§ 98.236 Data reporting requirements.
In addition to the information required by § 98.3(c), each annual report must contain reported emissions and related information as specified in this section. Reporters that use a flow or volume measurement system that corrects to standard conditions as provided in the introductory text in § 98.233 for data elements that are otherwise required to be determined at actual conditions, report gas volumes at standard conditions rather the gas volumes at actual conditions and report the standard temperature and pressure used by the measurement system rather than the actual temperature and pressure.
(a) The annual report must include the information specified in paragraphs (a)(1) through (10) of this section for each applicable industry segment. The annual report must also include annual emissions totals, in metric tons of each GHG, for each applicable industry segment listed in paragraphs (a)(1) through (10), and each applicable emission source listed in paragraphs (b) through (z) of this section.
(1) Onshore petroleum and natural gas production. For the equipment/activities specified in paragraphs (a)(1)(i) through (xvii) of this section, report the information specified in the applicable paragraphs of this section.
(i) Natural gas pneumatic devices. Report the information specified in paragraph (b) of this section.
(ii) Natural gas driven pneumatic pumps. Report the information specified in paragraph (c) of this section.
(iii) Acid gas removal units. Report the information specified in paragraph (d) of this section.
(iv) Dehydrators. Report the information specified in paragraph (e) of this section.
(v) Liquids unloading. Report the information specified in paragraph (f) of this section.
(vi) Completions and workovers with hydraulic fracturing. Report the information specified in paragraph (g) of this section.
(vii) Completions and workovers without hydraulic fracturing. Report the information specified in paragraph (h) of this section.
(viii) Onshore production storage tanks. Report the information specified in paragraph (j) of this section.
(ix) Well testing. Report the information specified in paragraph (l) of this section.
(x) Associated natural gas. Report the information specified in paragraph (m) of this section.
(xi) Flare stacks. Report the information specified in paragraph (n) of this section.
(xii) Centrifugal compressors. Report the information specified in paragraph (o) of this section.
(xiii) Reciprocating compressors. Report the information specified in paragraph (p) of this section.
(xiv) Equipment leak surveys. Report the information specified in paragraph (q) of this section.
(xv) Equipment leaks by population count. Report the information specified in paragraph (r) of this section.
(xvi) EOR injection pumps. Report the information specified in paragraph (w) of this section.
(xvii) EOR hydrocarbon liquids. Report the information specified in paragraph (x) of this section.
(xviii) Combustion equipment. Report the information specified in paragraph (z) of this section.
(2) Offshore petroleum and natural gas production. Report the information specified in paragraph (s) of this section.
(3) Onshore natural gas processing. For the equipment/activities specified in paragraphs (a)(3)(i) through (vii) of this section, report the information specified in the applicable paragraphs of this section.
(i) Acid gas removal units. Report the information specified in paragraph (d) of this section.
(ii) Dehydrators. Report the information specified in paragraph (e) of this section.
(iii) Blowdown vent stacks. Report the information specified in paragraph (i) of this section.
(iv) Flare stacks. Report the information specified in paragraph (n) of this section.
(v) Centrifugal compressors. Report the information specified in paragraph (o) of this section.
(vi) Reciprocating compressors. Report the information specified in paragraph (p) of this section.
(vii) Equipment leak surveys. Report the information specified in paragraph (q) of this section.
(4) Onshore natural gas transmission compression. For the equipment/activities specified in paragraphs (a)(4)(i) through (vii) of this section, report the information specified in the applicable paragraphs of this section.
(i) Natural gas pneumatic devices. Report the information specified in paragraph (b) of this section.
(ii) Blowdown vent stacks. Report the information specified in paragraph (i) of this section.
(iii) Transmission storage tanks. Report the information specified in paragraph (k) of this section.
(iv) Flare stacks. Report the information specified in paragraph (n) of this section.
(v) Centrifugal compressors. Report the information specified in paragraph (o) of this section.
(vi) Reciprocating compressors. Report the information specified in paragraph (p) of this section.
(vii) Equipment leak surveys. Report the information specified in paragraph (q) of this section.
(5) Underground natural gas storage. For the equipment/activities specified in paragraphs (a)(5)(i) through (vi) of this section, report the information specified in the applicable paragraphs of this section.
(i) Natural gas pneumatic devices. Report the information specified in paragraph (b) of this section.
(ii) Flare stacks. Report the information specified in paragraph (n) of this section.
(iii) Centrifugal compressors. Report the information specified in paragraph (o) of this section.
(iv) Reciprocating compressors. Report the information specified in paragraph (p) of this section.
(v) Equipment leak surveys. Report the information specified in paragraph (q) of this section.
(vi) Equipment leaks by population count. Report the information specified in paragraph (r) of this section.
(6) LNG storage. For the equipment/activities specified in paragraphs (a)(6)(i) through (v) of this section, report the information specified in the applicable paragraphs of this section.
(i) Flare stacks. Report the information specified in paragraph (n) of this section.
(ii) Centrifugal compressors. Report the information specified in paragraph (o) of this section.
(iii) Reciprocating compressors. Report the information specified in paragraph (p) of this section.
(iv) Equipment leak surveys. Report the information specified in paragraph (q) of this section.
(v) Equipment leaks by population count. Report the information specified in paragraph (r) of this section.
(7) LNG import and export equipment. For the equipment/activities specified in paragraphs (a)(7)(i) through (vi) of this section, report the information specified in the applicable paragraphs of this section.
(i) Blowdown vent stacks. Report the information specified in paragraph (i) of this section.
(ii) Flare stacks. Report the information specified in paragraph (n) of this section.
(iii) Centrifugal compressors. Report the information specified in paragraph (o) of this section.
(iv) Reciprocating compressors. Report the information specified in paragraph (p) of this section.
(v) Equipment leak surveys. Report the information specified in paragraph (q) of this section.
(vi) Equipment leaks by population count. Report the information specified in paragraph (r) of this section.
(8) Natural gas distribution. For the equipment/activities specified in paragraphs (a)(8)(i) through (iii) of this section, report the information specified in the applicable paragraphs of this section.
(i) Combustion equipment. Report the information specified in paragraph (z) of this section.
(ii) Equipment leak surveys. Report the information specified in paragraph (q) of this section.
(iii) Equipment leaks by population count. Report the information specified in paragraph (r) of this section.
(9) Onshore petroleum and natural gas gathering and boosting. For the equipment/activities specified in paragraphs (a)(9)(i) through (xi) of this section, report the information specified in the applicable paragraphs of this section.
(i) Natural gas pneumatic devices. Report the information specified in paragraph (b) of this section.
(ii) Natural gas driven pneumatic pumps. Report the information specified in paragraph (c) of this section.
(iii) Acid gas removal units. Report the information specified in paragraph (d) of this section.
(iv) Dehydrators. Report the information specified in paragraph (e) of this section.
(v) Blowdown vent stacks. Report the information specified in paragraph (i) of this section.
(vi) Storage tanks. Report the information specified in paragraph (j) of this section.
(vii) Flare stacks. Report the information specified in paragraph (n) of this section.
(viii) Centrifugal compressors. Report the information specified in paragraph (o) of this section.
(ix) Reciprocating compressors. Report the information specified in paragraph (p) of this section.
(x) Equipment leak surveys. Report the information specified in paragraph (q) of this section.
(xi) Equipment leaks by population count. Report the information specified in paragraph (r) of this section.
(xii) Combustion equipment. Report the information specified in paragraph (z) of this section.
(10) Onshore natural gas transmission pipeline. For blowdown vent stacks, report the information specified in paragraph (i) of this section.
(b) Natural gas pneumatic devices. 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, then you must report the information specified in paragraphs (b)(1) through (b)(4) of this section.
(1) The number of natural gas pneumatic devices as specified in paragraphs (b)(1)(i) and (ii) of this section.
(i) The total number of devices of each type, determined according to § 98.233(a)(1) and (2).
(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 (C) of this section.
(A) The number of devices of each type reported in paragraph (b)(1)(i) of this section that are counted.
(B) The number of devices of each type reported in paragraph (b)(1)(i) of this section that are estimated (not counted).
(C) Whether the calendar year is the first calendar year of reporting or the second calendar year of reporting.
(2) For each type of pneumatic device, the estimated average number of hours in the calendar year that the natural gas pneumatic devices reported in paragraph (b)(1)(i) of this section were operating in the calendar year (“Tt” in Equation W–1 of this subpart).
(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.
(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.
(c) Natural gas driven pneumatic pumps. 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 (4) of this section.
(1) Count of natural gas driven pneumatic pumps.
(2) Average estimated number of hours in the calendar year the pumps were operational (“T” in Equation W–2 of this subpart).
(3) Annual CO2 emissions, in metric tons CO2, for all natural gas driven pneumatic pumps combined, calculated according to § 98.233(c)(1) and (2).
(4) Annual CH4 emissions, in metric tons CH4, for all natural gas driven pneumatic pumps combined, calculated according to § 98.233(c)(1) and (2).
(d) Acid gas removal units. 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 (2) of this section.
(1) You must report the information specified in paragraphs (d)(1)(i) through (vi) 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 and the onshore petroleum and natural gas gathering and boosting industry segments, 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.
(ii) Total feed rate entering the acid gas removal unit, using a meter or engineering estimate based on process knowledge or best available data, in million cubic feet per year.
(iii) The calculation method used to calculate CO2 emissions from the acid gas removal unit, as specified in § 98.233(d).
(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). 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 under subpart PP of this part.
(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).
(vi) Sub-basin ID that best represents the wells supplying gas to the unit (for the onshore petroleum and natural gas production industry segment only) or name of the county that best represents the equipment supplying gas to the unit (for the onshore petroleum and natural gas gathering and boosting industry segment only).
(2) You must report information specified in paragraphs (d)(2)(i) through (iii) of this section, applicable to the calculation method reported in paragraph (d)(1)(iii) of this section, for each acid gas removal unit.
(i) If you used Calculation Method 1 or Calculation Method 2 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)(i)(A) and (B) of this section.
(A) Annual average volumetric fraction of CO2 in the vent gas exiting the acid gas removal unit.
(B) Annual volume of gas vented from the acid gas removal unit, in cubic feet.
(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) of this section.
(A) Indicate which equation was used (Equation W–4A or W–4B).
(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.
(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.
(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.
(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 (L) of this section, as applicable to the simulation software package used.
(A) The name of the simulation software package used.
(B) Natural gas feed temperature, in degrees Fahrenheit.
(C) Natural gas feed pressure, in pounds per square inch.
(D) Natural gas flow rate, in standard cubic feet per minute.
(E) Acid gas content of the feed natural gas, in mole percent.
(F) Acid gas content of the outlet natural gas, in mole percent.
(G) Unit operating hours, excluding downtime for maintenance or standby, in hours per year.
(H) Exit temperature of the natural gas, in degrees Fahrenheit.
(I) Solvent pressure, in pounds per square inch.
(J) Solvent temperature, in degrees Fahrenheit.
(K) Solvent circulation rate, in gallons per minute.
(L) Solvent weight, in pounds per gallon.
(e) Dehydrators. You must indicate whether your facility contains any of the following equipment: Glycol dehydrators with an annual average daily natural gas throughput greater than or equal to 0.4 million standard cubic feet per day, glycol dehydrators with an annual average daily natural gas throughput less than 0.4 million standard cubic feet per day, and dehydrators that use desiccant. If your facility contains any of the equipment listed in this paragraph (e), then you must report the applicable information in paragraphs (e)(1) through (3).
(1) For each glycol 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 (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 and the onshore petroleum and natural gas gathering and boosting industry segments, a different name or ID may be used for a single dehydrator for each location it operates at in a given year.
(ii) Dehydrator feed natural gas flow rate, in million standard cubic feet per day, determined by engineering estimate based on best available data.
(iii) Dehydrator feed natural gas water content, in pounds per million standard cubic feet.
(iv) Dehydrator outlet natural gas water content, in pounds per million standard cubic feet.
(v) Dehydrator absorbent circulation pump type (e.g., natural gas pneumatic, air pneumatic, or electric).
(vi) Dehydrator absorbent circulation rate, in gallons per minute.
(vii) Type of absorbent (e.g., triethylene glycol (TEG), diethylene glycol (DEG), or ethylene glycol (EG)).
(viii) Whether stripper gas is used in dehydrator.
(ix) Whether a flash tank separator is used in dehydrator.
(x) Total time the dehydrator is operating, in hours.
(xi) Temperature of the wet natural gas, in degrees Fahrenheit.
(xii) Pressure of the wet natural gas, in pounds per square inch gauge.
(xiii) Mole fraction of CH4 in wet natural gas.
(xiv) Mole fraction of CO2 in wet natural gas.
(xv) Whether any dehydrator emissions are vented to a vapor recovery device.
(xvi) Whether any dehydrator emissions are vented to a flare or regenerator firebox/fire tubes. If any emissions are vented to a flare or regenerator firebox/fire tubes, report the information specified in paragraphs (e)(1)(xvi)(A) through (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).
(B) Annual CH4 emissions, in metric tons CH4, for the dehydrator, calculated according to § 98.233(e)(6).
(C) Annual N2O emissions, in metric tons N2O, for the dehydrator, calculated according to § 98.233(e)(6).
(xvii) Whether any dehydrator emissions are vented to the atmosphere without being routed to a flare or regenerator firebox/fire tubes. 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 (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, if applicable, (e)(5).
(B) 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, if applicable, (e)(5).
(xviii) Sub-basin ID that best represents the wells supplying gas to the dehydrator (for the onshore petroleum and natural gas production industry segment only) or name of the county that best represents the equipment supplying gas to the dehydrator (for the onshore petroleum and natural gas gathering and boosting industry segment only).
(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 (v) of this section for the entire facility.
(i) The total number of dehydrators at the facility.
(ii) Whether any dehydrator emissions were vented to a vapor recovery device. If any dehydrator emissions were vented to a vapor recovery device, then you must report the total number of dehydrators at the facility that vented to a vapor recovery device.