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

Current through Register 2024 Notice Reg. No. 28, July 12, 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).