MEMORANDUM 

To: Docket # EPA-HQ-OAR-2011-0512 

From: Alexis McKittrick and Mark DeFigueiredo, EPA/CCD 

Date: February 20, 2014 

Subject: Revisions to the Subpart W Reporting Requirements as proposed in the “Greenhouse 

Gas Reporting Rule: Revisions and Confidentiality Determinations for Petroleum 

and Natural Gas Systems; Proposed Rule” 

In the notice entitled “Greenhouse Gas Reporting Rule: Revisions and Confidentiality 

Determinations for Petroleum and Natural Gas Systems; Proposed Rule,” the EPA is proposing 

changes to the reporting requirements in the Greenhouse Gas Reporting Program for Petroleum 

and Natural Gas Systems (subpart W). The proposed changes amend monitoring and data 

reporting requirements, revise calculation methods, clarify certain terms and definitions, and 

correct technical and editorial errors. Specifically, the reporting requirements section of 

subpart W has been re-written to revise the reported data elements to clarify and align more 

closely with the calculation methods and to clearly identify the data that must be reported for 

each source type. 

Table 1 lists all the proposed changes to the subpart W reporting requirements, including 

the proposed and current rule text, and an identification of whether the data element is new, 

revised, or a current reporting requirement. Data elements that are listed as “Current” are those 

with only minor changes that do not change the underlying data required to be reported in the 

existing data element. Data elements listed as “Revised” are those with substantial revisions to 

existing reporting requirements. 
2 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

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. 

§98.236(b)(1)(i) §98.236(c)(1)(i), 

(ii), (iii) 

(1) The number of natural gas pneumatic devices as specified in paragraphs (b)(1)(i) and (b)(1)(ii) of this section. (i) The total number of devices, determined according to §98.233(a)(1) and (a)(2). 

(i) Actual count and estimatcount separately of natural gpneumatic high bleed deviceas applicable. (ii) Actual count and estimacount separately of natural gpneumatic low bleed deviceapplicable. (iii) Actual count and estimacount separately of natural gpneumatic intermittent bleed devices as applicable. 
3 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(b)(1)(ii) and (b)(1)(ii)(A) 

§98.236(c)(1)(i), (ii), (iii) 

(ii) If the reported value in paragraph (b)(1)(i) of this section is an estimated value determined according to §98.233(a)(2), then you must report the information specified in paragraphs (b)(1)(ii)(A) through (b)(1)(ii)(C) of this section. (A) The number of devices reported in paragraph (b)(1)(i) of this section that are counted. 

(i) Actual count and estimatcount separately of natural gpneumatic high bleed deviceas applicable. (ii) Actual count and estimacount separately of natural gpneumatic low bleed deviceapplicable. (iii) Actual count and estimacount separately of natural gpneumatic intermittent bleed devices as applicable. 

§98.236(b)(1)(ii)(B) §98.236(c )(1)(i), 

(ii), (iii) 

(B) The number of devices reported in paragraph (b)(1)(i) of this section that are estimated (not counted). 

(i) Actual count and estimatcount separately of natural gpneumatic high bleed deviceas applicable. (ii) Actual count and estimacount separately of natural gpneumatic low bleed deviceapplicable. (iii) Actual count and estimacount separately of natural gpneumatic intermittent bleed devices as applicable. 

§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. 

§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). 
4 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(b)(3) §98.236(c )(1)(iv) (3) Annual CO2 emissions, in metric tons CO2, for the 

natural gas pneumatic devices combined, calculated using Equation W-1 of this subpart and §98.233(a)(4), and reported in paragraph (b)(1)(i) of this section. 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for each of the following pieces of equipmehigh bleed pneumatic deviceintermittent bleed pneumatic devices; low bleed pneumatidevices. 

§98.236(b)(4) §98.236(c)(1)(iv) (4) Annual CH4 emissions, in metric tons CH4, for the 

natural gas pneumatic devices combined, calculated using Equation W-1 of this subpart and §98.233(a)(4), and reported in paragraph (b)(1)(i) of this section. 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for each of the following pieces of equipmehigh bleed pneumatic deviceintermittent bleed pneumatic devices; low bleed pneumatidevices. 

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. 

§98.236(c)(1) §98.236(c)(2)(i) (1) Count of natural gas driven pneumatic pumps. Count of natural gas driven 

pneumatic pumps. 

§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). 
5 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(c)(3) §98.236(c)(2)(ii) (3) Annual CO2 emissions, in metric tons CO2, for all 

natural gas driven pneumatic pumps combined, calculated according to §98.233(c)(1) and (c)(2). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for all natural gdriven pneumatic pumps combined. 

§98.236(c)(4) §98.236(c)(2)(ii) (4) Annual CH4 emissions, in metric tons CH4, for all 

natural gas driven pneumatic pumps combined, calculated according to §98.233(c)(1) and (c)(2). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for all natural gdriven pneumatic pumps combined. 

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. 

§98.236(d)(1)(i) §98.236(c)(3)(vi) (1) You must report the information specified in 

paragraphs (d)(1)(i) through (d)(1)(v) of this section for each acid gas removal unit. (i) A unique name or ID number for the acid gas removal unit. For the onshore petroleum and natural gas production industry segment, a different name or ID may be used for a single acid gas removal unit for each location it operates at in a given year. 

For the onshore natural gas processing industry segment only, report a unique name oID number for the AGR unit
6 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(d)(1)(ii) §98.236(c)(3)(i) 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. 

Total throughput off the acid gas removal unit using a meor engineering estimate baseon process knowledge or beavailable data in million cubfeet per year. 

§98.236(d)(1)(iii) §98.236(c)(3)(vii) The calculation method used to calculate CO2

emissions from the acid gas removal unit, as specified in §98.233(d). 

An indication of which calculation methodology waused for the AGR. 

§98.236(d)(1)(iv) Whether any CO2 emissions from the acid gas removal 

unit are recovered and transferred outside the facility, as specified in § §98.233(d)(11). 

§98.236(d)(1)(iv) §98.236(c)(3)(iv) If any CO2 emissions from the acid gas removal unit 

were recovered and transferred outside the facility, then you must report the annual quantity of CO2, in metric tons CO2 that was recovered and transferred outside the facility. 

Report the annual quantity oCO2, expressed in metric tonCO2e, that was recovered frothe AGR unit and transferreoutside the facility, under subpart PP of this part. 

§98.236(d)(1)(v) §98.236(c)(3)(v) Annual CO2 emissions, in metric tons CO2, from the 

acid gas removal unit, calculated using any one of the calculation methods specified in § §98.233(d) and as specified in § §98.233(d)(10) and (11). 

Report annual CO2 emissionfor the AGR unit, expressed metric tons CO2e. 

§98.236(d)(1)(vi) Sub-basin ID (for the onshore petroleum and natural 

gas production industry segment only). 

§98.236(d)(2)(i) and (d)(2)(i)(A) 

§98.236(c)(3)(ii) (i) If you used Calculation Method 1 or Calculation 

Method 2 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)(i)(A) and (d)(2)(i)(B) of this section. (A) Annual average volumetric fraction of CO2 in the vent gas exiting the acid gas removal unit. 

For Calculation Methodologand Calculation Methodologof §98.233(d), annual averagfraction of CO2 content in thvent from the acid gas remounit (refer to §98.233(d)(6))
7 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(d)(2)(I)(B) Annual volume of gas vented from the acid gas 

removal unit, in cubic feet. 

§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 CO2 emissions from the acid gas removal unit, then you must report the information specified in paragraphs (d)(2)(ii)(A) through (d)(2)(ii)(D) of this section. (A) Which equation was used; Equation W-4A or W4B. 

§98.236(d)(2)(ii)(B) §98.236(c)(3)(iii) (B) Annual average volumetric fraction of CO2 in the 

natural gas flowing out of the acid gas removal unit, as specified in Equation W-4A or Equation W-4B of this subpart. 

For Calculation Methodologof §98.233(d), annual averagvolume fraction of CO2 contof natural gas into and out othe acid gas removal unit (reto §98.233(d)(7) and (d)(8))

§98.236(d)(2)(ii)(C) §98.236(c)(3)(iii) (C) Annual average volumetric fraction of CO2 content 

in natural gas flowing into the acid gas removal unit, as specified in Equation W-4A or Equation W-4B of this subpart. 

For Calculation Methodologof §98.233(d), annual averagvolume fraction of CO2 contof natural gas into and out othe acid gas removal unit (reto §98.233(d)(7) and (d)(8))

§98.236(d)(2)(ii) (D) 

§98.236(c)(3)(i) (D) The natural gas flow rate used, as specified in 

Equation W-4A of this subpart, reported as either total annual volume of natural gas flow into the acid gas removal unit in cubic feet at actual conditions; or total annual volume of natural gas flow out of the acid gas removal unit, as specified in Equation W-4B of this subpart, in cubic feet at actual conditions. 

Total throughput off the acid gas removal unit using a meor engineering estimate baseon process knowledge or beavailable data in million cubfeet per year. 
8 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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 CO2 emissions from the acid gas removal unit, then you must report the information specified in paragraphs (d)(2)(iii)(A) through (d)(2)(iii)(L) of this section, as applicable to the simulation software package used. (A) The name of the simulation software package used. 

§98.236(d)(2)(iii) (B) 

Natural gas feed temperature, in degrees Fahrenheit. 

§98.236(d)(2)(iii) (C) 

Natural gas feed pressure, in pounds per square inch. 

§98.236(d)(2)(iii) (D) 

§98.236(c)(3)(i) Natural gas flow rate, in standard cubic feet per minute. Total throughput off the acid 

gas removal unit using a meor engineering estimate baseon process knowledge or beavailable data in million cubfeet per year. 

§98.236(d)(2)(iii) (E) 

Acid gas content of the feed natural gas, in mole percent. 

§98.236(d)(2)(iii) (F) 

Acid gas content of the outlet natural gas, in mole percent. 

§98.236(d)(2)(iii) (G) 

Unit operating hours, excluding downtime for maintenance or standby, in hours per year. 

§98.236(d)(2)(iii) (H) 

Exit temperature of the natural gas, in degrees Fahrenheit. 

§98.236(d)(2)(iii)(I) Solvent pressure, in pounds per square inch. §98.236(d)(2)(iii)(J) Solvent temperature, in degrees Fahrenheit. §98.236(d)(2)(iii) (K) 

Solvent circulation rate, in gallons per minute. 

§98.236(d)(2)(iii) (L) 

Solvent weight, in pounds per gallon. 
9 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

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). 

§98.236(e)(1) and (e)(1)(i) 

§98.236(c)(4)(i)(L) (1) For each absorbent dehydrator that has an annual 

average daily natural gas throughput greater than or equal to 0.4 million standard cubic feet per day (as specified in § §98.233(e)(1)), you must report the information specified in paragraphs (e)(1)(i) through (e)(1)(xviii) of this section for the dehydrator.  (i) A unique name or ID number for the dehydrator. For the onshore petroleum and natural gas production industry segment, a different name or ID may be used for a single dehydrator for each location it operates at in a given year. 

For the onshore natural gas processing industry segment only, report a unique name oID number for glycol dehydrator. 

§98.236(e)(1)(ii) §98.236(c)(4)(i)(A) Dehydrator feed natural gas flow rate in million 

standard cubic feet per day, determined by engineering estimate based on best available data. 

Glycol dehydrator feed natugas flow rate in MMscfd, determined by engineering estimate based on best availdata. 

§98.236(e)(1)(iii) Dehydrator feed natural gas water content, in pounds 

per million standard cubic feet. 

§98.236(e)(1)(iv) Dehydrator outlet natural gas water content, in pounds 

per million standard cubic feet. 
10 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(e)(1)(v) §98.236(c)(4)(i)(B) Dehydrator absorbent circulation pump type (e.g. 

natural gas pneumatic, air pneumatic, or electric). 

Glycol dehydrator absorbencirculation pump type 

§98.236(e)(1)(vi) Dehydrator absorbent circulation rate, in gallons per 

minute. 

§98.236(e)(1)(vii) §98.236(c)(4)(i)(E) Type of absorbent (e.g. triethylene glycol (TEG), 

diethylene glycol (DEG), or ethylene glycol (EG)). 

Type of absorbent. 

§98.236(e)(1)(viii) §98.236(c)(4)(i)(C) Whether stripper gas is used in dehydrator. Whether stripper gas is used 

glycol dehydrator. 

§98.236(e)(1)(ix) §98.236(c)(4)(i)(D) Whether a flash tank separator is used in dehydrator. Whether a flash tank separat

is used in glycol dehydrator

§98.236(e)(1)(x) §98.236(c)(4)(i)(F) Total time the dehydrator is operating, in hours. Total time the glycol 

dehydrator is operating in hours. 

§98.236(e)(1)(xi) §98.236(c)(4)(i)(G) Temperature of the wet natural gas, in degrees 

Fahrenheit. 

Temperature, in degrees Fahrenheit and pressure, in psig, of the wet natural gas. 

§98.236(e)(1)(xii) Pressure of the wet natural gas, in pounds per square 

inch gauge. 

§98.236(e)(1)(xiii) §98.236(c)(4)(i)(H) Mole fraction of CH4 in wet natural gas. Concentration of CH4 and C

in wet natural gas. 

§98.236(e)(1)(xiv) §98.236(c)(4)(i)(H) Mole fraction of CO2 in wet natural gas. Concentration of CH4 and C

in wet natural gas. 

§98.236(e)(1)(xv) §98.236(c)(4)(i)(I) Whether any dehydrator emissions are vented to a 

vapor recovery device. 

What vent gas controls are u(refer to §98.233(e)(3) and (e)(4)). 

§98.236(e)(1)(xvi) §98.236(c)(4)(i)(I) Whether any dehydrator emissions are vented to a flare 

or regenerator firebox/fire tubes... 

What vent gas controls are u(refer to §98.233(e)(3) and (e)(4)). 
11 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(e)(1)(xvi) and (e)(1)(xvi)(A) 

§98.236(c)(4)(i)(K) (xvi)...If any emissions are vented to a flare or 

regenerator firebox/fire tubes, report the information specified in paragraphs (e)(1)(xvi)(A) through (e)(1)(xvi)(C) of this section for these emissions from the dehydrator. (A) Annual CO2 emissions, in metric tons CO2, for the dehydrator, calculated according to § §98.233(e)(6). 

For each glycol dehydrator, report annual CO2, CH4, and N2O emissions that resulted from flaring process gas from the dehydrator, expressed in metric tons CO2e for each g

§98.236(e)(1)(xvi) (B) 

§98.236(c)(4)(i)(K) Annual CH4 emissions, in metric tons CH4, for the 

dehydrator, calculated according to § §98.233(e)(6). 

For each glycol dehydrator, report annual CO2, CH4, and N2O emissions that resulted from flaring process gas from the dehydrator, expressed in metric tons CO2e for each g

§98.236(e)(1)(xvi) (C) 

§98.236(c)(4)(i)(K) Annual N2O emissions, in metric tons N2O per year, 

for the dehydrator, calculated according to § §98.233(e)(6). 

For each glycol dehydrator, report annual CO2, CH4, and N2O emissions that resulted from flaring process gas from the dehydrator, expressed in metric tons CO2e for each g

§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. 

§98.236(e)(1)(xvii) and (e)(1)(xvii)(A) 

§98.236(c)(4)(i)(J) (xvii) If any emissions are not routed to a flare or 

regenerator firebox/fire tubes, then you must report the information specified in paragraphs (e)(1)(xvii)(A) and (e)(1)(xvii)(B) of this section for those emissions from the dehydrator. (A) Annual CO2 emissions, in metric tons CO2, for the dehydrator when not venting to a flare or regenerator firebox/fire tubes, calculated according to § §98.233(e)(1) and (e)(5). 

For each glycol dehydrator, report annual CO2 and CH4emissions that resulted from venting gas directly to the atmosphere, expressed in metric tons CO2e for each g
12 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(e)(1) (xvii)(B) 

§98.236(c)(4)(i)(J) Annual CH4 emissions, in metric tons CH4, for the 

dehydrator when not venting to a flare or regenerator firebox/fire tubes, calculated according to § §98.233(e)(1) and (e)(5). 

For each glycol dehydrator, report annual CO2 and CH4emissions that resulted from venting gas directly to the atmosphere, expressed in metric tons CO2e for each g

§98.236(e)(1)(xviii) Sub-basin ID (for the onshore petroleum and natural 

gas production industry segment only). 

§98.236(e)(2)(i) §98.236(c)(4)(ii) 

(A) 

(2) For glycol dehydrators with an annual average daily natural gas throughput less than 0.4 million standard cubic feet per day (as specified in § §98.233(e)(2)), you must report the information specified in paragraphs (e)(2)(i) through (e)(2)(iv) of this section for the entire facility. (i) The total number of dehydrators at the facility. 

Count of glycol dehydrators

§98.236(e)(2)(ii) §98.236(c)(4)(ii)(B) Whether any dehydrators reported in paragraph 

(e)(2)(i) of this section were vented to a vapor recovery device.... 

Which vent gas controls are used (refer to §98.233(e)(3) (e)(4)). 

§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. 

§98.236(e)(2)(iii) §98.236(c)(4)(ii)(B) Whether 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.... 

Which vent gas controls are used (refer to §98.233(e)(3) (e)(4)). 

§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. 
13 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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.... 

§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. 

§98.236(e)(2)(iv)(B) §98.236(c)(4)(ii)(D) Annual CO2 emissions, in metric tons CO2, for the 

dehydrators reported in paragraph (e)(2)(iv)(A) of this section, calculated according to § §98.233(e)(6). 

Report annual CO2, CH4, anN2O emissions at the facility level that resulted from the flaring of process gas, expressed in metric tons COfor each gas, combined for aglycol dehydrators with annaverage daily throughput of than 0.4 MMscfd. 

§98.236(e)(2)(iv)(C) §98.236(c)(4)(ii)(D) Annual CH4 emissions, in metric tons CH4, for the 

dehydrators reported in paragraph (e)(2)(iv)(A) of this section, calculated according to § §98.233(e)(6). 

Report annual CO2, CH4, anN2O emissions at the facility level that resulted from the flaring of process gas, expressed in metric tons COfor each gas, combined for aglycol dehydrators with annaverage daily throughput of than 0.4 MMscfd. 
14 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(e)(2)(iv)(D) §98.236(c)(4)(ii)(D) Annual N2O emissions, in metric tons N2O, for the 

dehydrators reported in paragraph (e)(2)(iv)(A) of this section, calculated according to § §98.233(e)(6). 

Report annual CO2, CH4, anN2O emissions at the facility level that resulted from the flaring of process gas, expressed in metric tons COfor each gas, combined for aglycol dehydrators with annaverage daily throughput of than 0.4 MMscfd. 

§98.236(e)(2)(v) and (e)(2)(v)(A) 

§98.236(c)(4)(ii)(C) For dehydrators reported in paragraph (e)(2)(i) of this 

section that were not vented to a flare or regenerator firebox/fire tubes, report the information specified in paragraphs (e)(2)(v)(A) and (e)(2)(v)(B) of this section. (A) Annual CO2 emissions in metric tons CO2, for emissions from all dehydrators reported in paragraph (e)(2)(i) of this section that were not vented to a flare or regenerator firebox/fire tubes, calculated according to § §98.233(e)(2), (e)(4), and (e)(5), where emissions are added together for all such dehydrators. 

Report annual CO2 and CH4emissions at the facility levethat resulted from venting gadirectly to the atmosphere, expressed in metric tons COfor each gas, combined for aglycol dehydrators with annaverage daily throughput of than 0.4 MMscfd. 

§98.236(e)(2)(v)(B) §98.236(c)(4)(ii)(C) Annual CH4 emissions in metric tons CO2, for 

emissions from all dehydrators reported in paragraph (e)(2)(i) of this section that were not vented to a flare or regenerator firebox/fire tubes, calculated according to § §98.233(e)(2), (e)(4), and (e)(5), where emissions are added together for all such dehydrators. 

Report annual CO2 and CH4emissions at the facility levethat resulted from venting gadirectly to the atmosphere, expressed in metric tons COfor each gas, combined for aglycol dehydrators with annaverage daily throughput of than 0.4 MMscfd. 
15 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(e)(3) and (e)(3)(i) 

§98.236(c)(4)(iii) (A) 

(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.) 

Count of desiccant dehydrat

§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). 

§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) 
16 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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). 

§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) 

§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.) 
17 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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.) 

§98.236(e)(3) and (e)(3)(i) 

§98.236(c)(4)(iii)(B) (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. (Annual CO2 emissions for the dehydrators venting to a flare or firebox/fire tubes) 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for all absorbendesiccant dehydrators combined. 

§98.236(e)(3) and (e)(3)(i) 

§98.236(c)(4)(iii)(B) (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. (Annual CH4 emissions for the dehydrators venting to a flare or firebox/fire tubes.) 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for all absorbendesiccant dehydrators combined. 
18 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(e)(3) and (e)(3)(i) 

§98.236(c)(4)(iii)(B) (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. (Annual N2O emissions for the dehydrators venting to a flare or firebox/fire tubes.) 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for all absorbendesiccant dehydrators combined. 

§98.236(e)(3)(ii) §98.236(c)(4)(iii)(B) Annual CO2 emissions in metric tons CO2, for 

emissions from all desiccant dehydrators reported under paragraph (e)(3)(i) of this section that are not venting to a flare or regenerator firebox/fire tubes, calculated according to § §98.233(e)(3), (e)(4), and (e)(5), and summing for all such dehydrators. 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for all absorbendesiccant dehydrators combined. 

§98.236(e)(3)(iii) §98.236(c)(4)(iii)(B) Annual CH4 emissions in metric tons CH4, for 

emissions from all desiccant dehydrators reported in paragraph (e)(3)(i) of this section that are not venting to a flare or regenerator firebox/fire tubes, calculated according to § §98.233(e)(3), (e)(4), and (e)(5), and summing for all such dehydrators. 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, for all absorbendesiccant dehydrators combined. 

Liquids Unloading §98.236(f) Liquids unloading. You must indicate whether well 

venting for liquids unloading occurs at your facility 

§98.236(f) Indicate which methods (as specified in § §98.233(f)) 

were used to calculate emissions. 
19 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(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. 

§98.236(f)(1)(ii) Well tubing diameter and pressure group ID. §98.236(f)(1)(iii) §98.236(c)(5)(i)(B) Plunger lift indicator. Count of plunger lifts. Whet

the selected well from the tudiameter and pressure group combination had a plunger l(yes/no). 

§98.236(f)(1)(iv) §98.236(c)(5)(i)(A) Count of wells vented to the atmosphere for the subbasin/well tubing diameter and pressure grouping. Count of wells vented to the atmosphere for liquids 

unloading. 

§98.236(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. 

§98.236(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. 

§98.236(f)(1)(vii) §98.236(c)(5)(i)(C) Cumulative number of unloadings vented to the 

atmosphere for each well, aggregated across all wells in the sub-basin/well tubing diameter and pressure grouping. 

Cumulative number of unloadings vented to the atmosphere. 
20 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(f)(1)(viii) Annual natural gas emissions, in standard cubic feet, 

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

§98.236(f)(1)(ix) §98.236(c)(5)(i)(H) Annual CO2 emissions, in metric tons CO2, from well 

venting for liquids unloading, calculated according to § §98.233(f)(1) and § §98.233(f)(4). 

Report annual CO2 and CH4emissions, expressed in mettons CO2e for each gas. 

§98.236(f)(1)( x) §98.236(c)(5)(i)(H) Annual CH4 emissions, in metric tons CH4, from well 

venting for liquids unloading, calculated according to § §98.233(f)(1) and § §98.233(f)(4). 

Report annual CO2 and CH4emissions, expressed in mettons CO2e for each gas. 

§98.236(f)(1)(xi) and (f)(1)(xi)(A) 

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

§98.236(f)(1)(xi)(B) §98.236(c)(5)(i)(F) Casing pressure, in pounds per square inch absolute. Casing pressure, in psia, of e

well selected to represent emissions in that tubing size group and pressure group combination that does not haplunger lift. 

§98.236(f)(1)(xi)(C) §98.236(c)(5)(i)(E) Internal casing diameter, in inches. Internal casing diameter or 

internal tubing diameter in inches, where applicable, . . .selected to represent emissiin that tubing size and pressucombination. 

§98.236(f)(1)(xi) (D) 

§98.236(c)(5)(i)(E) Measured depth of the well in feet. . . . well depth of each well, 

feet, selected to represent emissions in that tubing size pressure combination. 
21 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(f)(1)(xi)(E) §98.236(c)(5)(i)(D) Average flow rate of the well venting over the duration 

of the liquids unloading, in standard cubic feet per hour. 

Average flow rate of the measured well venting in cufeet per hour (refer to §98.233(f)(1)(i)(A)). 

§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. 

§98.236(f)(1)(xii) (B) 

§98.236(c)(5)(i)(G) The tubing pressure, in pounds per square inch 

absolute. 

Tubing pressure, in psia, of well selected to represent emissions in a tubing size grand pressure group combinathat has a plunger lift. 

§98.236(f)(1)(xii) (C) 

§98.236(c)(5)(i)(E) The internal tubing diameter, in inches. Internal casing diameter or 

internal tubing diameter in inches, where applicable, . . .selected to represent emissiin that tubing size and pressucombination. 

§98.236(f)(1)(xii) (D) 

§98.236(c)(5)(i)(E) Measured depth of the well, in feet. . . .well depth of each well, 

feet, selected to represent emissions in that tubing size pressure combination. 

§98.236(f)(1)(xii) (E) 

§98.236(c)(5)(i)(D) Average flow rate of the well venting over the duration 

of the liquids unloading, in standard cubic feet per hour. 

Average flow rate of the measured well venting in cufeet per hour (refer to §98.233(f)(1)(i)(A)). 
22 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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 (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 

§98.236(f)(2)(ii) Calculation method. §98.236(f)(2)(iii) §98.236(c)(5)(ii)(B) Plunger lift indicator. Count of plunger lifts. §98.236(f)(2)(iv) §98.236(c)(5)(ii)(A) Number of wells vented to the atmosphere. Count of wells vented to the 

atmosphere for liquids unloading. 

§98.236(f)(2)(v) §98.236(c)(5)(ii)(C) Cumulative number of unloadings vented to the 

atmosphere for each well, aggregated across all wells. 

Cumulative number of unloadings vented to the atmosphere. 

§98.236(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. 

§98.236(f)(2)(vii) §98.236(c)(5)(ii)(E) Annual CO2 emissions, in metric tons CO2, from well 

venting for liquids unloading, calculated according to § §98.233(f)(2) or § §98.233(f)(3), as applicable, and § §98.233(f)(4). 

Report annual CO2 and CH4emissions, expressed in mettons CO2e for each GHG ga

§98.236(f)(2)(viii) §98.236(c)(5)(ii)(E) Annual CH4 emissions, in metric tons CH4, from well 

venting for liquids unloading, calculated according to § §98.233(f)(2) or § §98.233(f)(3), as applicable, and § §98.233(f)(4). 

Report annual CO2 and CH4emissions, expressed in mettons CO2e for each GHG ga
23 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(f)(2)(ix) §98.236(c)(5)(ii) 

(D) 

For wells without plunger lifts, the average internal casing diameter, in inches. 

Average internal casing diameter, in inches, for all wwhere applicable. 

§98.236(f)(2)(x) §98.236(c)(5)(i)(E) For wells with plunger lifts, the average internal tubing 

diameter, in inches. 

Internal casing diameter or internal tubing diameter in inches, where applicable, anwell depth of each well, in fselected to represent emissioin that tubing size and pressucombination. 

Completions and Workovers with Hydraulic Fracturing §98.236(g) You must indicate whether your facility had any gas 

well completions or workovers with hydraulic fracturing during the calendar year.... 

§98.236(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. 

§98.236(g)(2) Well type. §98.236(g)(3) §98.236(c)(6)(i)(A) 

and (C) 

Number of completions or workovers in the category. (A)Total count of completio

in calendar year. (C) Total count of workovercalendar year that flare gas ovent gas to the atmosphere. 

§98.236(g)(4) Calculation method used. 
24 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(g)(5) and (g)(5)(i) 

§98.236(c)(6)(i)(E) and (F) 

(5) If you used Equation W-10A to calculate annual volumetric total gas emissions, then you must report the information specified in paragraphs (g)(5)(i)and (g)(5)(ii) of this section. (i) Cumulative backflow time, in hours, for each subbasin (“Tp” in Equation W-10A). 

(E) When using Equation W10A, total number of days obackflow from all wells duricompletions. (F) When using Equation W10A, total number of days obackflow from all wells duriworkovers. 

§98.236(g)(5)(ii) §98.236(c)(6)(i)(B) 

and (D) 

Measured flowback rate, in standard cubic feet per hour, for each sub-basin (“FRs,p” in Equation W-12A). 

(B) When using Equation W10A, measured flow rate of backflow during well completion in standard cubifeet per hour. (D) When using Equation W10A, measured flow rate of backflow during well workoin standard cubic feet per ho

§98.236(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 W10B). 

§98.236(g)(7) Annual gas emissions, in standard cubic feet (“Es,n” in 

Equation W-10A or W-10B). 
25 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(g)(8) §98.236(c)(6)(i)(I) 

and (J) 

Annual CO2 emissions, in metric tons CO2. (I) Annual CO2 and CH4

emissions that resulted from venting gas directly to the atmosphere, expressed in metric tons CO2e for each gas.(J) Annual CO2, CH4, anN2O emissions that resulted from flares, expressed in metons CO2e for each gas. 

§98.236(g)(9) §98.236(c)(6)(i)(I) 

and (J) 

Annual CH4 emissions, in metric tons CH4. (I) Annual CO2 and CH4

emissions that resulted from venting gas directly to the atmosphere, expressed in metric tons CO2e for each g(J) Annual CO2, CH4, and Nemissions that resulted from flares, expressed in metric toCO2e for each gas. 

§98.236(g)(10) §98.236(c)(6)(i)(J) If the well emissions were vented to a flare, then you 

must report the total N2O emissions, in metric tons N2O. 

(I) Annual CO2 and CH4emissions that resulted from venting gas directly to the atmosphere, expressed in metric tons CO2e for each g(J) Annual CO2, CH4, and Nemissions that resulted from flares, expressed in metric toCO2e for each gas. 

Completions and Workovers without Hydraulic Fracturing §98.236(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.... 
26 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(h), (h)(1), and (h)(1)(i) 

(h)...If the facility had gas well completions or workovers without hydraulic fracturing, then you must report the information specified in paragraphs (h)(1) through (h)(4) of this section, as applicable. (1) For each sub-basin with gas well completions without hydraulic fracturing and without flaring, report the information specified in paragraphs (h)(1)(i) through (h)(1)(vi) of this section. (i) Sub-basin ID 

§98.236(h)(1)(ii) §98.236(c)(6)(ii)(A) Number of well completions that vented gas directly to 

the atmosphere without flaring. 

Total count of completions icalendar year. 

§98.236(h)(1)(iii) §98.236(c)(6)(ii)(C) Total number of hours that gas vented directly to the 

atmosphere during backflow for all completions in the sub-basin category (the sum of all “Tp” for completions that vented to the atmosphere as used in Equation W13B). 

Total number of days of gas venting to the atmosphere during backflow for completion. 

§98.236(h)(1)(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). 

§98.236(h)(1)(v) §98.236(c)(6)(ii)(D) Annual CO2 emissions, in metric tons CO2, that 

resulted from completions venting gas directly to the atmosphere (“Es,p” from Equation W-13B for completions that vented directly to the atmosphere, converted to mass emissions according to §98.233(h)(1)). 

(D) Annual CO2 and CH4emissions that resulted from venting gas directly to the atmosphere, expressed in metric tons CO2e for each g

§98.236(h)(1)(vi) §98.236(c)(6)(ii)(D) Annual CH4 emissions, in metric tons CH4, that 

resulted from completions venting gas directly to the atmosphere (Es,p from Equation W-13B for completions that vented directly to the atmosphere, converted to mass emissions according to §98.233(h)(1)). 

(D) Annual CO2 and CH4emissions that resulted from venting gas directly to the atmosphere, expressed in metric tons CO2e for each g
27 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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. 

§98.236(h)(2)(ii) §98.236(c)(6)(ii)(A) Number of well completions that flared gas. Total count of completions i

calendar year. 

§98.236(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). 

§98.236(h)(2)(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). 

§98.236(h)(2)(v) §98.236(c)(6)(ii)(E) Annual CO2 emissions, in metric tons CO2, that 

resulted from completions that flared gas calculated according to §98.233(h)(2). 

Annual CO2, CH4, and N2O emissions that resulted from flares, expressed in metric toCO2e for each gas. 

§98.236(h)(2)(vi) §98.236(c)(6)(ii)(E) Annual CH4 emissions, in metric tons CH4, that 

resulted from completions that flared gas calculated according to §98.233(h)(2). 

Annual CO2, CH4, and N2O emissions that resulted from flares, expressed in metric toCO2e for each gas. 

§98.236(h)(2)(vii) §98.236(c)(6)(ii)(E) Annual N2O emissions, in metric tons N2O, that 

resulted from completions that flared gas calculated according to §98.233(h)(2). 

Annual CO2, CH4, and N2O emissions that resulted from flares, expressed in metric toCO2e for each gas. 

§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.
28 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(h)(3)(ii) §98.236(c)(6)(ii)(B) Number of workovers that vented gas to the 

atmosphere without flaring . 

Total count of workovers in calendar year that flare gas ovent gas to the atmosphere. 

§98.236(h)(3)(iii) §98.236(c)(6)(ii)(D) Annual CO2 emissions, in metric tons CO2 per year, 

that resulted from workovers venting gas directly to the atmosphere (“Es,wo” in Equation W-13A for workovers that vented directly to the atmosphere, converted to mass emissions as specified in §98.233(h)(1)). 

Annual CO2 and CH4 emissithat resulted from venting gadirectly to the atmosphere, expressed in metric tons COfor each gas. 

§98.236(h)(3)(iv) §98.236(c)(6)(ii)(D) Annual CH4 emissions, in metric tons CH4 per year, 

that resulted from workovers venting gas directly to the atmosphere (“Es,wo” in Equation W-13A for workovers that vented directly to the atmosphere, converted to mass emissions as specified in §98.233(h)(1)). 

Annual CO2 and CH4 emissithat resulted from venting gadirectly to the atmosphere, expressed in metric tons COfor each gas. 

§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)(v) of this section. (i) Sub-basin ID. 

§98.236(h)(4)(ii) §98.236(c)(6)(ii)(B) Number of workovers that flared gas. Total count of workovers in 

calendar year that flare gas ovent gas to the atmosphere. 

§98.236(h)(4)(iii) §98.236(c)(6)(ii)(E) Annual CO2 emissions, in metric tons CO2 per year, 

that resulted from workovers that flared gas calculated as specified in §98.233(h)(2). 

Annual CO2, CH4, and N2O emissions that resulted from flares, expressed in metric toCO2e for each gas. 

§98.236(h)(4)(iv) §98.236(c)(6)(ii)(E) Annual CH4 emissions, in metric tons CH4 per year, 

that resulted from workovers that flared gas, calculated as specified in §98.233(h)(2). 

Annual CO2, CH4, and N2O emissions that resulted from flares, expressed in metric toCO2e for each gas. 
29 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(h)(4)(v) §98.236(c)(6)(ii)(E) Annual N2O emissions, in metric tons N2O per year, 

that resulted from workovers that flared gas calculated as specified in §98.233(h)(2). 

Annual CO2, CH4, and N2O emissions that resulted from flares, expressed in metric toCO2e for each gas. 

Blowdown Vent Stacks §98.236(i) You must indicate whether your facility has 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.... 

§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... 

§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). 

§98.236(i)(1)(ii) Annual CO2 emissions for the equipment type, in 

metric tons CO2, as calculated according to § §98.233(i)(2)(iii). 
30 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(i)(1)(iii) Annual CH4 emissions for the equipment type, in 

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

§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 of all CO2 mass emission values calculated according to § §98.233(i)(3) for all flow meters). 

§98.236(i)(2)(ii) Annual CH4 emissions from all blowdown vent stacks 

at the facility, in metric tons CH4, (the sum of all CH4mass emissions values calculated according to § §98.233(i)(3) for all flow meters). 

Onshore Production Storage Tanks §98.236(j) You must indicate whether your facility sends 

produced oil to atmospheric 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... 

§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... 

§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. 
31 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(j)(1)(ii) Calculation method used, and name of the software 

package used if using Calculation Method 1. 

§98.236(j)(1)(iii) §98.236(c)(8)(i)(F) The total annual gas-liquid separator oil volume that is 

sent to applicable onshore production storage tanks, in barrels. 

Total volume of oil from all wellhead separators sent to tank(s) in barrels per year. 

§98.236(j)(1)(iv) §98.236(c)(8)(i)(B) The average gas-liquid separator temperature, in 

degrees. 

Estimated average separator temperature, in degrees Fahrenheit, 

§98.236(j)(1)(v) §98.236(c)(8)(i)(B) The average gas-liquid separator pressure, in pounds 

per square inch gauge. 

Estimated average separator estimated average pressure, psig. 

§98.236(j)(1)(vi) §98.236(c)(8)(i)(C) The average sales oil or stabilized oil API gravity, in 

degrees. 

Estimated average sales oil stabilized API gravity, in degrees. 

§98.236(j)(1)(vii) §98.236(c)(8)(i)(I) The minimum and maximum concentration (mole 

fraction) of CO2 in flash gas from onshore production storage tanks. 

Range of concentrations of flash gas, CH4 and CO2.

§98.236(j)(1)(viii) §98.236(c)(8)(i)(I) The minimum and maximum concentration (mole 

fraction) of CH4 in flash gas from onshore production storage tanks. 

Range of concentrations of flash gas, CH4 and CO2.

§98.236(j)(1)(ix) §98.236(c)(8)(i)(A) The number of wells sending oil to gas-liquid 

separators or directly to atmospheric tanks. 

Number of wellhead separatsending oil to atmospheric tanks. 

§98.236(j)(1)(x) §98.236(c)(8)(i)(D) The number of atmospheric tanks. Count of hydrocarbon tanks 

well pads. 

§98.236(j)(1)(xi) §98.236(c)(8)(i)(E) An estimate of the number of atmospheric tanks, not on 

well-pads, receiving your oil. 

Best estimate of count of stotanks not at well pads receivyour oil. 
32 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(j)(1)(xii) (A) 

§98.236(c)(8)(i)(G) (xii) If any emissions from of the atmospheric tanks at 

your facility were controlled with vapor recovery systems, then you must indicate and report the information specified in paragraphs (j)(1)(xii)(A) through (j)(1)(xii)(E) of this section. (A) The number of atmospheric tanks that control emissions with vapor recovery systems. 

Count of tanks with emissiocontrol measures, either vaprecovery system or flaring, ftanks at well pads. 

§98.236(j)(1)(xii) (B) 

§98.236(c)(8)(i)(K) Total CO2 mass, in metric tons CO2, that was recovered 

during the calendar year using a vapor recovery system. 

Annual CO2 and CH4 gas quantities that were recovereexpressed in metric tons COfor each gas, for all wellhead gas-liquid separators or stortanks using Calculation Methodology 1, and for all wellhead gas-liquid separatoor storage tanks using Calculation Methodology 2 §98.233(j). 

§98.236(j)(1)(xii) (C) 

§98.236(c)(8)(i)(K) Total CH4 mass, in metric tons CH4, that was recovered 

during the calendar year using a vapor recovery system. 

Annual CO2 and CH4 gas quantities that were recovereexpressed in metric tons COfor each gas, for all wellhead gas-liquid separators or stortanks using Calculation Methodology 1, and for all wellhead gas-liquid separatoor storage tanks using Calculation Methodology 2 §98.233(j). 
33 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(j)(1)(xii) (D) 

§98.236(c)(8)(i)(J) Annual CO2 emissions, in metric tons CO2, from 

atmospheric tanks equipped with vapor recovery systems. 

Annual CO2 and CH4 emissithat resulted from venting gato the atmosphere, expressed metric tons CO2e for each gfor all wellhead gas-liquid separators or storage tanks using Calculation Methodol1, and for all wellhead gasliquid separators or storage tanks using Calculation Methodology 2 of §98.233(j

§98.236(j)(1)(xii)(E) §98.236(c)(8)(i)(J) Annual CH4 emissions, in metric tons CH4, from 

atmospheric tanks equipped with vapor recovery systems. 

Annual CO2 and CH4 emissithat resulted from venting gato the atmosphere, expressed metric tons CO2e for each gfor all wellhead gas-liquid separators or storage tanks using Calculation Methodol1, and for all wellhead gasliquid separators or storage tanks using Calculation Methodology 2 of §98.233(j

§98.236(j)(1)(xiii) and (j)(1)(xiii)(A) 

§98.236(c)(8)(i)(G) (xiii) If any atmospheric tanks at your facility vented 

gas directly to the atmosphere without using a vapor recovery system or without flaring, then you must report the information specified in paragraphs (j)(1)(xiii)(A) through (j)(1)(xiii)(C) of this section. (A) The number of atmospheric tanks that vented gas directly to the atmosphere without using a vapor recovery system or without flaring. 

Count of tanks with emissiocontrol measures, either vaprecovery system or flaring, ftanks at well pads. 
34 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(j)(1)(xiii) (B) 

§98.236(c)(8)(i)(J) Annual CO2 emissions, in metric tons CO2, that 

resulted from venting gas directly to the atmosphere. 

Annual CO2 and CH4 emissithat resulted from venting gato the atmosphere, expressed metric tons CO2e for each gfor all wellhead gas-liquid separators or storage tanks using Calculation Methodol1, and for all wellhead gasliquid separators or storage tanks using Calculation Methodology 2 of §98.233(j

§98.236(j)(1)(xiii) (C) 

§98.236(c)(8)(i)(J) Annual CH4 emissions, in metric tons CH4, that 

resulted from venting gas directly to the atmosphere. 

Annual CO2 and CH4 emissithat resulted from venting gato the atmosphere, expressed metric tons CO2e for each gfor all wellhead gas-liquid separators or storage tanks using Calculation Methodol1, and for all wellhead gasliquid separators or storage tanks using Calculation Methodology 2 of §98.233(j

§98.236(j)(1)(xiv) and (j)(1)(xiv)(A) 

§98.236(c)(8)(i)(G) (xiv) If you controlled emissions from any atmospheric 

tanks at your facility with one or more flares, then you must report the information specified in paragraphs (j)(1)(xiv)(A) through (j)(1)(xiv)(D) of this section. (A) The number of atmospheric tanks that controlled emissions with flares. 

Count of tanks with emissiocontrol measures, either vaprecovery system or flaring, ftanks at well pads. 
35 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(j)(1)(xiv) (B) 

§98.236(c)(8)(i)(L) Annual CO2 emissions, in metric tons CO2, from 

atmospheric tanks that controlled emissions with one or more flares. 

Annual CO2, CH4, and N2O emissions that resulted from flaring gas, expressed in metons CO2e for each gas, for awellhead gas-liquid separatoor storage tanks using Calculation Methodology 1, and for all wellhead gas-liquseparators or storage tanks using Calculation Methodol2 of §98.233(j). 

§98.236(j)(1)(xiv(C) §98.236(c)(8)(i)( L) Annual CH4 emissions, in metric tons CH4, from 

atmospheric tanks that controlled emissions with one ore more flares. 

Annual CO2, CH4, and N2O emissions that resulted from flaring gas, expressed in metons CO2e for each gas, for awellhead gas-liquid separatoor storage tanks using Calculation Methodology 1, and for all wellhead gas-liquseparators or storage tanks using Calculation Methodol2 of §98.233(j). 

§98.236(j)(1)(xiv) (D) 

§98.236(c)(8)(i)(L) Annual N2O emissions, in metric tons N2O, from 

atmospheric tanks that controlled emissions with one or more flares. 

(I) Annual CO2, CH4, and N2emissions that resulted from flaring gas, expressed in metons CO2e for each gas, for awellhead gas-liquid separatoor storage tanks using Calculation Methodology 1, and for all wellhead gas-liquseparators or storage tanks using Calculation Methodol2 of §98.233(j). 
36 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(j)(2) and (j)(2)(i) and (j)(2)(i)(A) 

§98.236(c)(8)(iii)(C) (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. 

Total volume of oil productiin barrels per year. 

§98.236(j)(2)((i)(B) §98.236(c)(8)(iii) 

(D) 

An estimate of the fraction of oil throughput reported in paragraph (j)(2)(i)(A) sent to atmospheric tanks in the basin that controlled emissions with flares. 

Best estimate of fraction of production sent to tanks with assumed control measures: either vapor recovery system flaring of tank vapors. 

§98.236(j)(2)((i)(C) §98.236(c)(8)(iii) 

(D) 

An estimate of the fraction of oil throughput reported in paragraph (j)(2)(i)(A) sent to atmospheric tanks in the basin that controlled emissions with vapor recovery systems. 

Best estimate of fraction of production sent to tanks with assumed control measures: either vapor recovery system flaring of tank vapors. 

§98.236(j)(2)((i)(D) §98.236(c)(8)(iii)(E) The number of atmospheric tanks, in the basin. Count of hydrocarbon tanks 

well pads. 

§98.236(j)(2)((i)(E) §98.236(c)(8)(iii) 

(A) 

The number of wells with gas-liquid separators (“Count” from Equation W-15 of this subpart), in the basin. 

Number of wellhead separat

§98.236(j)(2)((i)(F) §98.236(c)(8)(iii)(B) The number of wells without gas-liquid separators 

(“Count” from Equation W-15 of this subpart), in the basin. 

Number of wells without wellhead separators. 
37 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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) Subbasin ID. 

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

did not control emissions with flares. 

§98.236(j)(2)(ii)(C) §98.236(c)(8)(iii)(F) Annual CO2 emissions, in metric tons CO2 from 

atmospheric tanks in the sub-basin that did not control emissions with flares, calculated using Equation W-15 of this subpart. 

Annual CO2 and CH4 emissithat resulted from venting gato the atmosphere, expressed metric tons CO2e for each gat the sub-basin level for Calculation Methodology 5 §98.233(j). 

§98.236(j)(2)(ii)(D) §98.236(c)(8)(iii)(F) Annual CH4 emissions, in metric tons CH4 from 

atmospheric tanks in the sub-basin that vent gas directly to the atmosphere, calculated using Equation W-15 of this subpart. 

Annual CO2 and CH4 emissithat resulted from venting gato the atmosphere, expressed metric tons CO2e for each gat the sub-basin level for Calculation Methodology 5 §98.233(j). 

§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. 

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

controlled emissions with flares. 
38 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(j)(2)(iii)(C) §98.236(c)(8)(iii) 

(H) 

Annual CO2 emissions, in metric tons CO2 from atmospheric tanks that controlled emissions with flares. 

Annual CO2, CH4, and N2O emissions that resulted from flaring gas, expressed in metons CO2e for each gas, at thsub-basin level for CalculatiMethodology 5 of §98.233(j

§98.236(j)(2)(iii)(D) §98.236(c)(8)(iii) 

(H) 

Annual CH4 emissions, in metric tons CH4 from atmospheric tanks that controlled emissions with flares. 

Annual CO2, CH4, and N2O emissions that resulted from flaring gas, expressed in metons CO2e for each gas, at thsub-basin level for CalculatiMethodology 5 of §98.233(j

§98.236(j)(2)(iii)(E) §98.236(c)(8)(iii) 

(H) 

Annual N2O emissions, in metric tons from atmospheric tanks that controlled emissions with flares. 

Annual CO2, CH4, and N2O emissions that resulted from flaring gas, expressed in metons CO2e for each gas, at thsub-basin level for CalculatiMethodology 5 of §98.233(j

§98.236(j)(3) and (j)(3)(i) 

§98.236(c)(8)(iv)(A) (3) If any gas-liquid separator liquid dump values did 

not close properly during the calendar year, then you must report the information specified in paragraphs (j)(3)(i) through (j)(3)(iv) of this section. (i) The total number of gas-liquid separators whose liquid dump valves did not close properly during the calendar year. 

Count of wellhead separatorthat dump valve factor is applied. 

§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). 
39 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(j)(3)(iii) §98.236(c)(8)(iv)(B) Annual CO2 emissions, in metric tons CO2, that 

resulted from the dump valves on gas-liquid separators not closing properly during the calendar year, calculated using Equation W-16 of this subpart. 

Annual CO2 and CH4 emissithat resulted from venting gato the atmosphere, expressed metric tons CO2e for each gat the sub-basin level for improperly functioning dumvalves. 

§98.236(j)(3)(iv) §98.236(c)(8)(iv)(B) Annual CH4 emissions, in metric tons CH4, that 

resulted from the dump valves on gas-liquid separators not closing properly during the calendar year, calculated using Equation W-16 of this subpart. 

Annual CO2 and CH4 emissithat resulted from venting gato the atmosphere, expressed metric tons CO2e for each gat the sub-basin level for improperly functioning dumvalves. 

Transmission Storage Tanks §98.236(k) You must indicate whether your facility contains any 

transmission storage tanks.... 

§98.236(k), (k)(1), and (k)(1)(i) 

§98.236(c)(9)(iii) (k) ...If your facility contains at least one transmission 

storage tank, then you must report the information specified in paragraphs (k)(1) through (k)(3) of this section for each transmission storage tank vent stack. (1) For each transmission storage tank vent stack report the information specified in (k)(1)(i) through (k)(1)(iv) of this section. (i) The unique name or ID number for the transmission storage tank vent stack. 

A unique name or ID numbefor the vent stack monitored according to 40 CFR §98.233(k). 

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

occurred. 

§98.236(k)(1)(iii) Indicator whether scrubber dump valve leakage 

occurred for the transmission storage tank vent. 

§98.236(k)(1)(iv) Indicator if there is a flare attached to the transmission 

storage tank vent stack. 
40 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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. 

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

continuous flow measurement device) in standard cubic feet per hour. 

§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). 

§98.236(k)(2)(iv) §98.236(c)(9)(i) Annual CO2 emissions, in metric tons CO2, that 

resulted from venting gas directly to the atmosphere, calculated according to § §98.233(k)(1) through (k)(3). 

For each vent stack, report annual CO2 and CH4 emissiothat resulted from venting gadirectly to the atmosphere, expressed in metric tons COfor each gas. 

§98.236(k)(2)(v) §98.236(c)(9)(i) Annual CH4 emissions, in metric tons CH4, that 

resulted from venting gas directly to the atmosphere, calculated according to § §98.233(k)(1) through (k)(3). 

For each vent stack, report annual CO2 and CH4 emissiothat resulted from venting gadirectly to the atmosphere, expressed in metric tons COfor each gas. 
41 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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. 

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

continuous flow measurement device) in standard cubic feet per hour. 

§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). 

§98.236(k)(3)(iv) §98.236(c)(9)(ii) Annual CO2 emissions, in metric tons CO2, that 

resulted from flaring gas, calculated according to § §98.233(k)(4). 

For each transmission storagtank, report annual CO2, CHand N2O emissions that resufrom flaring process gas from the transmission storage tankexpressed in metric tons COfor each gas. 

§98.236(k)(3)(v) §98.236(c)(9)(ii) Annual CH4 emissions, in metric tons CH4, that 

resulted from flaring gas, calculated according to § §98.233(k)(4). 

For each transmission storagtank, report annual CO2, CHand N2O emissions that resufrom flaring process gas from the transmission storage tankexpressed in metric tons COfor each gas. 
42 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(k)(3)(vi) §98.236(c)(9)(ii) Annual N2O emissions, in metric tons N2O, that 

resulted from flaring gas, calculated according to § §98.233(k)(4). 

For each transmission storagtank, report annual CO2, CHand N2O emissions that resufrom flaring process gas from the transmission storage tankexpressed in metric tons COfor each gas. 

Well Testing §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.... 

§98.236(l), (l)(1), and (l)(1)(i) 

§98.236(c)(10)(i) (l)...If you performed well testing that resulted in 

vented or flared emissions during the calendar year, then you must report the information specified in paragraphs (l)(1) through (l)(4) as applicable. (1) If you used Equation W-17A to calculate annual volumetric natural gas emissions at actual conditions from oil wells and the emissions are not vented to a flare, then you must report the information specified in paragraphs (l)(1)(i) through (l)(1)(vi) of this section. (i) Number of wells tested in the calendar year. 

Number of wells tested per basin in calendar year. 

§98.236(l)(1)(ii) §98.236(c)(10)(iii) Average number of well testing days in the calendar 

year. 

Average number of days the well is tested in a basin. 

§98.236(l)(1)(iii) §98.236(c)(10)(ii) Average gas to oil ratio for well(s) tested, in cubic feet 

of gas per barrel of oil. 

Average gas to oil ratio for each basin. 

§98.236(l)(1)(iv) Average flow rate for well(s) tested, in barrels of oil 

per day. 
43 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(l)(1)(v) §98.236(c)(10)(iv) Annual CO2 emissions, in metric tons CO2, as 

calculated according to § §98.233(l). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from well testing venting. 

§98.236(l)(1)(vi) §98.236(c)(10)(iv) Annual CH4 emissions, in metric tons CH4, calculated 

according to § §98.233(l). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from well testing venting. 

§98.236(l)(2) and (l)(2)(i) 

§98.236(c)(10)(i) (2) If you used Equation W-17A to calculate annual 

volumetric natural gas emissions at actual conditions from oil wells and the emissions are vented to a flare, then you must report the information specified in paragraphs (l)(2)(i) through (l)(2)(vii) of this section. (i) Number of wells tested in the calendar year. 

Number of wells tested per basin in calendar year. 

§98.236(l)(2)(ii) §98.236(c)(10)(iii) Average number of well testing days in the calendar 

year. 

Average number of days the well is tested in a basin. 

§98.236(l)(2)(iii) §98.236(c)(10)(ii) Average gas to oil ratio for well(s) tested, in cubic feet 

of gas per barrel of oil. 

Average gas to oil ratio for each basin. 

§98.236(l)(2)(iv) Average flow rate for well(s) tested, in barrels of oil 

per day. 

§98.236(l)(2)(v) §98.236(c)(10)(iv) Annual CO2 emissions, in metric tons CO2, calculated 

according to § §98.233(l). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from well testing venting. 

§98.236(l)(2)(vi) §98.236(c)(10)(iv) Annual CH4 emissions, in metric tons CH4, calculated 

according to § §98.233(l). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from well testing venting. 
44 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(l)(2)(vii) §98.236(c)(10)(iv) Annual N2O emissions, in metric tons N2O, calculated 

according to § §98.233(l). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from well testing venting. 

§98.236(l)(3) and (l)(3)(i) 

§98.236(c)(10)(i) (3) If you used Equation W-17B to calculate annual 

volumetric natural gas emissions at actual conditions from gas wells and the emissions were not vented to a flare, then you must report the information specified in paragraphs (l)(3)(i) through (l)(3)(v) of this section. (i) Number of wells tested in the calendar year. 

Number of wells tested per basin in calendar year. 

§98.236(l)(3)(ii) §98.236(c)(10)(iii) Average number of well testing days in the calendar 

year. 

Average number of days the well is tested in a basin. 

§98.236(l)(3)(iii) Average annual production rate for well(s) tested in 

actual cubic feet per day. 

§98.236(l)(3)(iv) §98.236(c)(10)(iv) Annual CO2 emissions in metric tons CO2, calculated 

according to § §98.233(l). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from well testing venting. 

§98.236(l)(3)(v) §98.236(c)(10)(iv) Annual CH4 emissions in metric tons CH4, calculated 

according to § §98.233(l). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from well testing venting. 

§98.236(l)(4) and (l)(4)(i) 

§98.236(c)(10)(i) (4) If you used Equation W-17B to calculate annual 

volumetric natural gas emissions at actual conditions from gas wells and the emissions were vented to a flare, then you must report the information specified in paragraphs (l)(4)(i) through (l)(4)(vi) of this section. (i) Number of wells tested in calendar year. 

Number of wells tested per basin in calendar year. 
45 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(l)(4)(ii) §98.236(c)(10)(iii) Average number of well testing days in the calendar 

year. 

Average number of days the well is tested in a basin. 

§98.236(l)(4)(iii) Average annual production rate for well(s) tested, in 

actual cubic feet per day. 

§98.236(l)(4)(iv) §98.236(c)(10)(v) Annual CO2 emissions,, in metric tons CO2, calculated 

according to § §98.233(l). 

Report annual CO2, CH4, and N2O emissions at the facility level, expressed in metric toCO2e for each gas, emissionfrom well testing flaring. 

§98.236(l)(4)(v) §98.236(c)(10)(v) Annual CH4 emissions, in metric tons CH4, calculated 

according to § §98.233(l). 

Report annual CO2, CH4, and N2O emissions at the facility level, expressed in metric toCO2e for each gas, emissionfrom well testing flaring. 

§98.236(l)(4)(vi) §98.236(c)(10)(v) Annual N2O emissions, in metric tons N2O, calculated 

according to § §98.233(l). 

Report annual CO2, CH4, and N2O emissions at the facility level, expressed in metric toCO2e for each gas, emissionfrom well testing flaring. 

Associated Natural Gas §98.236(m) You must indicate whether any associated gas was 

vented or flared during the calendar year.... 

§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. 

§98.236(m)(2) Indicator whether any associated gas was vented 

directly to the atmosphere without flaring. 

§98.236(m)(3) Indicator whether any associated gas was flared. 
46 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(m)(4) §98.236(c)(11)(ii) Average gas to oil ratio, in standard cubic feet of gas 

per barrel of oil (average of the “GOR” values used in Equation W-18 of this subpart). 

Average gas to oil ratio for each basin. 

§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 W18 of this subpart). 

§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). 

§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). 

§98.236(m)(8) and (m)(8)(i) 

§98.236(c)(11)(i) (8) If you had associated gas emissions directly to the 

atmosphere without flaring, then you must report the information specified in paragraphs (m)(8)(i) through (m)(8)(iii) of this section for each sub-basin. (i) Total number of wells for which associated gas was vented directly to the atmosphere without flaring. 

Number of wells venting or flaring associated natural gaa calendar year. 

§98.236(m)(8)(ii) §98.236(c)(11)(iii) Annual CO2 emissions, in metric tons CO2, calculated 

according to § §98.233(m)(3) and (m)(4). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from associated natural gas ventin
47 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(m)(8)(iii) §98.236(c)(11)(iii) Annual CH4 emissions, in metric tons CH4, calculated 

according to § §98.233(m)(3) and (m)(4). 

Report annual CO2 and CH4emissions at the facility leveexpressed in metric tons COfor each gas, emissions from associated natural gas ventin

§98.236(m)(9) and (m)(9)(i) 

§98.236(c)(11)(i) (9) If you had associated gas emissions that were 

flared, then you must report the information specified in paragraphs (m)(9)(i) through (m)(9)(iv) of this section for each sub-basin.(i) Total number of wells for which associated gas was flared. 

Number of wells venting or flaring associated natural gaa calendar year. 

§98.236(m)(9)(ii) §98.236(c)(11)(iv) Annual CO2 emissions, in metric tons CO2, calculated 

according to § §98.233(m)(5). 

Report annual CO2, CH4, and N2O emissions at the facility level, expressed in metric toCO2e for each gas, emissionfrom associated natural gas flaring. 

§98.236(m)(9)(iii) §98.236(c)(11)(iv) Annual CH4 emissions, in metric tons CH4, calculated 

according to § §98.233(m)(5). 

Report annual CO2, CH4, and N2O emissions at the facility level, expressed in metric toCO2e for each gas, emissionfrom associated natural gas flaring. 

§98.236(m)(9)(iv) §98.236(c)(11)(iv) Annual N2O emissions, in metric tons N2O, calculated 

according to § §98.233(m)(5). 

Report annual CO2, CH4, and N2O emissions at the facility level, expressed in metric toCO2e for each gas, emissionfrom associated natural gas flaring. 

Flare Stacks§98.236(n) You must indicate if your facility contains any flare 

stacks. 
48 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(n) and (n)(1) 

§98.236(c)(12)(x) (n)...You must report the information specified in 

paragraphs (n)(1) through (n)(13) of this section for each flare stack at your facility, and for each industry segment applicable to your facility. (1) Unique name or ID for the flare stack. For the onshore petroleum and natural gas production industry segment, a different name or ID may be used for a single flare stack for each location where it operates at in a given calendar year. 

For the natural gas processinindustry segment, a unique name or ID number for the fstack. 

§98.236(n)(2) §98.236(c)(12)(i) Indicate whether the flare stack has a continuous flow 

measurement device. 

Whether flare has a continuoflow monitor. 

§98.236(n)(3) §98.236(c)(12)(iv) Indicate whether the flare stack has a continuous gas 

composition analyzer on feed gas to the flare. 

Whether flare has a continuogas analyzer. 

§98.236(n)(4) §98.236(c)(12)(ii) Volume of gas sent to the flare in standard cubic feet 

(“Va” in Equation W-19 of this subpart). 

Volume of gas sent to flare icubic feet per year. 

§98.236(n)(5) §98.236(c)(12)(iii) Fraction of the feed gas sent to an un-lit flare (“Zu” in 

Equation W-19 of this subpart). 

Percent of gas sent to un-lit flare determined by engineeestimate and process knowledge based on best available data and operating records. 

§98.236(n)(6) §98.236(c)(12)(v) Flare combustion efficiency expressed as the fraction 

of gas combusted by a burning flare. 

Flare combustion efficiency

§98.236(n)(7) Mole fraction of CH4 in the feed gas to the flare 

(“XCH4” in Equation W-19 of this subpart). 

§98.236(n)(8) Mole fraction of CO2 in the feed gas to the flare 

(“XCO2” in Equation W-20 of this subpart). 
49 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(n)(9) §98.236(c)(12)(vii) 

and (viii) 

Annual CO2 emissions, in metric tons CO2 (refer to Equation W-20 of this subpart). 

(vii) Report uncombusted Cemissions in metric tons CO(refer to Equation W-20 of §98.233) (viii) Report combusted COemissions, in metric tons CO(refer to Equation W-21 of §98.233). 

§98.236(n)(10) §98.236(c)(12)(vi) Annual CH4 emissions, in metric tons CH4 (refer to 

Equation W-19 of this subpart). 

Report uncombusted CH4emissions, in metric tons CO(refer to Equation W-19 of §98.233). 

§98.236(n)(11) §98.236(c)(12)(ix) Annual N2O emissions, in metric tons N2O (refer to 

Equation W-40 of this subpart). 

Report N2O emissions, in metric tons CO2e. 

§98.236(n)(12) §98.236(c)(12)(xi) Indicate whether a CEMS was used to measure 

emissions from the flare. If a CEMS was used to measure emissions from the flare, then you are not required to report N2O and CH4 emissions for the flare stack. 

In the case that a CEMS is uto measure CO2 emissions fothe flare stack, indicate that CEMS was used in the annureport and report the combuCO2 and uncombusted CO2 combined number. 

Centrifugal Compressors§98.236(o) You must indicate whether your facility has 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. 

§98.236(o)(1)(ii) §98.236(c)(13)(i)(F) Hours in operating-mode. Total time the compressor is 

operating in hours. 
50 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(o)(1)(iii) §98.236(c)(13)(iii)(

A) 

Hours in not-operating-depressurized-mode. Total time in hours the 

compressor is in shutdown, depressurized mode. 

§98.236(o)(1)(iv) Indicate whether the compressor was measured in 

operating-mode. 

§98.236(o)(1)(v) Indicate whether the compressor was measured in notoperating-depressurized-mode. §98.236(o)(1)(vi) Indicate whether any compressor sources are part of a 

manifolded group of compressor sources. 

§98.236(o)(1)(vii) Indicate whether any compressor sources are routed to 

a flare. 

§98.236(o)(1)(viii) Indicate whether any compressor sources have vapor 

recovery. 

§98.236(o)(1)(ix) Indicate whether emissions from any compressor 

sources are captured for fuel use or are routed to a thermal oxidizer. 

§98.236(o)(1)(x) Indicate whether the compressor has blind flanges 

installed. 

§98.236(o)(1)(xi) Indicate whether the compressor has wet or dry seals. §98.236(o)(1)(xii) §98.236(c)(13)(i)(A) If the compressor has wet seals, the number of wet 

seals. 

Number of wet seals connecto the degassing vent. 

§98.236(o)(1)(xiii) Compressor power rating (hp). §98.236(o)(1)(xiv) Year compressor was installed. §98.236(o)(1)(xv) Compressor model name and description. §98.236(o)(1)(xvi) Date of last maintenance shutdown that compressor 

was depressurized. 
51 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(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. 

§98.236(o)(2)(ii) Centrifugal compressor source (wet seal, isolation 

valve, or blowdown valve). 

§98.236(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. 

§98.236(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. 

§98.236(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. 

§98.236(o)(2)(vi) Indicate whether continuous leak measurements as 

identified in § §98.233(o)(3) or (o)(5) were conducted on the emission vent. 

§98.236(o)(2)(vii) and (o)(2)(vii)(A) 

§98.236(c)(13)(iv) Report emissions as specified in paragraphs 

(o)(2)(vii)(A) and (o)(2)(vii)(B) of this section for the emission vent. For emission vents associated with individual compressor sources that use an as found leak measurement(s), calculate emissions by summing all emissions from all compressor mode-source combinations for the emission vent. (A) Annual CO2 emissions, in metric tons CO2. 

Report total annual compresemissions from all modes of operation in metric tons of CO2e for each gas. 
52 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(o)(2)(vii) (B) 

§98.236(c)(13)(iv) Annual CH4 emissions, in metric tons CH4. Report total annual compres

emissions from all modes of operation in metric tons of CO2e for each gas. 

§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. 

§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. 

§98.236(o)(3)(i)(B) Sample date. §98.236(o)(3)(i)(C) Leak measurement method. §98.236(o)(3)(i)(D) Measured flow rate, in standard cubic feet per hour. §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. 

§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. 
53 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(o)(3)(ii)(B) §98.236(c)(13)(iii) 

(B) 

The compressor mode-source combination reporter emission factor, in standard cubic feet per hour (EFm,sin Equation W-24). 

(B) Reporter emission factor for isolation valve emissions shutdown, depressurized moin cubic feet per hour (refer Equation W-24 of §98.233). 

§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 (Countm in Equation W-24). 

§98.236(o)(3)(ii)(D) Indicate whether the compressor mode-source 

combination reporter emission factor is facility-specific or corporate. 

§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. 

§98.236(o)(4)(ii) Measured volume of flow during the reporting year, in 

million standard cubic feet. 

§98.236(o)(5) and (o)(5)(i) 

§98.236(c)(13)(v) (A) 

(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. 

Count of compressors. 
54 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(o)(5)(ii) §98.236(c)(13)(v) 

(B) 

Annual CO2 emissions, in metric tons CO2, from centrifugal compressors with wet seal oil degassing vents.

Report annual emissions in metric tons of CO2e for each gas (refer to Equation W-25 §98.233) collectively. 

§98.236(o)(5)(iii) §98.236(c)(13)(v) 

(B) 

Annual CH4 emissions, in metric tons CH4, from centrifugal compressors with wet seal oil degassing vents. 

Report annual emissions in metric tons of CO2e for each gas (refer to Equation W-25 §98.233) collectively. 

Reciprocating Compressors§98.236(p) You must indicate whether your facility has 

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. 

§98.236(p)(1)(ii) §98.236(c)(14)(i)(B) Hours in operating-mode. Total time in hours the 

reciprocating compressor is operating mode. 

§98.236(p)(1)(iii) §98.236(c)(14)(ii) 

(A) 

Hours in standby-depressurized-mode. Total time in hours the 

compressor is in standby, pressurized mode. 

§98.236(p)(1)(iv) §98.236(c)(14)(iii) 

(A) 

Hours in not-operating-depressurized-mode. Total time the compressor is 

not operating, depressurized mode. 

§98.236(p)(1)(v) Indicate whether the compressor was measured in 

operating-mode. 

§98.236(p)(1)(vi) Indicate whether the compressor was measured in 

standby-depressurized-mode. 

§98.236(p)(1)(vii) Indicate whether the compressor was measured in notoperating-depressurized-mode. 
55 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(p)(1)(viii) Indicate whether any compressor sources are part of a 

manifolded group of compressor sources. 

§98.236(p)(1)(ix) Indicate whether any compressor sources are routed to 

a flare. 

§98.236(p)(1)(x) Indicate whether any compressor sources have vapor 

recovery. 

§98.236(p)(1)(xi) Indicate whether emissions from any compressor 

sources are captured for fuel use or are routed to a thermal oxidizer. 

§98.236(p)(1)(xii) Indicate whether the compressor has blind flanges 

installed. 

§98.236(p)(1)(xiii) Compressor power rating (hp). §98.236(p)(1)(xiv) Year compressor was installed. §98.236(p)(1)(xv) Compressor model name and description. §98.236(p)(1)(xvi) Date of last maintenance shutdown for rod packing 

replacement. 

§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. 

§98.236(p)(2)(ii) Reciprocating compressor source (isolation valve, 

blowdown valve, or rod packing). 

§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. 
56 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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. 

§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. 

§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. 

§98.236(p)(2)(vii) and (p)(2)(vii)(A) 

§98.236(c)(14)(iv) (vii) Report emissions as specified in paragraphs 

(p)(2)(vii)(A) through (p)(2)(vii)(B) of this section for the emission vent. For emission vents associated with 

individual compressor sources that use an as found leak measurement(s), calculate emissions by summing all emissions from all compressor mode-source combinations for the emission vent. (A) Annual CO2 emissions, in metric tons CO2. 

Report total annual compresemissions from all modes of operation in metric tons of CO2e for each gas. 

§98.236(p)(2)(vii) (B) 

§98.236(c)(14)(iv) Annual CH4 emissions, in metric tons CH4. Report total annual compres

emissions from all modes of operation in metric tons of CO2e for each gas. 

§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. 
57 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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. 

§98.236(p)(3)(i)(B) Sample date. §98.236(p)(3)(i)(C) Leak measurement method. §98.236(p)(3)(i)(D) Measured flow rate, in standard cubic feet per hour. §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. 

§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. 

§98.236(p)(3)(ii)(B) §98.236(c)(14)(iii) 

(B) 

The compressor mode-source combination reporter emission factor, in standard cubic feet per hour (EFm,sin Equation W-28). 

Reporter emission factor for isolation valve emissions in operating, depressurized moin cubic feet per hour (refer Equation W-28 of §98.233). 
58 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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 (Countm in Equation W-28). 

§98.236(p)(3)(ii)(D) Indicate whether the compressor mode-source 

combination reporter emission factor is facility-specific or corporate. 

§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. 

§98.236(p)(4)(ii) Measured volume of flow during the reporting year, in 

million standard cubic feet. 

§98.236(p)(5) and (p)(5)(i) 

§98.236(c)(14)(v) (A) 

(5) Reciprocating compressors in onshore petroleum and natural gas production must report the information specified in paragraphs (p)(5)(i) through (p)(5)(iii) of this section. (i) Number of reciprocating compressors. 

Count of compressors. 

§98.236(p)(5)(ii) §98.236(c)(14)(v) 

(B) 

Annual CO2 emissions, in metric tons CO2, from reciprocating compressors. 

Report annual emissions in metric tons of CO2e for each gas collectively (refer to Equation W-29 of §98.233). 

§98.236(p)(5)(iii) §98.236(c)(14)(v) 

(B) 

Annual CH4 emissions, in metric tons CH4, from reciprocating compressors. 

Report annual emissions in metric tons of CO2e for each gas collectively (refer to Equation W-29 of §98.233). 
59 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

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. 

§98.236(q)(1)(ii) §98.236(c)(16)(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. 

Number of years over which T-D transfer stations will be monitored at least once. 

§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.
60 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(q)(2)(ii) §98.236(c)(15)(i)(A) Total number of the survey component type that were 

identified as leaking in the calendar year (“xp” in Equation W-30 of this subpart for the component type). 

Total count of leaks found in each complete survey listed date of survey and each component type for which this a leaker emission factor in Tables W-2, W-3, W-4, W-5W-6, and W-7 of this subpar

§98.236(q)(2)(iii) Average time the surveyed components were found 

leaking and operational, in hours (average of Tp,z from Equation W-30 of this subpart for the component type). 

§98.236(q)(2)(iv) §98.236(c)(15)(i)(C) Annual CO2 emissions, in metric tons CO2, for the 

component type. 

Annual CO2 and CH4 emissiin metric tons CO2e for each gas (refer to Equation W-30of §98.233), by component t

§98.236(q)(2)(v) §98.236(c)(15)(i)(C) Annual CH4 emissions, in metric tons CH4, for the 

component type. 

Annual CO2 and CH4 emissiin metric tons CO2e for each gas (refer to Equation W-30of §98.233), by component t

§98.236(q)(3) and (q)(3)(i) 

§98.236(c)(16)(iii) (3) Natural gas distribution facilities must report the 

information specified in paragraphs (q)(3)(i) through (q)(3)(viii) of this subpart. 

(i) Number of above grade transmission-distribution 

transfer stations surveyed in the calendar year. 

Number of T-D stations monitored in calendar year. 

§98.236(q)(3)(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). 

§98.236(q)(3)(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). 
61 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(q)(3)(iv) §98.236(c)(16)(ii) Number of above grade transmission-distribution 

transfer stations surveyed in the current leak survey cycle. 

(iii) Number of T-D stations monitored in calendar year. 

§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,y from 

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

§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,y from Equation W-31of this subpart, for 

all years included in the leak survey cycle). 

§98.236(q)(3)(vii) §98.236(c)(16)(viii) Meter/regulator run CO2 emission factor based on all 

surveyed transmission-distribution transfer stations in the current leak survey cycle, in standard cubic feet of CO2 per meter/regulator run operating hour (“EFs,MR,CO2” calculated using Equation W-31 of this subpart). 

Leak factor for meter/regularun developed in Equation W32 of §98.233. 

§98.236(q)(3)(viii) §98.236(c)(16)(viii) Meter/regulator run CH4 emission factor based on all 

surveyed transmission-distribution transfer stations in the current leak survey cycle, in standard cubic feet of CH4 per meter/regulator run operating hour (“EFs,MR,CH4” calculated using Equation W-31 of this subpart). 

Leak factor for meter/regularun developed in Equation W32 of §98.233. 
62 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

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.). 

§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. 

§98.236(r)(1)(ii) §98.236(c)(15)(ii) 

(A) 

Total number of the emission source type at the facility (“Counte” in Equation W-32A of this subpart). 

Total count for each compontype in Tables W-4, W-5, anW-6 of this subpart for whicthere is a population emissiofactor, listed by major headiand component type. 

§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). 
63 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(r)(1)(iv) §98.236(c)(15)(ii) 

(C) 

Annual CO2 emissions, in metric tons CO2, for the emission source type. 

Annual CO2 and CH4emissions, in metric tons COfor each gas (refer to EquatiW-31 of §98.233), by component type. 

§98.236(r)(1)(v) §98.236(c)(15)(ii) 

(C) 

Annual CH4 emissions, in metric tons CH4, for the emission source type. 

Annual CO2 and CH4emissions, in metric tons COfor each gas (refer to EquatiW-31 of §98.233), by component type. 

§98.236(r)(2) and (r)(2)(i) 

§98.236(c)(16)(i) (2) Natural gas distribution facilities must also report 

the information specified in paragraphs (q)(2)(i) through (q)(2)(viii) of this subpart. (i) Number of above grade transmission-distribution transfer stations at the facility. 

Total number of above gradD transfer stations in the facility. 

§98.236(r)(2)(ii) §98.236(c)(16)(v) Number of above grade metering-regulating stations 

that are not transmission-distribution transfer stations at the facility. 

Total number of above gradmetering-regulating stations (this count will include abovgrade T-D transfer stations) the facility. 

§98.236(r)(2)(iii) §98.236(c)(16)(iv) Number of below grade transmission-distribution 

transfer stations at the facility. 

Total number of below gradD transfer stations in the facility. 

§98.236(r)(2)(iv) §98.236(c)(16)(vi) Number of below grade metering-regulating stations 

that are not transmission-distribution transfer stations at the facility. 

Total number of below gradmetering-regulating stations (this count will include belograde T-D transfer stations) the facility. 

§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). 
64 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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). 

§98.236(r)(2)(vii) Annual CO2 emissions, in metric tons CO2, from above 

grade metering regulating stations that are not above grade transmission-distribution transfer stations. 

§98.236(r)(2)(viii) Annual CH4 emissions, in metric tons CH4, from above 

grade metering regulating stations that are not above grade transmission-distribution transfer stations. 

§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. 

§98.236(r)(3)(ii) and (r)(3)(ii)(A) 

(ii) Onshore petroleum and natural gas production facilities must report the information specified in paragraphs (r)(3)(ii)(A) and (r)(3)(ii) 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. 

§98.236(r)(3)(ii)(B) §98.236(c)(15)(ii) 

(B) 

If the facility does contain the equipment type, the count of the major equipment type. 

Total count for each type of major equipment in Table W1B and Table W-1C of this subpart, by facility. 
65 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

Offshore Petroleum and Natural Gas Production §98.236(s)(1), (s)(2), and (s)(3) 

§98.236(b) (s) You must report the information specified in 

paragraphs (s)(1) through (s)(3) of this section for each emission source type listed in the most recent BOEMRE study. (1) Annual CO2 emissions, in metric tons CO2. (2) Annual CH4 emissions, in metric tons CH4. (3) Annual N2O emissions, in metric tons N2O. 

Report emissions of CH4, Cand N2O as applicable to the source type (in metric tons CO2e per year at standard conditions) individually for of the emissions source typelisted in the most recent BOEMRE study. 

EOR Injection Pumps §98.236(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 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. 

§98.236(w)(1) Sub-basin ID. §98.236(w)(2) EOR injection pump system identifier. §98.236(w)(3) §98.236(c)(17)(i) Pump capacity, in barrels per day. Pump capacity, in barrels pe

day 

§98.236(w)(4) §98.236(c)(17)(ii) Total volume of EOR injection pump system 

equipment chambers, in cubic feet(“Vv” in Equation W-37 of this subpart). 

Volume of critical phase gas between isolation valves. 

§98.236(w)(5) §98.236(c)(17)(iii) Number of blowdowns for the EOR injection pump 

system in the calendar year. 

Number of blowdowns per year. 

§98.236(w)(6) §98.236(c)(17)(iv) Density of critical phase EOR injection gas, in 

kilograms per cubic foot(“Rc” in Equation W-37 of this subpart) 

Critical phase EOR injection gas density. 
66 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(w)(7) Mass fraction of CO2 in critical phase EOR injection 

gas (“GHGCO2” in Equation W-37 of this subpart). 

§98.236(w)(8) §98.236(c)(17)(v) Annual CO2 emissions, in metric tons CO2, from EOR 

injection pump system blowdowns. 

For each EOR pump, report annual CO2 emissions, expressed in metric tons COfor each gas. 

EOR Hydrocarbon Liquids §98.236(x) You must indicate whether hydrocarbon liquids were 

produced through EOR operations.... 

§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. 

§98.236(x)(2) §98.236(c)(18)(i) Total volume of hydrocarbon liquids produced through 

EOR operations in the calendar year, in barrels (“Vhl” in Equation W-38 of this subpart). 

Volume of crude oil producein barrels per year. 

§98.236(x)(3) §98.236(c)(18)(ii) Average CO2 retained in hydrocarbon liquids 

downstream of the storage tank, in metric tons per barrel under standard conditions (“Shl” in Equation W38 of this subpart). 

Amount of CO2 retained in hydrocarbon liquids in metritons per barrel, under standaconditions. 

§98.236(x)(4) §98.236(c)(18)(iii) Annual CO2 emissions, in metric tons CO2, from CO2

retained in hydrocarbon liquids produced through EOR operations downstream of the storage tank (“MassCO2”in Equation W-38 of this subpart). 

Report annual CO2 emissionthe sub-basin level , expressin metric tons CO2e. 
67 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

Combustion Equipment for Onshore Petroleum and Natural Gas Production and Natural Gas Distribution Facilities §98.236(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.... 

§98.236(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).... 

§98.236(z)(1) and (z)(1)(i) 

(1)...If the facility contains external fuel combustion units with a rated heat capacity less than or equal to 5 million Btu per hour or internal fuel combustion units that are not compressor-drivers, with a rated heat capacity less than or equal to 1 million Btu per hour (or the equivalent of 130 horsepower), then you must report the information specified in paragraphs (z)(1)(i) and (z)(1)(ii) of this section for each unit type. (i) The type of combustion unit. 
68 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(z)(1)(ii) §98.236(c)(19)(i) 

and (ii) 

The total number of combustion units. (i) Cumulative number of 

external fuel combustion unwith a rated heat capacity eqto or less than 5 mmBtu/hr, type of unit. (ii) Cumulative number of external fuel combustion unwith a rated heat capacity lathan 5 mmBtu/hr, by type of unit. 

§98.236(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. 

§98.236(z)(2) and (z)(2)(i) 

§98.236(c )(19)(i) and (ii) 

(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. 

(i) Cumulative number of external fuel combustion unwith a rated heat capacity eqto or less than 5 mmBtu/hr, type of unit. (ii) Cumulative number of external fuel combustion unwith a rated heat capacity lathan 5 mmBtu/hr, by type of unit. 

§98.236(z)(2)(ii) The type of fuel combusted. 
69 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(z)(2)(iii) §98.236(c )(19)(iv) 

and (c)(19)(vii) 

The quantity of fuel combusted in the calendar year, in thousand standard cubic feet, gallons, or tons. 

(iv) Cumulative volume of fcombusted in external fuel combustion units with a rateheat capacity larger than 5 mmBtu/hr, by fuel type. (vii) Cumulative volume of combusted in internal combustion units with a rateheat capacity larger than 1 mmBtu/hr or 130 horsepoweby fuel type. 

§98.236(z)(2)(iv) §98.236(c )(19)(iii) 

and (c)(19)(vi) 

Annual CO2 emissions, in metric tons CO2, calculated according to § §98.233(z)(1) and (z)(2). 

(iii) Report annual CO2, CHand N2O emissions from external fuel combustion unwith a rated heat capacity lathan 5 mmBtu/hr, expressed metric tons CO2e for each gby type of unit. (vi) Report annual CO2, CHand N2O emissions from internal combustion units greater than 1mmBtu/hr, expressed in metric tons COfor each gas, by type of unit
70 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(z)(2)(v) §98.236(c )(19)(iii) 

and (c)(19)(vi) 

Annual CH4 emissions, in metric tons CH4, calculated according to § §98.233(z)(1) and (z)(2). 

(iii) Report annual CO2, CHand N2O emissions from external fuel combustion unwith a rated heat capacity lathan 5 mmBtu/hr, expressed metric tons CO2e for each gby type of unit. (vi) Report annual CO2, CHand N2O emissions from internal combustion units greater than 1mmBtu/hr, expressed in metric tons COfor each gas, by type of unit

§98.236(z)(2)(vi) §98.236(c )(19)(iii) 

and (c)(19)(vi) 

Annual N2O emissions, in metric tons N2O, calculated according to § §98.233(z)(1) and (z)(2). 

(iii) Report annual CO2, CHand N2O emissions from external fuel combustion unwith a rated heat capacity lathan 5 mmBtu/hr, expressed metric tons CO2e for each gby type of unit. (vi) Report annual CO2, CHand N2O emissions from internal combustion units greater than 1mmBtu/hr, expressed in metric tons COfor each gas, by type of unit
71 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

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. 

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

sales, in thousand standard cubic feet. 

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

for sales, not including lease condensates, in barrels. 

§98.236(aa)(1)(i)(D) The quantity of lease condensate produced in the 

calendar year for sales, in barrels. 

§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. 

§98.236(aa)(1)(ii) (B) 

County. 
72 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(aa)(1)(ii) (C) 

Formation type. 

§98.236(aa)(1)(ii) (D) 

The number of producing wells at the end of the calendar year 

§98.236(aa)(1)(ii) (E) 

The number of producing wells acquired during the calendar year 

§98.236(aa)(1)(ii) (F) 

The number of producing wells divested during the calendar year. 

§98.236(aa)(1)(ii) (G) 

The number of wells completed during the calendar year. 

§98.236(aa)(1)(ii) (H) 

The number of wells taken out of production during the calendar year. 

§98.236(aa)(1)(ii) (I) 

Average mole fraction of CH4 in produced gas. 

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

§98.236(e) If an oil sub-basin, report the average GOR of all wells, 

in thousand standard cubic feet per barrel. 

For onshore petroleum and natural gas production, repo. best available estimate of gto oil ratio, ...for each oil subasin category. 

§98.236(aa)(1)(ii) (L) 

§98.236(e) If an oil sub-basin, report the average API gravity of all 

wells. 

For onshore petroleum and natural gas production, repothe best available estimate oAPI gravity, . . .for each oil sub-basin category. 

§98.236(aa)(1)(ii)(M) 

§98.236(e) If an oil sub-basin, report average low pressure 

separator pressure, in pounds per square inch gauge. 

For onshore petroleum and natural gas production, repothe . . .best available estimataverage low pressure separapressure for each oil sub-bascategory. 
73 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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. 

§98.236(aa)(2)(ii) The quantity of oil produced from the offshore 

platform in the calendar year for sales, in barrels. 

§98.236(aa)(2)(iii) The quantity of condensate produced from the offshore 

platform in the calendar year for sales, in barrels. 

§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. 

§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. 

§98.236(aa)(3)(iii) The quantity of NGLs (bulk and fractionated) received 

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

§98.236(aa)(3)(iv) The quantity of NGLs (bulk and fractionated) leaving 

the gas processing plant in the reporting year (barrels). 

§98.236(aa)(3)(v) Average mole fraction of CH4 in produced gas 

received. 

§98.236(aa)(3)(vi) Average mole fraction of CO2 in produced gas 

received. 

§98.236(aa)(3)(vii) Indicate whether the facility fractionates NGLs. 
74 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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. 

§98.236(aa)(4)(ii) Number of compressors. §98.236(aa)(4)(iii) Total compressor power rating of all compressors 

combined, in horsepower. 

§98.236(aa)(4)(iv) Average upstream pipeline pressure, in pounds per 

square inch gauge. 

§98.236(aa)(4)(v) Average downstream pipeline pressure, in pounds per 

square inch gauge. 

§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. 

§98.236(aa)(5)(ii) The quantity of gas withdrawn from storage in the 

calendar year, in thousand standard cubic feet. 

§98.236(aa)(5)(iii) Total storage capacity, in thousand standard cubic feet. §98.236(aa)(6) For LNG import equipment, report the quantity of 

LNG imported in the calendar year, in thousand standard cubic feet. 

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

exported in the calendar year, in thousand standard cubic feet. 
75 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§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. 

§98.236(aa)(8)(ii) The quantity of LNG withdrawn from storage in the 

calendar year, in thousand standard cubic feet. 

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

§98.236(aa)(9)(ii) The quantity of natural gas withdrawn from in-system 

storage in the calendar year, in thousand standard cubic feet. 

§98.236(aa)(9)(iii) The quantity of natural gas added to in-system storage 

in the calendar year, in thousand standard cubic feet. 

§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. 

§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. 

§98.236(aa)(9)(vi) The quantity of natural gas consumed by the LDC for 

operational purposes, in thousand standard cubic feet. 
76 

Table 1. Proposed Changes to the Subpart W Reporting Requirements

Proposed Citation 

Reference 

Current Citation 

Reference Proposed Rule Text Current Rule Text 

§98.236(aa)(9)(vii) The estimated quantity of gas stolen in the calendar 

year, in thousand standard cubic feet. 

Missing Data Provisions §98.236(bb), and (bb)(1) 

(bb) For any missing data procedures used, report the information in paragraphs (1) through (5) 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. 

§98.236(bb)(2) The equation(s) in which the missing data is used §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. 

§98.236(bb)(4) The description of the procedures used to substitute an 

unavailable value of a parameter. 

§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.