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 2 - Requirements for the Mandatory Reporting of Greenhouse Gas Emissions from Specific Types of Facilities, Suppliers, and Entities › Section 95113 - Petroleum Refineries

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The operator of a facility who is required to report
						  under section
						  95101 of this article, and who is
						  not eligible for abbreviated reporting under section
						  95103(a), must
						  comply with Subpart Y of 40 CFR Part 98 (40 CFR §§
													98.250 to
						  98.258) in reporting emissions and
						  other data from petroleum refineries to ARB, except as otherwise provided in
						  this section. Petroleum refinery operators and refiners are considered separate
						  reporting entities for the purposes of this article.
(a)
CO2 from
						Fossil Fuel Combustion
. When calculating CO2
						emissions from fuel combustion under subpart C as specified at
						40 CFR §
													98.252(a), the operator must
						use a method in 40 CFR
						§
													98.33(a)(1) to §
												98.33(a)(4) as
						specified by fuel type in section
						95115 of this article.
						CO2 emissions from refinery fuel gas combustion must be
						calculated using a Tier 3 or Tier 4 methodology of subpart C, as specified in
						40 CFR §
													98.252(a).
(b)
Monitoring, Data and
						Records
. For each emissions calculation method chosen under section
						95113(a), the
						operator must meet the applicable requirements for monitoring, missing data
						procedures, data reporting, and records retention that are specified in
						40 CFR §
													98.34 to §
												98.37, except as modified in
						sections 95113(k),
						95115, and
						95129 of this article.
(c)
Refinery Fuel Gas
						Sampling
. As required by
						40 CFR §
													98.34(b)(3)(ii)(E), in cases
						where equipment necessary to perform daily sampling and analysis of carbon
						content and molecular weight for refinery fuel gas is not in place, such
						equipment must be installed and procedures established to implement daily
						sampling and analysis no later than January 1, 2013.
(d)
Calculating
CO2
from Flares
. For periods of normal
						flare operation, the operator must use Equation Y-1a, Y-1b, or Y-2 as specified
						in 40 CFR §
													98.253(b)(ii)(A) or
						98.253(b)(ii)(B).
						For periods of startup, shutdown, and malfunction (SSM) during which the
						operator was unable to measure the parameters required by Equations Y-1a, Y-1b,
						or Y-2, the operator must determine the quantity of gas discharged to the flare
						separately for each SSM, and calculate the CO2 emissions
						as specified in the equation shown below. For SSM periods the operator must use
						engineering calculations and process knowledge to estimate the carbon content
						of flared gas as required by §
												98.253(b)(iii)(A).
						The terms of the equation below are defined as they are for Equation Y-3 in
						40 CFR §
													98.253(b)(iii)(C).
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(e)
Calculating
CO2
from FCCUs and Fluid Coking
. The
						requirements of 40 CFR
						§
													98.253(c)(2) apply
						under this article regardless of the rated capacity of a fluid catalytic
						cracking unit or a fluid coking unit. The operator may not use Equation Y-8 or
						the option provided under 40
						CFR §
													98.253(c)(3) for
						units with rated capacities of 10,000 barrels per stream day or less.
(f)
Uncontrolled Blowdown
						Systems
. When calculating CH4 emissions for
						uncontrolled blowdown systems as required by
						40 CFR §
													98.253(k), the operator must
						use the methods for process vents in
						40 CFR §
													98.253(j).
(g)
Data Reporting Requirements for
						Flares
. When the operator has calculated flare emissions for SSM
						periods using the modified equation specified in section
						95113(d), the
						operator reporting data under the requirements of
						40 CFR §
													98.256(e)(8) must report
						only the total number of SSM events, the volume of gas flared, and the average
						molecular weight and carbon content of the flare gas for each SSM event, using
						the units specified.
(h)
Data Reporting Requirements for FCCUs and Coking Units
. When
						the operator has calculated CO2 from fluid catalytic
						cracking units or fluid coking units consistent with section
						95113(e), the
						operator shall not report the data required by
						40 CFR §
													98.256(f)(9).
(i)
Data Reporting Requirements for
						Uncontrolled Blowdown Systems
. When the operator has calculated
						CH4 from uncontrolled blowdown systems consistent with
						section 95113(g), the
						operator must report the information required for process vents in
						40 CFR §
													98.256 (
l
), as applicable,
						in lieu of the information required by
						40 CFR §
													98.256(m)(2).
(j)
Records that must be
						retained
. In addition to the requirements of
						40 CFR §
													98.257, for each process vent for which the
						concentration of CO2, N2O and
						CH4 are determined to be below the thresholds in
						40 CFR §
													98.253(j), the operator must
						maintain records of the method used to determine the
						CO2, N2O, and
						CH4 concentrations, and all supporting documentation
						necessary to demonstrate that the thresholds in
						40 CFR §
													98.253(j) are not exceeded
						during the data year pursuant to the record keeping requirements of section
						95105.
(k)
Missing Data Substitution
						Procedures
. The operator must comply with
						40 CFR §
													98.255 when substituting for missing data,
						except as otherwise provided in paragraphs (1)-(2) below.
(1) To substitute for missing data for
						emissions reported under section
						95115 of this article (stationary
						combustion units and units using continuous emissions monitoring systems), the
						operator must follow the requirements of section
						95129 of this article.
(2) For all other data required for emissions
						calculations in this section, the operator must follow the requirements of
						paragraphs (A)-(C) below.
(A) If the
						analytical data capture rate is at least 90 percent for the data year, the
						operator must substitute for each missing value using the best available
						estimate of the parameter, based on all available process data.
(B) If the analytical data capture rate is at
						least 80 percent but not at least 90 percent for the data year, the operator
						must substitute for each missing value with the highest quality assured value
						recorded for the parameter during the given data year, as well as the two
						previous data years.
(C) If the
						analytical data capture rate is less than 80 percent for the data year, the
						operator must substitute for each missing value with the highest quality
						assured value recorded for the parameter in all records kept according to
						section 95105(a).