CPUC General Order 112-F § 123 - ANNUAL REPORTS

123.1Each Operator shall submit to the DOT, with a copy to the CPUC, annual reports and mechanical fitting failure reports as required by 49 CFR, Part 191, §§191.11, 191.12 and 191.17. Such reports shall be submitted in the manner prescribed in 49 CFR Part 191.#

123.2At the same time copies of the reports required by paragraph 123.1 are submitted, each utility shall submit, in a format and guidance provided by the Commission’s Safety and Enforcement Division or its successor, the following information to demonstrate to the Commission and the public an utility’s efforts towards minimizing the risk from system leaks and failures:#

a)Number of gas leaks repaired associated with grades, causes, pipeline materials, sizes, and decades of installation.#

b)For leaks repaired in the calendar year, show time between finding the leak and its repair in intervals of 0-3 months; 3-6 months; 6-9 months; 9-12 months; 12-15 months; and greater than 15 months. For the aggregated value of leaks repaired greater than 15 months, segregate the value into leaks that are never regraded; regraded once; regarded twice; regraded three times; and regraded more than three times.#

c)Response times in five-minute intervals, segregated first by business hours (0800 – 1700 hours), after business hours and weekends/legal state holidays, and then by Division, District, and/or Region, to reports of leaks or damages reported to the utility by its own employees or by the public. The intervals start with 0-5 minutes, all the way to 40-45 minutes, an interval of 45-60 minutes and then all response times greater than 60 minutes.#

The timing for the response starts when the utility first receives the report and ends when an utility’s qualified representative determines, per the utility’s emergency standards, that the reported leak is not hazardous or the utility’s representative completes actions to mitigate a hazardous leak and render it as being non-hazardous (i.e., by shutting-off gas supply, eliminating subsurface leak migration, repair, etc.) per the utility’s standards. In addition, the utility must report, using the same intervals, the times for the first company responder to arrive on scene.#

d)The number of events in which pressure in any pipeline facility exceeded the maximum allowable operating pressure (MAOP) by 50% or more of the build-up allowed for by 49 CFR § 192.201. For any transmission pipeline facility where the utility applies the provisions of 49 CFR § 192.917 (e)(3) or (e)(4), any increases above the maximum operating pressure must be reported. Also, for low-pressure systems (i.e., inches of water column pressure), all pressure increases above MAOP must be reported. Increases in pressure above MAOP resulting from planned, designed, testing, or other intentional operations performed per procedures or process established by the utility are exempted from this requirement. For purposes of reporting, “events” includes each occurrence of overpressurization that develops between overpressurization being noted and maintenance being performed.#

e)The amount of time it takes for changes, repairs, or new facilities to be finalized and updated, per the utility’s procedures, to the utility’s facilities maps. The provided information shall show the number of facilities mapped segregated into the following time intervals:#

1.Less than 14 days;#

2.More than 14 days, but less than 30 days;#

3.More than 30 days, but less than 90 days;#

4.More than 90 days, but less than 180 days;#

5.More than 180 days, but less than 360 days;#

6.More than 360 days.#

f)The number of employees, by operating Division, District, Region, or Other (i.e., an employee of a mobile workforce not assigned to Division, District, or Region) evaluated, and those disqualified after evaluations, performed by the utility per 49 CFR§ 192.805 (d) or (e).#

g)The 32 metrics required to be tracked per 49 CFR § 192.945(a) and ASME B31.8S, Chapter 9, Table 9.#

h)Excavation Damage Prevention Related Data#

1.Number of excavation damages and related costs involving homeowners;#

2.Number of damages and related costs involving agencies (i.e., Caltrans, non-pressurized sewer, etc.) excluded per California Government Code 4216 (GC4216);#

3.Number of person-days, along with total costs, devoted to: i) excavation field meetings (per GC4216); and ii) stand-by activities for preventing damage to subsurface facilities during an excavation;#

4.Number of person-days, along with total costs, devoted to: i) mark and locate activities (per GC 4216); and ii) all other subsurface damage prevention activities excluding those from paragraph 3 above.#

i)Lost and Unaccounted For Gas (LUAF Gas)#

1.A listing of the different causes of LUAF Gas that the utility tracks as part of its operations; and#

2.An accounting of the contribution by each of the different causes of LUAF Gas, actual and/or estimated values, which factor into the aggregated LUAF Gas value provided by the utility on all reports submitted pursuant to subsection 123.1. An utility must provide details on how each estimated value is derived.#

j)Public Liaison Activities#

1.The number of public liaison activities scheduled by the utility and the number of public liaison activities actually performed along with details to explain what caused the difference between the scheduled and performed liaison activities.#

2.A summary of public agencies (by county and agency name) to which the utility provided notice of, and made available for participation, its annual liaison sessions during each of the five calendar years preceding the reporting year. The summary must also denote which agencies were able to have representation at the session.#

3.In an effort to provide a convenient resource for the public to use towards confirming that utilities and first responders continue to work together in better coordinating responses to emergencies, each utility shall make the same information provided per paragraph 2 above available on its website with a link to the same information provided on the CPUC website. Attendance of agencies at liaison sessions is voluntary and may be dependent on agencies having to allocate resources to emergencies that occur when sessions are scheduled.#

k)Gas Safety Plan#

1.Each utility must submit a Gas Safety Plan, as codified by Pub. Util. Code §§ 961 and 963, and as ordered by the Commission in D.12-04-010.#

2.Each utility must make any modifications to its Gas Safety Plan identified by the Commission’s Safety and Enforcement Division, or its successor.#

123.3All information submitted by an utility pursuant to paragraph 123.2 shall be submitted with verification, under penalty of perjury, from a senior officer of the utility, at the level of Vice-President or above, stating that the facts contained in the information are true and correct to the best knowledge of that senior officer.#