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 95156 - Additional Data Reporting Requirements

Universal Citation: 17 CA Code of Regs 95156

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

Operators must conform to the data reporting requirements in section 95157 in addition to the data reporting requirements specified below. Sales records or sales records with an inventory adjustment are allowable methods to quantify the covered product data required by paragraphs (a)(7)-(10), (b), (c) and (d) of this section, for products that are sold or produced during the data year, if the measurement system meets the criteria in section 95103(k). Any changes in the covered product data reporting method must conform to the requirements in section 95103(m). Reporting entities must exclude inaccurate product data pursuant to section 95103 (l).

(a) In addition to the data required by section 95157, the operator of an onshore or offshore petroleum and natural gas production facility must report the following data for the facility, disaggregated within the basin by sub-facility:

(1) CO2e emissions, including CO2, CH4, and N2O as applicable for the source types specified in section 95152(c);

(2) For combustion sources for which emissions are reported, fuel use by fuel type;

(3) For cogeneration sources:
(A) Total thermal output (MMBtu);

(B) Net electricity generation (MWh);

(C) Amount of electricity generation (MWh) not consumed within the facility (i.e., exported offsite or to another facility owner/operator);

(4) For steam generator sources:
(A) Total thermal energy generated (MMBtu) and the CO2e emissions associated with this output;

(B) Thermal energy (MMBtu) not utilized within the facility (i.e., exported offsite or to another facility owner/operator) and the CO2e emissions associated with this output;

(5) For electricity generation sources not included in section 95156(a)(3):
(A) Net electricity generation (MWh) and the CO2e emissions associated with this generation;

(B) Amount of electricity generation (MWh) not consumed within the facility (i.e., exported offsite or to another facility owner/operator) and the portion of CO2e emissions associated with this generation;

(6) Total steam (MMBtu) utilized but not generated at the facility and the CO2e emissions associated with this output, if known;

(7) Barrels of crude oil produced using thermal enhanced oil recovery. This means the volume of crude oil produced within the facility boundary during the data year, a volume which may include the crude oil fraction piped as an emulsion as defined in section 95102(a);

(8) Barrels of crude oil produced using non-thermal enhanced oil recovery. This means the volume of crude oil produced within the facility boundary during the data year, a volume which may include the crude oil fraction piped as an emulsion as defined in section 95102(a);

(9) Heat energy (MMBtu) of associated gas produced using thermal enhanced oil recovery. This includes the associated gas fraction piped as an emulsion as defined in section 95102(a). Associated gas may be quantified using production or sales meters as appropriate. Associated gas may also be quantified by multiplying the barrels of crude oil produced during the data year by a representative GOR measurement plus the representative GWR measurement multiplied by the produced water volume. When GOR and GWR measurements are used for quantifying associated gas, these measurements must be the most disaggregated data available (e.g., field or tank farm level). The annual weighted average HHV of the produced gas must be multiplied by the data year volume to determine the annual heat content in MMBtu. HHV measurements must be collected and averaged consistent with the frequency requirements in section 95153(y)(2)(D);

(10) Heat energy (MMBtu) of associated gas produced using non-thermal enhanced oil recovery. This includes the associated gas fraction piped as an emulsion as defined in section 95102(a). Associated gas may be quantified using production or sales meters as appropriate. Associated gas may also be quantified by multiplying the barrels of crude oil produced during the data year by a representative GOR measurement plus the representative GWR measurement multiplied by the annual produced water volume. When GOR and GWR measurements are used for quantifying associated gas, these measurements must be the most disaggregated data available (e.g., field or tank farm level). The annual weighted average HHV of the produced gas must be multiplied by the data year volume to determine the annual heat content in MMBtu. HHV measurements must be collected and averaged consistent with the frequency requirements in section 95153(y)(2)(D).

(b) For dry gas production, the operator of an onshore petroleum and natural gas production facility must report its annual heat energy of dry gas produced (MMBtu). The annual weighted average HHV of the produced gas must be multiplied by the data year volume to determine the heat energy in MMBtu. HHV measurements must be collected and averaged consistent with the frequency requirements in section 95153(y)(2)(D);

(c) The operator of a natural gas liquid fractionating facility, or a natural gas processing facility, or an onshore petroleum and natural gas production facility with a natural gas processing plant that processes less than 25 MMscf per day must report the annual production of the following natural gas liquids in barrels corrected to 60 degrees Fahrenheit:

(1) Ethane

(2) Ethylene

(3) Propane

(4) Propylene

(5) Butane

(6) Butylene

(7) Isobutane

(8) Isobutylene

(9) Pentanes plus

(10) Natural gasoline

(11) Liquefied petroleum gas

(12) Bulk natural gas liquids not included in 95156(d)(1)-(11)

If a facility extracts natural gas liquids from produced gas, associated gas, or waste gas, and re-injects these natural gas liquids into barrels of crude oil produced at the same facility, the operator of such a facility shall report the amount of any re-injected natural gas liquids as covered product data pursuant to section 95156(a)(7) or (8). All other natural gas liquids produced at the facility should be reported as covered product data pursuant to section 95156(c).

(d) Onshore natural gas processing facilities that have an annual average throughput of 25 MMscf per day or greater must also report the heat energy of associated gas, waste gas, and natural gas processed (MMBtu). The annual weighted average HHV of the produced gas must be multiplied by the data year volume to determine the heat energy in MMBtu. Facility operators may quantify the volume of gas processed as either the annual output volume or the annual throughput volume of the gas processed at the facility. HHV measurements must be collected and averaged consistent with the frequency requirements in 95153(y)(2)(D).

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 section filed 12-19-2012; operative 1-1-2013 pursuant to Government Code section 11343.4 (Register 2012, No. 51).
3. Amendment filed 12-31-2013; operative 1-1-2014 pursuant to Government Code section 11343.4(b)(3) (Register 2014, No. 1).
4. Amendment of first paragraph and subsections (a), (a)(7)-(10), (b), (c)(12) and (d) 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 (a)(9)-(10), (b)-(c) and (d) filed 9-1-2017; operative 1-1-2018 (Register 2017, No. 35).

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.

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