Document ID: chunk:federal_register_of_legislation:F2024C00833:reg:8:p1
Version: federal_register_of_legislation:F2024C00833
Segment Type: reg
Provision Reference: reg 8 (pt 1/2)
Character Range: 434895–437647

8     Other—leaker                              5.88 × 10‑3                            tonnes CO2‑e / component ‑ hour

 (4) For subsection (3), the LDAR program must survey each component used in natural gas liquefaction, storage and transfer at the facility at least once in a reporting year in accordance with:
         (a)  paragraph 98.234(a)(1) of Title 40, Part 98 of the Code of Federal Regulations, United States of America using optical gas imaging with a sensitivity of 60 grams per hour; or
         (b) the method outlined in USEPA Method 21—Determination of organic volatile compound leaks, as set out in Appendix A‑7 of Title 40, Part 60 of the Code of Federal Regulations, United States of America where a leaker is detected if 10,000 parts per million or greater is measured consistent with that method; or
         (c) an equivalent leak detection standard.
 (5) To determine whether a component is a leaker or non leaker at a period of time:
         (a)  if a leak is detected in a survey the component is assumed to leak from the later of the beginning of the reporting year or last survey where it was a non leaker; and
         (b)  after a leak is detected in a survey the component is assumed to leak until the earlier of the end of the reporting year or the next survey where it is a non leaker.

Division 3.3.8—Natural gas distribution (other than emissions that are flared)

3.79  Application
  This Division applies to fugitive emissions from natural gas distribution activities.

3.80  Available methods
 (1) Subject to section 1.18 and subsections (2) and (3), one of the following methods must be used for estimating fugitive emissions (other than emissions that are flared) of each gas type, being carbon dioxide and methane, released during a year from the operation of a facility that is constituted by natural gas distribution through a system of pipelines:
 (a) method 1 under section 3.81;
 (b) method 2 under section 3.82;
 (c) method 3 under section 3.82A.
Note: There is no method 4 for this Division.
 (2) However, for incidental emissions another method may be used that is consistent with the principles in section 1.13.
 (3) Method 3 may only be used if the percentage of unaccounted for gas for a facility is calculated or determined during a reporting year in accordance with gas market rules or procedures applicable to the facility.
Note: A percentage of unaccounted for gas is generally worked out under procedures made by the Australian Energy Market Operator and available on their website: www.aemo.com.au

3.81  Method 1—natural gas distribution
 (1) Method 1 is
Ejp = Sp × %UAGp × 0.373 × Cjp
where:
Ejp is the fugitive emissions of gas type (j) that result from natural gas distribution through a