# Appendix AEmission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production

Natural Gas Pneumatic Device Venting 98.236(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 for each device type. 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) 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) 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) 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 your 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. 1 1

Acid Gas Removal 98.236(d)(1)(iv) Whether any CO2emissions from the acid gas removal unit are recovered and transferred outside the facility, as specified in § 98.233(d)(11). 1 1
Acid Gas Removal 98.236(d)(1)(vi) Sub-basin ID (for the onshore petroleum and natural gas production industry segment only).1 1 Acid Gas Removal 98.236(d)(2)(i)(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 as specified in § 98.233(d) to calculate CO2emissions

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. 1 1

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

(d)(2)(iii)(A) (iii) If you used Calculation Method 4 as specified in §98.233(d) to calculate CO2emissions

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. 1 1

Acid Gas Removal 98.236(d)(2)(iii)(B) Natural gas feed temperature, in degrees Fahrenheit. 1 1 Acid Gas Removal 98.236(d)(2)(iii)(C) Natural gas feed pressure, in pounds per square inch. 1 1 Acid Gas Removal 98.236(d)(2)(iii)(E) Acid gas content of the feed natural gas, in mole percent. 1 1 

### Table 1. Proposed New Data Elements

A-1Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Acid Gas Removal 98.236(d)(2)(iii)(F) Acid gas content of the outlet natural gas, in mole percent. 1 1 Acid Gas Removal 98.236(d)(2)(iii)(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) Exit temperature of the natural gas, in degrees Fahrenheit. 1 1 Acid Gas Removal 98.236(d)(2)(iii)(I) Solvent pressure, in pounds per square inch. 1 1 Acid Gas Removal 98.236(d)(2)(iii)(J) Solvent temperature, in degrees Fahrenheit. 1 1 Acid Gas Removal 98.236(d)(2)(iii)(K) Solvent circulation rate, in gallons per minute. 1 1 Acid Gas Removal 98.236(d)(2)(iii)(L) Solvent weight, in pounds per gallon. 1 1 Dehydrators 98.236(e) Dehydrators. You must indicate whether your facility contains any of the following equipment: absorbent 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 your 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) Dehydrator feed natural gas water content, in pounds per million standard cubic feet. 1 1 Dehydrators 98.236(e)(1)(iv) Dehydrator outlet natural gas water content, in pounds per million standard cubic feet. 1 1 Dehydrators 98.236(e)(1)(vi) Dehydrator absorbent circulation rate, in gallons per minute. 1 1 Dehydrators 98.236(e)(1)(xii) Pressure of the wet natural gas, in pounds per square inch gauge. 1 1 Dehydrators 98.236(e)(1)(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) Sub-basin ID (for the onshore petroleum and natural gas production industry segment only). 1 1 Dehydrators 98.236(e)(2)(ii) ...If any dehydrators reported in paragraph (e)(2)(i) of this section are 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) ...If any dehydrators reported in paragraph (e)(2)(i) of this section were vented to a control device other than a vapor recovery device or a flare or regenerator firebox/fire tubes, then you must specify the type of control device and the number of dehydrators at the facility that were vented to each type of control device. 1 1

Dehydrators 98.236(e)(2)(iv) Whether any dehydrators reported in paragraph (e)(2)(i) of this section were vented to a flare or regenerator firebox/fire tubes.... 1 1 Dehydrators 98.236(e)(2)(iv) and

(e)(2)(iv)(A) ...If any dehydrators reported in paragraph (e)(2)(i) of this section 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-2Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Dehydrators 98.236(e)(3) and

(e)(3)(i) (3) For dehydrators that use desiccant (as specified in § 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). 1 1

Dehydrators 98.236(e)(3) and

(e)(3)(i) (3) For dehydrators that use desiccant (as specified in § 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) 1 1

Dehydrators 98.236(e)(3) and

(e)(3)(i) (3) For dehydrators that use desiccant (as specified in § 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). 1 1

Dehydrators 98.236(e)(3) and

(e)(3)(i) (3) For dehydrators that use desiccant (as specified in § 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) 1 1

Dehydrators 98.236(e)(3) and

(e)(3)(i) (3) For dehydrators that use desiccant (as specified in § 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 (as specified in § 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.) 1 1



### A-3Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Well Venting for Liquids Unloading98.236(f) Liquids unloading. You must indicate whether well venting for liquids unloading occurs at your facility 1 Well Venting for Liquids Unloading98.236(f) Indicate which methods (as specified in § 98.233(f)) were used to calculate emissions. 1 Well Venting for Liquids Unloading98.236(f), (f)(1), and

(f)(1)(i) If your 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 grouping 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 Unloading98.236(f)(1)(ii) Well tubing diameter and pressure group ID. 1 Well Venting for Liquids Unloading98.236(f)(1)(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 Unloading98.236(f)(1)(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 Unloading98.236(f)(1)(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 Unloading98.236(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 Unloading98.236(f)(1)(xii) and

(f)(1)(xii)(A) (xii) For each well tubing diameter group and pressure group combination, then 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 Unloading98.236(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 (as specified in § 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 Unloading98.236(f)(2)(ii) Calculation method. 1 Well Venting for Liquids Unloading98.236(f)(2)(vi) 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



### A-4Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Completions and Workovers with Hydraulic Fracturing98.236(g) You must indicate whether your facility had any gas well completions or workovers with hydraulic fracturing during the calendar year.... 1

Completions and Workovers with Hydraulic Fracturing98.236(g) and (g)(1) (g)...If your 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 Fracturing98.236(g)(2) Well type.
1

Completions and Workovers with Hydraulic Fracturing98.236(g)(4) Calculation method used.
1

Completions and Workovers with Hydraulic Fracturing98.236(g)(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 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 Fracturing98.236(g)(7) Annual gas emissions, in standard cubic feet (“Es,n”in Equation W-10A or W-10B).
1

Completions and Workovers without Hydraulic Fracturing98.236(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.... 1

Completions and Workovers without Hydraulic Fracturing98.236(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 Fracturing98.236(h)(1)(iv) Average daily gas production rate for all completions without hydraulic fracturing in the subbasin without flaring, in standard cubic feet per hour (average of all “Vp” used in Equation W13B). 1

Completions and Workovers without Hydraulic Fracturing98.236(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



### A-5Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Completions and Workovers without Hydraulic Fracturing98.236(h)(2)(iii) Total number of hours that gas vented to a flare during backflow 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 Fracturing98.236(h)(2)(iv) Average daily gas production rate for all completions without hydraulic fracturing in the subbasin with flaring, in standard cubic feet per hour (the average of all “Vp” from Equation W13B). 1

Completions and Workovers without Hydraulic Fracturing98.236(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 Fracturing98.236(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) You must indicate whether your facility has blowdown vent stacks.... 1 1 1 Blowdown Vent Stacks 98.236(i) ...If your facility has blowdown vent stacks, then you must report whether emissions were calculated by equipment type or by using flow meters.... 1 1 1 Blowdown Vent Stacks 98.236(i) and (i)(1) (i)...If you calculated emissions by equipment type, then you must report the information specified in paragraph (i)(1) of this section... (1) ...you must report the equipment types... 1 1 1

Blowdown Vent Stacks 98.236(i)(1)(i) (1) If you calculated emissions from blowdown vent stacks by equipment type, then you must report...the information specified in paragraphs (i)(1)(i) through (i)(1)(iii) of this section for reach equipment type. If a blowdown event resulted in emissions from multiple equipment types, then you must report the information in paragraphs (i)(1)(i) through (i)(1)(iii) of this section for the equipment 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 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 type). 1 1 1

Blowdown Vent Stacks 98.236(i)(1)(ii) Annual CO2emissions for the equipment type, in metric tons CO2, as calculated according to § 98.233(i)(2)(iii). 1 1 1
Blowdown Vent Stacks 98.236(i)(1)(iii) Annual CH4emissions for the equipment 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



### A-6Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Blowdown Vent Stacks 98.236(i)(2)(ii) Annual CH4emissions from all blowdown vent stacks at the facility, in metric tons CH4, (the sum all CH4mass emissions values calculated according to § 98.233(i)(3) for all flow meters).1 1 1

Onshore Production Storage Tanks 98.236(j) You must indicate whether your facility sends produced oil to atmospheric tanks. 1

Onshore Production Storage Tanks 98.236(j) If your facility sends produced oil to atmospheric tanks, then you must indicate which Calculation Method(s) you used to calculate GHG emissions... 1

Onshore Production Storage Tanks 98.236(j) If any atmospheric tanks were observed to have malfunctioning dump valves during the calendar year, then you must indicate that dump valves were malfunctioning... 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) 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) The number of atmospheric tanks in the sub-basin that did not control emissions with flares. 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) The number of atmospheric tanks in the sub-basin that controlled emissions with flares. 1

Onshore Production Storage Tanks 98.236(j)(3)(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
Transmission Storage Tanks 98.236(k) You must indicate whether your facility contains any transmission storage tanks.... 1 Transmission Storage Tanks 98.236(k)(1)(ii) Method used to determine if dump valve leakage occurred. 1 Transmission Storage Tanks 98.236(k)(1)(iii) Indicator whether scrubber dump valve leakage occurred for the transmission storage tank vent. 1



### A-7Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Transmission Storage Tanks 98.236(k)(1)(iv) Indicator 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) 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) 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) Duration of time that venting occurred in hours (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) 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) 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) 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) Average flow rate for well(s) tested, in barrels of oil per day. 1
Well Testing Venting and Flaring 98.236(l)(2)(iv) Average flow rate for well(s) tested, in barrels of oil per day. 1
Well Testing Venting and Flaring 98.236(l)(3)(iii) Average annual production rate for well(s) tested in actual cubic feet per day. 1
Well Testing Venting and Flaring 98.236(l)(4)(iii) Average annual production rate for well(s) tested, in actual cubic feet per day. 1

Associated Natural Gas Venting and Flaring 98.236(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 reportthe information specified in paragraphs (m)(1) through (m)(8) of this section for each subbasin. (1) Sub-basin ID. 1



### A-8Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Associated Natural Gas Venting and Flaring 98.236(m)(2) Indicator whether any associated gas was vented directly to the atmosphere without flaring. 1

Associated Natural Gas Venting and Flaring 98.236(m)(3) Indicator whether any associated gas was flared. 1

Associated Natural Gas Venting and Flaring 98.236(m)(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 this subpart). 1

Associated Natural Gas Venting and Flaring 98.236(m)(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 this subpart). 1

Associated Natural Gas Venting and Flaring 98.236(m)(7) Total volume of emissions reported elsewhere, in standard cubic feet, during time periods in which associated gas was vented or flared and which are calculated and reported under other paragraphs of this section, in standard cubic feet (the sum of “EREp,q” values used in Equation W-18 of this subpart). 1

Flare Stacks 98.236(n) You must indicate if your facility contains any flare stacks. 1 1 1 1 1 1 Flare Stacks 98.236(n)(7) Mole fraction of CH4in the feed gas to the flare (“XCH4” in Equation W-19 of this subpart). 1 1 1 1 1 1
Flare Stacks 98.236(n)(8) Mole fraction of CO2in 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) You must indicate whether your facility has centrifugal compressors.... 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1) and

(o)(1)(i) Report the information specified in paragraphs (o)(1)(i) through (o)(1)(xvi) of this section for

each 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) Indicate whether the compressor was measured in operating-mode. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(v) Indicate whether the compressor was measured in not-operating-depressurized-mode. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(vi) Indicate whether any compressor sources are part of a manifolded group of compressor
sources. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(vii) Indicate whether any compressor sources are routed to a flare. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(viii) Indicate whether any compressor sources have vapor recovery. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(ix) Indicate whether emissions from any compressor sources are are captured for fuel use or are routed to a thermal oxidizer. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(x) Indicate whether the compressor has blind flanges installed. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(xi) Indicate whether the compressor has wet or dry seals. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(xiii) Compressor power rating (hp). 1 1 1 1 1



### A-9Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Centrifugal Compressors 98.236(o)(1)(xiv) Year compressor was installed. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(xv) Compressor model name and description. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(1)(xvi) Date of last maintenance shutdown that compressor was depressurized. 1 1 1 1 1 Centrifugal Compressors 98.326(o)(2) and

(o)(2)(i) (2) For each compressor source at each compressor, report the information specified in

paragraphs (o)(2)(i) through (o)(2)(viii) of this section. (i) 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)(ii) Centrifugal compressor source (wet seal, isolation valve, or blowdown valve). 1 1 1 1 1 Centrifugal Compressors 98.326(o)(2)(iii) Unique name or ID for the emission vent. If the emission vent is connected a manifolded group of compressor sources, use the same emission vent ID for each compressor source. 1 1 1 1 1
Centrifugal Compressors 98.326(o)(2)(iv) Indicate whether the emission vent is for a single compressor source or manifolded group of compressor sources and whether the emissions from the emission 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)(v) Indicate whether an as found leak measurement(s) as identified in § 98.233(o)(2) or (o)(4) was conducted on the emission vent. 1 1 1 1 1 Centrifugal Compressors 98.326(o)(2)(vi) Indicate whether continuous leak measurements as identified in § 98.233(o)(3) or (o)(5) were conducted on the emission vent. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(2)(viii) If the emission vent is routed to flare, combustion, or vapor recovery, report the percentage of time that the respective device was operational. 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... (i) For each as found leak measurement performed on an emission vent, report the information specified in paragraphs (o)(3)(i)(A) through (o)(3)(i)(E) of this section. (A) Name or ID of emission vent. Use same emission vent ID as in paragraph (o)(2)(iii) of this section. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(3)(i)(B) Sample date. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(3)(i)(C) Leak measurement method. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(3)(i)(D) Measured flow rate, in standard cubic feet per hour. 1 1 1 1 1 Centrifugal Compressors 98.236(o)(3)(i)(E) For each compressor attached to the emission vent, report the mode of operation the compressor was in when the sample was taken. 1 1 1 1 1



### A-10Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

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-24 was used to calculate emissions in Equation W-23, 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

Centrifugal Compressors 98.236(o)(3)(ii)(C) The total number of compressors measured in the compressor mode-source combination in the current reporting year and the preceding two reporting years (Countmin Equation W24). 1 1 1 1 1
Centrifugal Compressors 98.236(o)(3)(ii)(D) Indicate whea ther the compressor mode-source combination reporter emission factor is facility-specific or corporate. 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) and (o)(4)(ii) of this section for each continuous measurement conducted on each emission vent associated with each compressor source or manifolded group of compressor sources. (i) Name or ID of emission vent. Use same Vent ID as in paragraph (o)(2)(iii) of this section. 1 1 1 1 1

Centrifugal Compressors 98.236(o)(4)(ii) Measured volume of flow during the reporting year, in million standard cubic feet. 1 1 1 1 1 Reciprocating Compressors 98.236(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)(xvi) of this section

for each 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) Indicate whether the compressor was measured in operating-mode. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(vi) Indicate whether the compressor was measured in standby-depressurized-mode. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(vii) Indicator whether the compressor was measured in not-operating-depressurized-mode. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(viii) Indicate whether any compressor sources are part of a manifolded group of compressor
sources. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(ix) Indicate whether any compressor sources are routed to a flare. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(x) Indicate whether any compressor sources have vapor recovery. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(xi) Indicate whether emissions from any compressor sources are captured for fuel use or are routed to a thermal oxidizer. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(xii) Indicate whether the compressor has blind flanges installed. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(xiii) Compressor power rating (hp). 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(xiv) Year compressor was installed. 1 1 1 1 1



### A-11Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Reciprocating Compressors 98.236(p)(1)(xv) Compressor model name and description. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(1)(xvi) Date of last maintenance shutdown for rod packing replacement. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(2) and

(p)(2)(i) (2) For each compressor source at each compressor, report the information specified in

paragraphs (p)(2)(i) through (p)(2)(viii) of this section. (i) 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)(ii) Reciprocating compressor source (isolation valve, blowdown valve, or rod packing). 1 1 1 1 1 Reciprocating Compressors 98.236(p)(2)(iii) Unique name or ID for the emission vent. If the emission vent is connected to a manifolded group of compressor sources, use the same emission vent ID for each compressor source. 1 1 1 1 1
Reciprocating Compressors 98.236(p)(2)(iv) Indicate whether the emission vent is for a single compressor source or manifolded group of compressor sources and whether the emissions from the emission 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)(v) Indicate whether an as found leak measurement(s) as identified in § 98.233(p)(2) or (p)(4) was conducted on the emission vent. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(2)(vi) Indicate whether continuous leak measurements as identified in § 98.233(p)(3) or (p)(5) were conducted on the emission vent. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(2)(viii) If the emission vent is routed to flare, combustion, or vapor recovery, report the percentage of time that the respective device was operational. 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 measurement method specified in paragraph §98.233(p)(2) is performed , report the information specified in paragraph (p)(3)(ii) of this section. (i) For each as found leak measurement performed on an emission vent, report the information specified in paragraphs (p)(3)(i)(A) through (p)(3)(i)(E) of this section. (A) Name or ID of emission vent. Use the same emission vent ID as in paragraph (p)(2)(iii) of this section. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(i)(B) Sample date. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(3)(i)(C) Leak measurement method. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(3)(i)(D) Measured flow rate, in standard cubic feet per hour. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(3)(i)(E) For each compressor attached to the emission vent, report the mode of operation the compressor was in when the sample was taken. 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) compressor mode-source combination. 1 1 1 1 1



### A-12Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Reciprocating Compressors 98.236(p)(3)(ii)(C) The total number of compressors measured in the compressor mode-source combination in the current reporting year and the preceding two reporting years (Countmin Equation W28). 1 1 1 1 1

Reciprocating Compressors 98.236(p)(3)(ii)(D) Indicate wheather the compressor mode-source combination reporter emission factor is facility-specific or corporate. 1 1 1 1 1 Reciprocating Compressors 98.236(p)(4) and

(p)(4)(i) 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) and (p)(4)(ii) of this section for each continuous measurement conducted on each emission vent associated with each compressor source or manifolded group of compressor sources. (i) Name or ID of emission vent. Use same emission vent ID as in paragraph (p)(2)(iii) of this section. 1 1 1 1 1

Reciprocating Compressors 98.236(p)(4)(ii) Measured volume of flow during the reporting year, in million standard cubic feet. 1 1 1 1 1 Equipment Leaks Surveys 98.236(q), (q)(1), and

(q)(1)(i) If your 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 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 (ii) of this section. (i) The number of complete equipment leak surveys performed during the calendar year. 1 1 1 1 1 1

Equipment Leaks Surveys 98.236(q)(2) and

(q)(2)(i) (2) You must indicate whether your 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 your facility’s industry segment. For each component type that is located at your facility, you must report the information specified in paragraphs (q)(2)(i) through (q)(2)(iv) of this section. If a component type is located at your 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”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 Surveys 98.236(q)(2)(iii) Average time the surveyed components were found leaking and operational, in hours (average of Tp,zfrom Equation W-30 of this subpart for the component type). 1 1 1 1 1 1
Equipment Leaks Surveys 98.236(q)(3)(ii) Number of meter/regulator runs at above grade transmission-distribution transfer stations surveyed in the calendar year (CountMR,yfrom Equation W-31 of this subpart, for the current calendar year). 1
Equipment Leaks Surveys 98.236(q)(3)(iii) Average time that meter/regulator runs surveyed in the calendar year were operational, in hours (average of Tw,yfrom Equation W-31 of this subpart, for the current calendar year). 1



### A-13Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Equipment Leaks Surveys 98.236(q)(3)(v) Number of meter/regulator runs at above grade transmission-distribution transfer stations surveyed in current leak survey cycle (sum of CountMR,yfrom Equation W-31 of this subpart, for all calendar years in the current leak survey cycle). 1

Equipment Leaks Surveys 98.236(q)(3)(vi) Average time that meter/regulator runs surveyed in the current leak survey cycle were operational, in hours (average of Tw,yfrom Equation W-31of this subpart, for all years included in the leak survey cycle). 1
Equipment Leaks by Population Count 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 (r)(1) of this section. Natural gas distribution facilities must also report the information specified in paragraph (r)(2) of this section. Onshore petroleum and natural gas production facilities must also report the information specified in paragraph (r)(3) of this section. (1) You must indicate whether your facility contains any of the emission source types covered by § 98.233(r), for the applicable industry segment. You must report the information specified in paragraphs (r)(1)(i) through (r)(1)(v) of this section separately for each emission source type 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 Count 98.236(r)(1)(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
Equipment Leaks by Population Count 98.236(r)(1)(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 Count 98.236(r)(2)(v) 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 Count 98.236(r)(2)(vi) Average estimated time that each meter/regulator run 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 Count 98.236(r)(2)(vii) Annual CO2emissions, in metric tons CO2, from above grade metering regulating stations that are not above grade transmission-distribution transfer stations. 1
Equipment Leaks by Population Count 98.236(r)(2)(viii) Annual CH-4emissions, in metric tons CH4, from above grade metering regulating stations that are not above grade transmission-distribution transfer stations. 1
Equipment Leaks by Population Count 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



### A-14Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Equipment Leaks by Population Count 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)(iv ) 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) You must indicate whether CO2EOR injection was used at your facility during the calendar year, and if any EOR injection pump blowdowns occurred during the year. If 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. 1

EOR Injection Pump Blowdown 98.236(w)(1) Sub-basin ID. 1 EOR Injection Pump Blowdown 98.236(w)(2) EOR injection pump system identifier. 1 EOR Injection Pump Blowdown 98.236(w)(7) Mass fraction of CO2in critical phase EOR injection gas (“GHGCO2” in Equation W-37 of this subpart). 1 EOR Hydrocarbon Liquids 98.236(x) You must indicate whether hydrocarbon liquids were produced through EOR operations.... 1 EOR Hydrocarbon Liquids 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

Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities98.236(z) If your facility is required by §98.232(c)(22) or (i)(7) to report emissions from combustion equipment, then you must indicate whether your facility has any combustion units subject to reporting according to paragraphs (a)(1)(xvii) or (a)(8)(iii) of this section....

1 1

Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities98.236(z) and (z)(1)(z) ...If your facility contains any combustion units subject to reporting according to paragraphs (a)(1)(xvii) or (a)(8)(iii) 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).... 1 1



### A-15Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities98.236(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 compressordrivers, 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. 1 1

Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities98.236(z)(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. 1 1

Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities98.236(z)(2)(ii) The type of fuel combusted.

1 1

Miscellaneous 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

Miscellaneous 98.236(aa)(1)(i)(B) The quantity of gas produced in the calendar year for sales, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(1)(i)(C) The quantity of crude oil produced in the calendar year for sales, not including lease condensates, in barrels. 1



### A-16Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Miscellaneous 98.236(aa)(1)(i)(D) The quantity of lease condensate produced in the calendar year for sales, in barrels. 1 Miscellaneous 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

Miscellaneous 98.236(aa)(1)(ii)(B) County. 1 Miscellaneous 98.236(aa)(1)(ii)(C) Formation type. 1 Miscellaneous 98.236(aa)(1)(ii)(D)The number of producing wells at the end of the calendar year 1 Miscellaneous 98.236(aa)(1)(ii)(E) The number of producing wells acquired during the calendar year 1 Miscellaneous 98.236(aa)(1)(ii)(F) The number of producing wells divested during the calendar year. 1 Miscellaneous 98.236(aa)(1)(ii)(G)The number of wells completed during the calendar year. 1 Miscellaneous 98.236(aa)(1)(ii)(H)The number of wells taken out of production during the calendar year. 1 Miscellaneous 98.236(aa)(1)(ii)(I) Average mole fraction of CH4in produced gas. 1 Miscellaneous 98.236(aa)(1)(ii)(J) Average mole fraction of CO2in produced gas 1 Miscellaneous 98.236(aa)(2) and

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

(aa)(2)(iii) of this section. (i) The quantity of gas produced from the offshore platform in the calendar year for sales, in thousand standard cubic feet. 1

Miscellaneous 98.236(aa)(2)(ii) The quantity of oil produced from the offshore platform in the calendar year for sales, in barrels. 1 Miscellaneous 98.236(aa)(2)(iii) The quantity of condensate produced from the offshore platform in the calendar year for sales, in barrels. 1 Miscellaneous 98.236(aa)(3) and

(aa)(3)(i) (3) For natural gas processing, report the quantities specified in paragraphs (aa)(3)(i) through

(aa)(3)(vii) of this section. (i) The quantity of produced gas received at the gas processing plant in the calendar year, in thousand standard cubic feet. 1

Miscellaneous 98.236(aa)(3)(ii) The quantity of processed (residue) gas leaving the gas processing plant in the calendar year, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(3)(iii) The quantity of NGLs (bulk and fractionated) received at the gas processing plant in the calendar year, in barrels. 1 Miscellaneous 98.236(aa)(3)(iv) The quantity of NGLs (bulk and fractionated) leaving the gas processing plant in the reporting year (barrels). 1 Miscellaneous 98.236(aa)(3)(v) Average mole fraction of CH4 in produced gas received. 1 Miscellaneous 98.236(aa)(3)(vi) Average mole fraction of CO2 in produced gas received. 1 Miscellaneous 98.236(aa)(3)(vii) Indicate whether the facility fractionates NGLs. 1 Miscellaneous 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

Miscellaneous 98.236(aa)(4)(ii) Number of compressors. 1 Miscellaneous 98.236(aa)(4)(iii) Total compressor power rating of all compressors combined, in horsepower. 1 Miscellaneous 98.236(aa)(4)(iv) Average upstream pipeline pressure, in pounds per square inch gauge. 1 Miscellaneous 98.236(aa)(4)(v) Average downstream pipeline pressure , in pounds per square inch gauge. 1



### A-17Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Miscellaneous 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

Miscellaneous 98.236(aa)(5)(ii) The quantity of gas withdrawn from storage in the calendar year, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(5)(iii) Total storage capacity, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(6) For LNG import equipment, report the quantity of LNG imported in the calendar year, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(7) For LNG export equipment, report the quantity of LNG exported in the calendar year, in thousand standard cubic feet. 1 Miscellaneous 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

Miscellaneous 98.236(aa)(8)(ii) The quantity of LNG withdrawn from storage in the calendar year, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(8)(iii) Total storage capacity, in thousand standard cubic feet. 1 Miscellaneous 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

Miscellaneous 98.236(aa)(9)(ii) The quantity of natural gas withdrawn from in-system storage in the calendar year, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(9)(iii) The quantity of natural gas added to in-system storage in the calendar year, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(9)(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

Miscellaneous 98.236(aa)(9)(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

Miscellaneous 98.236(aa)(9)(vi) The quantity of natural gas consumed by the LDC for operational purposes, in thousand standard cubic feet. 1 Miscellaneous 98.236(aa)(9)(vii) The estimated quantity of gas stolen in the calendar year, in thousand standard cubic feet. 1



### A-18Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 1. Proposed New Data Elements

Missing Data Provisions 98.236(bb), and

(bb)(1) (bb) For any missing data procedures used, report the information in paragraphs (i) through

(v) in this section for each individual missing data value used in a calculation. Aggregation of missing data values within a component, well, sub-basin, or basin is not acceptable. If missing data is substituted for the same parameter in non-consecutive periods during the calendar year, the information in paragraphs (1) through (5) in this section should be reported for each period separately. (1) The date(s) the missing data is used. 1 1 1 1 1 1 1

Missing Data Provisions 98.236(bb)(2) The equation(s) in which the missing data is used 1 1 1 1 1 1 1 Missing Data Provisions 98.236(bb)(3) The description of the unique or unusual circumstance that led to missing data use, including information on any equipment or components involved and any procedures that were not followed. 1 1 1 1 1 1 1
Missing Data Provisions 98.236(bb)(4) The description of the procedures used to substitute an unavailable value of a parameter. 1 1 1 1 1 1 1 Missing Data Provisions 98.236(bb)(5) The description of how the owner or operator will avoid the use of missing data in the future, such as mitigation strategies or changes to standard operating procedures. 1 1 1 1 1 1 1

TOTAL NUMBER OF PROPOSED NEW DATA ELEMENTS TOTAL NUMBER OF PROPOSED NEW DATA ELEMENTS BY INDUSTRY SEGMENT121 99 82 86 124 31 79 3 245



### A-19

### Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production



### Acid Gas Removal 98.236(d)(1)(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) Natural gas flow rate, in standard cubic feet per minute. 1 1 Well Venting for Liquids Unloading 98.236(f)(1)(iv) Count of wells vented to the atmosphere for the sub-basin/well tubing diameter and pressure grouping. 1 Completions and Workovers with Hydraulic Fracturing 98.236(g)(3) Number of completions or workovers in the category. 1
Completions and Workovers without Hydraulic Fracturing98.236(h)(1)(ii) Number of well completions that vented gas directly to the atmosphere without flaring. 1
Completions and Workovers without Hydraulic Fracturing98.236(h)(2)(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. 1

Centrifugal Compressors 98.236(o)(3)(ii)(B) The compressor mode-source combination reporter emission factor, in standard cubic feet per hour (EFm,s

### in Equation W-24). 1 1 1 1 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 Compressors98.236(p)(2)(vii)(B)Annual CH4

### emissions, in metric tons CH4

### . 1 1 1 1 1 Reciprocating Compressors98.236(p)(3)(ii)(B) The compressor mode-source combination reporter emission factor, in standard cubic feet per hour (EFm,s

### in Equation W-28). 1 1 1 1 1 Equipment Leaks Surveys 98.236(q)(1)(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



### Table 2. Proposed Revised Data Elements

A-20

### Emission Source Proposed Citation Reference Proposed Rule Text Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 2. Proposed Revised Data Elements

EOR Injection Pump Blowdown 98.236(w)(4) Total volume of EOR injection pump system equipment chambers, in cubic feet(“Vv

### ” in Equation W-37 of this subpart). 1 Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities 98.236(z)(1)(ii) The total number of combustion units.

1 1

Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities 98.236(z)(2) and (z)(2)(i) (2)...If your facility contains: external fuel combustion units with a rated heat

capacity greater than 5 mmBtu/hr ; internal fuel combustion units that are not compressor-drivers, with a rated heat capacity greater than to 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 1

TOTAL NUMBER OF PROPOSED REVISED DATA ELEMENTS TOTAL NUMBER OF PROPOSED REVISED DATA ELEMENTS BY INDUSTRY SEGMENT6 4 4 4 10 3 4 0 15



### A-21

### Emission Source Current Rule Text [98.236(c) or 98.236(d)] Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production



### Completions and Workovers with Hydraulic Fracturing (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 (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 (A) Total number of blowdowns for each unique physical volume in the calendar year. 1 1 1 Blowdown Vent Stacks (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 (C) A unique name or ID number for the unique physical volume. 1 1 1 Blowdown Vent Stacks (A) Total number of blowdowns for all unique physical volumes in the calendar year. 1 1 1 Blowdown Vent Stacks (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 (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 (A) Total volume of sales oil from all wells in barrels per year. 1 Onshore Production Storage Tanks (B) Total number of wells sending oil directly to tanks. 1 Onshore Production Storage Tanks (C) Total number of wells sending oil to separators off the well pads. 1 Onshore Production Storage Tanks (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 (E) Count of hydrocarbon tanks on wellpads. 1 Onshore Production Storage Tanks (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 (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 (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 (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 (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 

### Table 3. Data Elements To Be Deleted

A-22

### Emission Source Current Rule Text [98.236(c) or 98.236(d)] Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 3. Data Elements To Be Deleted

Centrifugal Compressors (B) Fraction of vent gas recovered for fuel or sales or flared. 1 1 1 1 1 Centrifugal Compressors (C) Annual throughput in million scf, use an engineering calculation based on best available data. 1 1 1 1 1 Centrifugal Compressors (D) Type of meters used for making measurements. 1 1 1 1 1 Centrifugal Compressors (E) Reporter emission factor for wet seal oil degassing vents in cubic feet per hour (refer to Equation W24 of §98.233). 1 1 1 1 1 Centrifugal Compressors (G) Report seal oil degassing vent emissions for compressors measured and for compressors not measured in metric tons of CO2e for each gas. 1 1 1 1 1 Centrifugal Compressors (A) Total time in hours the compressor is in operating mode. 1 1 1 1 1 Centrifugal Compressors (B) Reporter emission factor for blowdown vents in cubic feet per hour (refer to Equation W-24 of §98.233). 1 1 1 1 1 Centrifugal Compressors (C) Report blowdown vent emissions when in operating mode in metric tons of CO2e for each gas. 1 1 1 1 1 Centrifugal Compressors (C) Report the isolation valve leakage emissions in not operating, depressurized mode in metric tons of CO2e for each gas. 1 1 1 1 1 Reciprocating Compressors(A) Annual throughput in million scf, use an engineering calculation based on best available data. 1 1 1 1 1 Reciprocating Compressors(C) Report rod packing emissions for compressors measured and for compressors not measured in metric tons of CO2e for each gas. 1 1 1 1 1 Reciprocating Compressors(B) Reporter emission factor for blowdown vents in cubic feet per hour (refer to §98.233, Equation W28). 1 1 1 1 1 Reciprocating Compressors(C) Report blowdown vent emissions when in operating and standby pressurized modes in metric tons of CO2e for each gas. 1 1 1 1 1 Reciprocating Compressors(C) Report isolation valve leakage emissions in not operating, depressurized mode in metric tons of CO2e for each gas. 1 1 1 1 1 Equipment Leaks Surveys (B) For onshore natural gas processing, range of concentrations of CH4 and CO2 (refer to Equation W30A of §98.233). 2 Equipment Leaks Surveys - LDC (ix) Number of miles of unprotected steel distribution mains. 1 Equipment Leaks Surveys - LDC (x) Number of miles of protected steel distribution mains. 1 Equipment Leaks Surveys - LDC (xi) Number of miles of plastic distribution mains. 1 Equipment Leaks Surveys - LDC (xii) Number of miles of cast iron distribution mains. 1 Equipment Leaks Surveys - LDC (xiii) Number of unprotected steel distribution services. 1



### A-23

### Emission Source Current Rule Text [98.236(c) or 98.236(d)] Onshore Natural Gas Processing Onshore Natural Gas Transmission Compression Underground Natural Gas Storage LNG Import and Export Equipment Onshore Petroleum and Natural Gas Production Natural Gas Distribution LNG Storage Offshore Petroleum and Natural Gas Production 

### Table 3. Data Elements To Be Deleted

Equipment Leaks Surveys - LDC (xiv) Number of protected steel distribution services. 1 Equipment Leaks Surveys - LDC (xv) Number of plastic distribution services. 1 Equipment Leaks Surveys - LDC (xvi) Number of copper distribution services. 1 Equipment Leaks Surveys - LDC (xvii) Annual CO2 and CH4 emissions, in metric tons CO2e for each gas, from all above grade T-D transfer stations combined. 2 Equipment Leaks Surveys - LDC (xviii) Annual CO2 and CH4 emissions, in metric tons CO2e for each gas, from all below grade T-D transfer stations combined. 2 Equipment Leaks Surveys - LDC (xix) Annual CO2 and CH4 emissions, in metric tons CO2e for each gas, from all above grade meteringregulating stations (including T-D transfer stations) combined. 2 Equipment Leaks Surveys - LDC (xx) Annual CO2 and CH4 emissions, in metric tons CO2e for each gas, from all below grade meteringregulating stations (including T-D transfer stations) combined. 2 Equipment Leaks Surveys - LDC (xxi) Annual CO2 and CH4 emissions, in metric tons CO2e for each gas, from all distribution mains combined. 2 Equipment Leaks Surveys - LDC (xxii) Annual CO2 and CH4 emissions, in metric tons CO2e for each gas, from all distribution services combined. 2 Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities (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 DATA ELEMENTS TO BE DELETED TOTAL NUMBER OF DATA ELEMENTS TO BE DELETED BY INDUSTRY SEGMENT23 21 14 21 20 21 14 0 63



### A-24