Get Full Government Meeting Transcripts, Videos, & Alerts Forever!
Get email alerts on the Gas Operations topic
No spam. Unsubscribe anytime.
PG&E gas operations seek $1.1B expense, $2.2B capital for 2027; proposes expanded inline inspection and pipe replacements
Summary
PG&E’s Exhibit 3 proposes expanded distribution and transmission programs including 64 miles per year of distribution replacement, upgrades to make 960 miles of transmission pickable for inline inspection, valve automation and strength testing. PG&E forecasts $1.1 billion in test‑year expense and $2.2 billion in capital for gas operations.
PG&E presented detailed forecasts for gas operations in Exhibit 3, asking the commission to approve a test‑year expense forecast of $1,100,000,000 and capital of $2,200,000,000 for 2027. Jessica Campbell, the Exhibit 3 case manager, said the filing proposes 64 miles per year of distribution pipe replacement (described by the company as 39 miles per year of pre‑1985 assets and 25 miles per year of pre‑1941 steel main) and identified 960 miles of transmission that have been made ‘‘pickable’’ for inline inspection.
Campbell said PG&E is forecasting $89,600,000 for inline inspection (ILI) runs, with an additional $64,300,000 forecast for remediation work driven by ILI anomaly findings. The company is also proposing a transmission integrity strength testing (TIMP) forecast of $77,100,000 to support compliance with 49 CFR Subpart O and to reduce reliance on less effective assessment methods.
Other notable proposals include automating approximately 40 transmission valves to enable 30‑minute or less remote isolation of critical zones, and a locate‑and‑mark forecast supporting roughly 600,000 response calls over the rate case cycle to reduce third‑party dig‑ins. Jessica Campbell told the workshop that 714 miles of pipeline were reclassified from transmission to distribution under a revised definition and that forecasts reflect that reclassification.
PG&E also described an Alternative Energy Program (AEP) that provides incentives for full conversions from gas to electric; Campbell said the company has converted 19 customers so far and has set a target to convert more customers during the rate case period. When asked, PG&E representatives confirmed AEP’s current incentives apply to full conversions rather than partial equipment swaps.
All gas proposals were presented as requests in the rate case; no CPUC decisions were made at the workshop. The company said more program details and supporting work papers are available in the exhibit attachments.
