Md. Code Regs. 26.11.41.03

Current through Register Vol. 51, No. 24, December 2, 2024

Section 26.11.41.03 - Leak Detection and Repair Requirements

A. Affected facilities that are natural gas compressor stations or natural gas underground storage facilities and that use natural gas-powered equipment to compress natural gas shall comply with the following leak detection and repair requirements.

(1) Owners and operators of affected facilities subject to this section shall develop and submit to the Department an initial methane emissions monitoring plan that includes a technique for determining fugitive emissions (for example, EPA Method 21 at 40 CFR part 60, appendix A-7, or optical gas imaging).

(2) If an affected facility uses optical gas imaging for leak detection, the following information shall be included in the initial methane emissions monitoring plan:

(a) A list of the unsafe-to-monitor components;

(b) Procedures and time frames for identifying and repairing fugitive emissions components;

(c) A defined observation path throughout the site to confirm all components can be viewed and recorded;

(d) Manufacturer and model number of fugitive emissions detection equipment to be used; and

(e) Equipment specifications and procedures as specified in 40 CFR § 60.5397a(c)(7), as published in July 2017.

(3) If an affected facility uses EPA Method 21 ( 40 CFR 60, Appendix A-7) for leak detection, the following information shall be included in the initial methane emissions monitoring plan:

(a) A list of all fugitive emission components, difficult-to-monitor components, and unsafe-to-monitor components at an affected facility;

(b) Procedures and time frames for identifying and repairing fugitive emission components; and

(c) Equipment specifications and procedures as specified in 40 CFR § 60.5397a(c)(8), as published in July 2017.

(4) Each difficult-to-monitor and unsafe-to-monitor component shall be identified in the written initial methane monitoring plan explaining the location and why the fugitive emissions components are difficult-to-monitor and unsafe-to-monitor.

(5) Initial Methane Emissions Monitoring Plan Submission.

(a) Except for a new natural gas compressor station or natural gas underground storage facility, owners and operators of the affected facilities subject to this section shall submit the initial methane emissions monitoring plan required in §A(1)-(4) of this regulation to the Department within 90 days of the adoption of this regulation.

(b) Owners and operators of a new natural gas compressor station or natural gas underground storage facility subject to this section shall submit the initial methane emissions monitoring plan required in §A(1)-(4) of this regulation to the Department within 60 days of startup.

(6) Owners and operators of affected facilities that modify or reconstruct a natural gas compressor station or underground storage facility shall submit an initial monitoring plan with the elements in §A(1)-(4) of this regulation within 90 days of the facility startup operation for each new collection of fugitive emissions components at the modified or reconstructed compressor station or underground storage facility.

(7) Owners or operators of affected facilities subject to this section shall conduct an audio, visual, and olfactory inspection of all fugitive emission components for leaks or indications of leaks at least once per calendar week except for:

(a) Unsafe-to-monitor components; and

(b) Natural gas storage wells and observations, which shall conduct audio, visual, and olfactory inspections according to §A(10) of this regulation.

(8) Leak Monitoring Survey.

(a) Owners and operators of affected facilities shall follow the initial monitoring methane plan and shall inspect all fugitive emission components, except for unsafe-to-monitor components, for leaks using OGI or EPA Method 21 within 180 days of the adoption of this chapter and quarterly thereafter.

(b) Owners and operators of affected facilities that install any new, modified, or reconstructed natural gas compressor station or underground storage facility that uses natural gas-powered equipment to compress natural gas shall meet the requirements of §A(8)(a) of this regulation within 180 days of the startup of the facility's operations.

(c) At least annually, all difficult-to-monitor fugitive emissions components shall be inspected for leaks using an OGI camera.

(9) Repair Requirements.

(a) Any leaking fugitive emissions component identified during a leak monitoring survey or audio, visual, and olfactory inspection shall be successfully repaired, replaced, or removed from service as soon as practicable, but no later than 30 calendar days after leak detection.

(b) Fugitive Emissions Component Resurvey.

(i) Each repaired or replaced fugitive emissions component shall be resurveyed within 30 days after being repaired or replaced using either OGI or EPA Method 21 ( 40 CFR 60, Appendix A-7).

(ii) Owners and operators of facilities subject to this section that use EPA Method 21 ( 40 CFR 60, Appendix A-7) to resurvey the repaired or replaced fugitive emissions component shall consider the fugitive emissions component repaired when the EPA Method 21 ( 40 CFR 60, Appendix A-7) instrument indicates a concentration of less than 500 ppm of methane or when no soap bubbles are observed during a bubble test.

(iii) Owners and operators of affected facilities subject to this section that use OGI to resurvey the repaired or replaced fugitive emissions component shall consider the fugitive emissions component repaired when the OGI instrument shows no indication of visible emissions or when no soap bubbles are observed during a bubble test.

(c) A delay of repair may occur when, upon request, the owner or operator provides documentation to the Department that supports the following:

(i) The parts or equipment required to make necessary repairs will take longer than 30 days to be ordered and delivered, but the repair may not exceed 1 year;

(ii) The repair is unsafe to perform during the operation of the unit; or

(iii) The repair requires a blowdown or facility shutdown in order to complete.

(d) Leaking fugitive emission components awaiting repair or replacement under a delay of repair shall be clearly marked or identified in the facility's records.

(e) Leaking fugitive emission components under a delay of repair according to §A(9)(c)(i) of this regulation shall:

(i) Be repaired or replaced within 7 days after the owner or operator receives parts or equipment; or

(ii) Be repaired or replaced at the next vent or compressor station blowdown if the owner or operator has identified this fugitive emission component as needing a vent or compressor station blowdown.

(f) Fugitive emission components under a delay of repair according to §A(9)(c)(ii) and (iii) of this regulation shall be repaired or replaced within 1 year, at the next vent blowdown or facility shutdown, whichever occurs first.

(g) If a repair of a leak cannot be successfully completed according to this subsection, the owner or operator of the affected facility shall prepare a plan, for Department approval, that includes:

(i) An explanation of the technical difficulty;

(ii) A timeline to successfully repair the fugitive emission components;

(iii) A calculation of the additional methane that is expected to be released while on delay of repair; and

(iv) Upon written request from the Department, any other information that the Department determines is necessary to evaluate the plan.

(h) The owner or operator of the affected facility shall submit any plan required under §A(9)(g) of this regulation to the Department within 30 days from identifying the leak.

(10) Natural Gas Storage Field Inspections.

(a) Owners and operators of natural gas underground storage facilities shall conduct an audio, visual, and olfactory inspection of every natural gas storage well and observation well in the natural gas storage field at least once each month.

(b) For each inspection according to §A(10)(a) of this regulation, owners and operators shall record:

(i) The well-head pressure or water level measurement, as appropriate;

(ii) The open flow on the annulus of the production casing or the annulus pressure if the annulus is shut in;

(iii) A measurement of gas escaping the well if there is evidence of a gas leak; and

(iv) Evidence of progressive corrosion, rusting, or other signs of equipment deterioration.

(c) For each natural gas storage well with emissions that exceed 1,440 cubic feet per day, owners and operators shall:

(i) Notify the Department within 1 business day of discovering the emission rate exceedance; and

(ii) File a written report within 10 days which shall include an explanation of the problem and corrective action taken or planned.

(d) For each audio, visual, and olfactory inspection that detects a leaking fugitive emission component, the owner and operator shall comply with the repair requirements specified in §A(9) of this regulation, as applicable.

B. Affected facilities that are natural gas compressor stations and natural gas underground storage facilities, that exclusively use electric-powered equipment to compress natural gas, shall comply with the following leak detection and repair requirements.

(1) Owners and operators of facilities in this section shall meet the requirements of §A(1)-(6), (9), and (10) of this regulation.

(2) Except for unsafe-to-monitor components, owners or operators of facilities in this section shall conduct an audio, visual, and olfactory inspection of all fugitive emission components for leaks or indications of leaks at least once per calendar month.

(3) Leak Monitoring Survey.

(a) Except for unsafe-to-monitor components, owners and operators of affected facilities subject to this section shall inspect all fugitive emission components, including difficult-to-monitor components, for leaks using OGI or EPA Method 21 ( 40 CFR 60, Appendix A-7) within 180 days of the adoption of this chapter and annually thereafter.

(b) Owners and operators of affected facilities that install any new, modified, or reconstructed natural gas compressor station or underground storage facility that uses electric-powered equipment to compress natural gas shall meet the requirements of §B(3)(a) of this regulation within 180 days of the startup of the facility's operations.

C. Cove Point Liquefied Natural Gas facility shall comply with:

(1) The leak detection and repair requirements as specified by the Climate Action Plan, which is defined, prepared, and approved under COMAR 26.09.02.06.B - E; and

(2) The leak detection and repair plan defined and approved under the Certificate of Public Convenience and Necessity, issued by the Maryland Public Service Commission on May 30, 2014, Order No. 86372, Case No. 9318, as amended on February 6, 2018, with Order No. 88565, and Errata on February 23, 2018, Order No. 88565, as amended.

D. Any new liquefied natural gas facility that begins operations or repairs after the effective date of this chapter shall comply with §A of this regulation.

E. If an owner requests approval, the Department may approve a new technology or alternative practice to identify leaking fugitive emissions components as an equivalent substitution for the requirements in §A or B of this regulation.

Md. Code Regs. 26.11.41.03

Regulation .03 adopted effective 47:23 Md. R. 978, eff. 11/16/2020