California Code of Regulations
Title 17 - Public Health
Division 3 - Air Resources
Chapter 1 - Air Resources Board
Subchapter 10 - Climate Change
Article 2 - Mandatory Greenhouse Gas Emissions Reporting
Subarticle 5 - Reporting Requirements and Calculation Methods for Petroleum and Natural Gas Systems
Section 95152 - Greenhouse Gases to Report

Universal Citation: 17 CA Code of Regs 95152

Current through Register 2024 Notice Reg. No. 38, September 20, 2024

(a) The operator of a facility must report CO2, CH4, and N2O emissions from each industry segment specified in paragraphs (b) through (i) of this section, CO2, CH4, and N2O emissions from each flare as specified in paragraphs (b) through (i) of this section, and stationary and portable combustion emissions as applicable and as specified in paragraph (j) of this section.

(b) For offshore petroleum and natural gas production, the operator must report CO2, CH4, and N2O emissions from equipment leaks, vented emissions, and flare emission source types as identified in the data collection and emissions estimation study, (Year 2008 Gulfwide Emission Inventory Study (GOADS) (December 2010)) conducted by the Bureau of Ocean Energy Management, Regulation and Enforcement (BOEMRE) in compliance with 30 CFR §§ 250.302 through 304 (July 1, 2011), which is hereby incorporated by reference. Offshore platforms do not need to report portable emissions. In addition, offshore production facilities must report combustion emissions from supply and transportation vessels (e.g., ships and helicopters) used to transport personnel, equipment and products to and from the production facility using methods found in subpart C of 40 CFR Part 98.

(c) For an onshore petroleum and natural gas production facility, the operator must report CO2, CH4, and N2O emissions from the following source types on a well-pad, associated with a well-pad or associated with equipment to which an emulsion is transferred:

(1) Metered natural gas pneumatic device and pump venting;

(2) Non-metered natural gas pneumatic device venting;

(3) Acid gas removal vents;

(4) Dehydrator vents;

(5) Well venting for liquids unloading;

(6) Gas well venting during well completions and workovers;

(7) Equipment and pipeline blowdowns;

(8) Dump valves;

(9) Well testing venting and flaring;

(10) Associated gas venting and flaring;

(11) Flare stack or other destruction device emissions;

(12) Centrifugal compressor venting;

(13) Reciprocating compressor venting;

(14) EOR injection pump blowdown;

(15) Crude oil, condensate and produced water CO2 and CH4;

(16) Equipment leaks from valves, connectors, open ended lines, pressure relief valves, pumps, flanges, and other equipment leak sources (such as instruments, loading arms, stuffing boxes, compressor seals, dump lever arms, and breather caps); and

(17) The operator must use the methods in section 95153(y) and report under this subarticle the emissions of CO2, CH4, and N2O from stationary or portable fuel combustion equipment that cannot move on roadways under its own power and drive train, and that is located at an onshore petroleum and natural gas production facility as defined in section 95150. Stationary or portable equipment includes equipment which is integral to the extraction, processing, and movement of oil and/or natural gas; such as well pad construction equipment, well drilling and completion equipment, equipment used for abandoned well plugging and site reclamation, workover equipment, natural gas dehydrators, natural gas compressors, electrical generators, steam boilers, and process heaters.

(d) For onshore natural gas processing, the operator must report CO2, CH4, and N2O emissions from the following sources:

(1) Acid gas removal vents;

(2) Dehydrator vents;

(3) Equipment and pipeline blowdowns;

(4) Flare stack or other destruction device emissions;

(5) Centrifugal compressor venting;

(6) Reciprocating compressor venting; and

(7) Equipment leaks from valves, connectors, open ended lines, pressure relief valves, and meters.

(e) For onshore natural gas transmission compression, the operator must report CO2, CH4, and N2O emissions from the following sources:

(1) Metered natural gas pneumatic device and pump venting;

(2) Non-metered natural gas pneumatic device venting;

(3) Equipment and pipeline blowdowns;

(4) Transmission storage tanks;

(5) Flare stack or other destruction device emissions;

(6) Centrifugal compressor venting;

(7) Reciprocating compressor venting; and

(8) Equipment leaks from valves, connectors, open ended lines, pressure relief valves, and meters.

(f) For underground natural gas storage, the operator must report CO2, CH4, and N2O from the following sources:

(1) Metered natural gas pneumatic device and pump venting;

(2) Non-metered natural gas pneumatic device venting;

(3) Equipment and pipeline blowdowns;

(4) Flare stack or other destruction device emissions;

(5) Centrifugal compressor venting;

(6) Reciprocating compressor venting; and

(7) Equipment leaks from valves, connectors, open ended lines, pressure relief valves, and meters.

(g) For LNG storage, the operator must report CO2, CH4, and N2O emissions from the following sources:

(1) Equipment and pipeline blowdowns;

(2) Flare stack or other destruction device emissions;

(3) Centrifugal compressor venting;

(4) Reciprocating compressor venting; and

(5) Equipment leaks from valves, pump seals, connectors, vapor recovery compressors, and other equipment leak sources.

(h) For LNG import and export equipment, the operator must report CO2, CH4, and N2O emissions from the following sources:

(1) Equipment and pipeline blowdowns;

(2) Flare stack or other destruction device emissions;

(3) Centrifugal compressor venting;

(4) Reciprocating compressor venting; and

(5) Equipment leaks from valves, pump seals, connectors, vapor recovery compressors, and other equipment leak sources.

(i) For natural gas distribution, the operator must report CO2, CH4, and N2O emissions from the following sources:

(1) Equipment leaks from connectors, block valves, control valves, pressure relief valves, orifice meters, regulators, and open ended lines at above grade transmission-distribution transfer stations;

(2) Equipment leaks at below grade transmission-distribution transfer stations;

(3) Equipment leaks at above grade metering-regulating stations that are not above grade transmission-distribution transfer stations;

(4) Equipment leaks at below grade metering-regulating stations.

(5) Distribution main equipment leaks;

(6) Distribution services equipment leaks;

(7) Report under section 95150 of this article the emissions of CO2, CH4, and N2O from stationary fuel combustion sources following the methods in 95153(y);

(8) Flare stack emissions;

(9) Equipment and pipeline blowdowns;

(10) CO2 and CH4 emissions from customer meters (N2O emissions excluded); and

(11) CO2 and CH4 emissions from pipeline dig-ins (N2O emissions excluded).

(j) Except for facilities under onshore petroleum and natural gas production and natural gas distribution, the operator of a facility must report emissions of CO2, CH4, and N2O for each stationary fuel combustion unit by following the requirements of section 95115 of this article. Operators of onshore petroleum and natural gas production facilities must report stationary and portable combustion emissions as specified in paragraph (c) of this section. Natural gas distribution facilities must report stationary combustion emissions as specified in paragraph (i) of this section.

(k) Operators of facilities must report CO2 emissions captured and transferred off site by following the requirements of section 95123 of this article (suppliers of carbon dioxide).

1. New section filed 12-14-2011; operative 1-1-2012 pursuant to Government Code section 11343.4 (Register 2011, No. 50).
2. Amendment of section heading and repealer and new section filed 12-19-2012; operative 1-1-2013 pursuant to Government Code section 11343.4 (Register 2012, No. 51).
3. Amendment of subsections (c), (c)(8) and (c)(15), repealer of subsection (c)(16), subsection renumbering and new subsection (i)(9) filed 12-31-2013; operative 1-1-2014 pursuant to Government Code section 11343.4(b)(3) (Register 2014, No. 1).
4. Amendment of subsections (b), (c)(13), (d)(6), (e)(7), (f)(6), (g)(4), (h)(4) and (i)(1)-(9) and new subsections (i)(10)-(11) filed 12-31-2014; operative 1-1-2015 pursuant to Government Code section 11343.4(b)(3) (Register 2015, No. 1).
5. Amendment of subsections (f)(5), (g)(3) and (h)(3) filed 3-29-2019; operative 4-1-2019 pursuant to Government Code section 11343.4(b)(3) (Register 2019, No. 13).

Note: Authority cited: Sections 38510, 38530, 39600, 39601, 39607, 39607.4 and 41511, Health and Safety Code. Reference: Sections 38530, 39600 and 41511, Health and Safety Code.

Disclaimer: These regulations may not be the most recent version. California may have more current or accurate information. We make no warranties or guarantees about the accuracy, completeness, or adequacy of the information contained on this site or the information linked to on the state site. Please check official sources.
This site is protected by reCAPTCHA and the Google Privacy Policy and Terms of Service apply.