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 95154 - Monitoring and QA/QC Requirements

Current through Register 2024 Notice Reg. No. 28, July 12, 2024
The GHG emissions data for petroleum and natural gas
						  emissions sources must be quality assured as applicable and as specified in
						  this section. Offshore petroleum and natural gas production facilities must
						  adhere to the monitoring and QA/QC requirements as set forth in 30 CFR Part 250
						  (July 1, 2011), which is hereby incorporated by reference.
(a) Facility operators must use any of the
						methods described as follows in this paragraph to conduct leak detection(s) of
						equipment leaks and through-valve leakage from all source types listed in
						sections 95153(i), (m), (n) and
						(o) that occur during a calendar year, except
						as provided in paragraph (a)(4) of this section.
(1)
Optical gas imaging
						instrument
. Use an optical gas imaging instrument for equipment leak
						detection in accordance with 40 CFR Part 60 , subarticle A, §
													60.18 of the
Alternative
						work practice for monitoring equipment leaks
, §
													60.18(i)(1)(i);
						§
													60.18(i)(2)(i)
						except that the monitoring frequency shall be annual using the detection
						sensitivity level of 60 grams per hour as stated in 40 CFR Part 60 , subarticle
						A, Table 1:
Detection Sensitivity Levels
; §
													60.18(i)(2)(ii) and
						(iii) except the gas chosen shall be methane,
						and §
													60.18(i)(2)(iv) and
						(v); §
													60.18(i)(3);
						§
													60.18(i)(4)(i) and
						(v); including the requirements for daily
						instrument checks and distances, and excluding requirements for video records
						(July 1, 2011, which is hereby incorporated by reference). Any emissions
						detected by the optical gas imaging instrument is a leak unless screened with
						Method 21 ( 40 CFR Part 60 , appendix A-7 (July 1, 2011), which is hereby
						incorporated by reference) monitoring, in which case 10,000 ppm or greater is
						designated a leak. In addition, facility operators must operate the optical gas
						imaging instrument to image the source types required by this subarticle in
						accordance with the instrument manufacturer's operating parameters. Unless
						using methods in paragraph (a)(2) of this section, an optical gas imaging
						instrument must be used for all source types that are inaccessible and cannot
						be monitored without elevating the monitoring personnel more than two meters
						above a support surface.
(2)
Method 21.
Use the equipment leak detection methods in 40 CFR
						Part 60 , appendix A-7, Method 21 (July 1, 2011). If using Method 21
						monitoring, if an instrument reading of 10,000 ppm or greater is measured, a
						leak is detected. Inaccessible emissions sources, as defined in 40 CFR Part 60
						, are not exempt from this subarticle. Owners or operators must use alternative
						leak detection devices as described in paragraph (a)(1) or (a)(2) of this
						section to monitor inaccessible equipment leaks or vented emissions.
(3)
Infrared laser beam illuminated
						instrument.
Use an infrared laser beam illuminated instrument for
						equipment leak detection. Any emissions detected by the infrared laser beam
						illuminated instrument is a leak unless screened with Method 21 monitoring, in
						which case 10,000 ppm or greater is designated a leak. In addition, the
						facility operator must operate the infrared laser beam illuminated instrument
						to detect the source types required by this subarticle in accordance with the
						instrument manufacturer's operating instructions.
(4)
Optical gas imaging
						instrument.
An optical gas imaging instrument must be used for all
						source types that are inaccessible and cannot be monitored without elevating
						the monitoring personnel more than 2 meters above a support surface.
(5)
Acoustic leak detection
						device
. Use the acoustic leak detection device to detect through-valve
						leakage. When using the acoustic leak detection device to quantify the
						through-valve leakage, use the instrument manufacturer's calculation methods to
						quantify the through-valve leak. When using the acoustic leak detection device,
						if a leak of 3.1 scf per hour or greater is calculated, a leak is detected. In
						addition, the facility operator must operate the acoustic leak detection device
						to monitor the source valves required by this subarticle in accordance with the
						instrument manufacturer's operating parameters. Acoustic stethoscope type
						devices designed to detect through valve leakage when put in contact with the
						valve body and that provide an audible leak signal but do not calculate a leak
						rate can be used to identify non-leakers with subsequent measurement required
						to calculate the rate if through-valve leakage is identified. Leaks are
						reported if a leak rate of 3.1 scf per hour or greater is measured. In
						addition, the facility operator must operate the acoustic leak detection device
						to monitor the source valves required by this subarticle in accordance with the
						instrument manufacturer's operating parameters.