(1) Beginning March 15, 2021, and on an annual basis thereafter, each gas pipeline company must submit a report to the commission that includes:
(a) The total number of known leaks in pipelines owned by the gas pipeline company as of January 1st of the year the report is submitted;
(b) The total number of hazardous leaks eliminated or repaired during the previous one-year period ending December 31st;
(c) The total number of nonhazardous leaks eliminated or repaired during the previous one-year period ending December 31st;
(d) The total number of leaks scheduled for repair in the next one-year period beginning January 1st of the year the report is submitted. The data provided in this subsection (1)(d) does not obligate the gas pipeline company to repair all leaks scheduled for repair, nor does it prevent the gas pipeline company from prioritizing its repair schedule based on new information and newly-identified leaks.
(2) Natural gas leaks include all confirmed discoveries of unintentional leak events, including leaks from: Corrosion failure; natural force damage; excavation damage; other outside force damage; pipe, weld, or joint failure; equipment failure; or other causes.
(3) The commission may determine information requirements for the annual reports submitted under subsection (1) of this section including, but not limited to:
(a) The approximate date and location of each leak from the gas pipeline system detected by the company during its routine course of inspection;
(b) The approximate date and location of each leak caused by third-party excavation or other causes not attributable to the normal operation or inspection practices of the company;
(c) Whether the reported leaks are included as part of a filing submitted and approved by the commission under RCW
80.28.420;
(d) The volume of each leak, measured in carbon dioxide equivalents and thousands of cubic feet, except that where an exact volume of gas leaked cannot be identified, a gas pipeline company may provide its best approximation;
(e) Whether the identified cause of each leak was from: Corrosion failure; natural force damage; excavation damage; other outside force damage; pipe, weld, or joint failure; equipment failure; or other causes;
(f) The estimated market value of lost gas and the methodology used to measure the loss of gas; and
(g) Any additional information required in an order approved by the commission.
(4) The commission must use the data reported by gas pipeline companies under this section, as well as other data reported by gas pipeline companies to the commission and to the department of ecology, to estimate the volume of leaked gas and associated greenhouse gas emissions from operational practices in the state. The commission may request additional information by order.
(5) By March 31, 2021, and on an annual basis thereafter, the commission must provide on its public internet website aggregate data, as submitted by gas pipeline companies under this section, concerning the volume and causes of gas leaks.
(6) By March 31, 2021, and on an annual basis thereafter, the commission must transmit to the department of ecology information on gas leakage in the state, as submitted by gas pipeline companies under this section.
(7) Those portions of reports submitted by gas pipeline companies to the commission under this section that contain proprietary data, trade secrets, or if disclosure would adversely affect public safety, are exempt from public inspection and copying under chapter
42.56 RCW.
(8) For the purposes of this section, "carbon dioxide equivalents" has the same meaning as provided in RCW
70A.45.010.
(9) Nothing in this section may be construed to preempt the process by which a gas pipeline company is required to petition relevant state or local authorities when seeking to expand the capacity of the company's gas transmission or distribution lines.
