Item 7
1 VALLEY CLEAN ENERGY ALLIANCE
Staff Report – Item 7
To: Board of Directors
From: Keyes & Fox, Regulatory Consultant
Subject: Regulatory Monitoring Report – Keyes & Fox
Date: September 10, 2026
______________________________________________________________________________ Please find attached Keyes & Fox’s August 2026 Regulatory Memorandum dated September 2, 2026 an informational summary of the key California regulatory and compliance-related updates from the California Public Utilities Commission (CPUC).
Attachment: Keyes & Fox Regulatory Memorandum dated September 2, 2026
1 Valley Clean Energy Alliance
Regulatory Monitoring Report
To: Valley Clean Energy Alliance (VCE) Board of Directors From: Sheridan Pauker, Partner, Keyes & Fox LLP
Jason Hoyle, Director of Research, EQ Research LLC
Subject: Monthly Regulatory Update
Date: September 2, 2026
Keyes & Fox LLP and EQ Research LLC are pleased to provide VCE’s Board of Directors with this informational memo describing key California regulatory and compliance-related updates from the California Public Utilities Commission (CPUC) over the past two months.
RPS Rulemaking
Background: This proceeding addresses ongoing Renewables Portfolio Standard (RPS) requirements, including legislative mandates, and other matters related to the purchase of renewable energy. This proceeding is the forum for review of VCE’s RPS Procurement Plan and RPS Compliance reports.
Recent Developments: Comments on draft RPS plans were filed on July 13 and reply comments were filed on July 27.
VCE’s Final Compliance Report for Compliance Period 4 (2021-2024) was filed on August 24.
Analysis: VCE’s Final Compliance Report for Compliance Period 4 shows that VCE met its RPS procurement requirement for the Compliance Period and procured additional renewable energy above its RPS target to meet its own internal goals.
Additional Information: VCE’s Final Compliance Report for CP4 (Aug. 24, 2026); Final Resolution E-5457 (Jun. 12, 2026); VCE Draft 2026 RPS Procurement Plan (Jun. 12, 2026); Scoping Memo and Ruling (May 9, 2024); OIR (Feb. 1, 2024); Docket No. R.24-01-017.
PCIA/ERRA Reform
Background: This Rulemaking considers updates and reforms to the ERRA and Power Charge Indifference Adjustment (PCIA) rules and processes with the objectives of improving existing rules, mitigating rate volatility, and ensuring indifference among bundled and departing customers. Track 1 concluded in 2025, Track 2’s scope was revised to consider issues related to the valuation of pre-2019 RECs arising from 2026 ERRA forecast proceedings, and Track 3 will address broader issues in Track 3A and Track 3B.
Recent Developments: On August 13, the CPUC issued a Proposed Decision resolving Track 2 issues and setting the value of pre-2019 banked RECs at zero dollars. Oral arguments were held on August 31. A Track 3 Scoping Memo and Ruling was issued on August 18 establishing Track 3A and Track 3B. Track 3 will address broader reforms to the PCIA mechanism, market-price benchmarks, and policy guidance for ratemaking proceedings, with Track 3A focused on refining the existing PCIA structures and Track 3B focused on changes to the structural PCIA framework.
Analysis: A zero-dollar valuation for pre-2019 banked RECs means that CCA customers who departed IOU generation service after 2019 paid for the RECs at the time they were created and will receive no compensation from the remaining IOU bundled customers who will now use them to reduce RPS compliance costs.
Next Steps: The Proposed Decision on pre-2019 banked REC valuation may be heard as soon as the September 17 Commission meeting. Comments on the Proposed Decision are due September 2 and reply comments are due September 8. A staff report or proposal in Track 3A is expected in October, followed by party proposals in late 2026/early 2027, and a Q1 2027 workshop.
Additional Information: Scoping Memo and Ruling (Aug. 18, 2026); Proposed Decision (Aug. 13, 2026); Ruling (Jun. 19, 2026); Ruling on hearing (May 28, 2026); Track 3 Workshop Ruling (May 13, 2026); Ruling (Apr. 24, 2026); Ruling and Staff Report (Mar. 27, 2026); Ruling (Feb. 20, 2026); Amended Scoping Memo (Feb. 3, 2026); Ruling (Dec. 26, 2025); CalCCA Petition for Writ of Review (Dec. 1, 2025); D.25-06-049 (Jun. 27, 2025); Scoping Memo (Apr. 8, 2025); ALJ Ruling (Mar. 21, 2025); Ruling & Staff Report on RA MPB (Feb. 26, 2025); OIR (Feb. 26, 2025); Docket No. R.25-02- 005.
2 RA Rulemaking
Background: This proceeding is the successor to R.23-10-011, and it will address the 2027 and 2028 RA compliance years, local RA obligations for the 2027-2029 and 2028-2030 compliance years, further refinements to the 24-hour Slice-of-Day (SOD) framework. Track 1 considered accreditation for long-duration energy storage, unforced capacity outage rates for thermal resources, accreditation for solar and wind resources, and transactability within the SOD framework during the first half of 2026. Track 2 addresses the planning reserve margin and coordination with the integrated resource plan proceeding.
Recent Developments: On July 2, the CPUC issued D.26-07-008 adopting local capacity obligations for 2027-2029, flexible capacity obligations for 2027 and making other program refinements. The Decision adjusts bidding rules and treatment of revenue for certain RA-related product transactions in the CAISO’s new extended day-ahead market (EDAM). The modified rules will only apply to new resource contracts. On August 17, an ALJ Ruling provided the draft results of Energy Division’s Loss of Load Expectation Study for 2028, but no planning reserve margin (PRM) for the 2028-2029 RA years was proposed. On August 25, the CPUC issued a Scoping Memo and Ruling for Track 2 which addresses RA requirements for 2028-2030, the 2028 and 2029 planning reserve margin, the RA penalty structure, and other RA counting and accreditation topics.
Analysis: D.26-07-008 imposes restrictions on CPUC-jurisdictional activity in CAISO’s EDAM beyond those imposed on other market participants. The EDAM began operating during Spring 2026 with a single external participant but will expand to include utilities across a broader Western U.S. geography over the next couple of years. The full impacts of the EDAM restrictions on CPUC-jurisdictional participants are unknown and may change as the market adds new participants, but the restrictions may result in higher procurement costs for newly contracted resources.
Next Steps: A final PRM recommendation for the 2028-2029 RA years will be included in the final report from Energy Division, expected to be released in October.
Additional Information: Scoping Memo and Ruling (Aug. 25, 2026); Ruling and Draft Loss of Load Expectation Study for 2028 (Aug. 17, 2026); D.26-07-008 (Jul. 2, 2026); Scoping Memo (Dec. 12, 2025); OIR (Oct. 15, 2025); Docket No.
R.25-10-003.
PG&E 2027 ERRA Forecast
Background: The annual Energy Resource and Recovery Account (ERRA) forecast proceedings establish the amount of the Power Charge Indifference Adjustment (PCIA) and other non-bypassable charges (NBCs) for the following year, as well as fuel and purchased power costs associated with serving bundled customers that utilities may recover in rates.
Recent Developments: On August 3, the CPUC issued a Scoping Memo and Ruling. On August 28, PG&E submitted Advice Letter 7972-E providing notice that its ERRA account balance surpassed the 5% trigger threshold and is forecast to self-correct within 120 days. As of the end of July 2026, PG&E had over-collected $225 million, of 5.4% of the prior-year generation revenue and the account is projected to end 2026 with an over-collection of $120 million, or 2.9% of the prior-year generation revenue.
Analysis: CalCCA filed testimony on August 27 addressing PG&E’s Slice of Day RA valuation methodology; its approach to RA valuation more broadly; its treatment of Unsold RPS volumes; its data center load forecasting; and its treatment of its General Rate Case revenue requirement, among other things.
Next Steps: PG&E’s rebuttal testimony is due September 16, and the Fall Update is due October 16 to be followed by a proposed decision in November with issuance of a final decision in late 2026.
Additional Information: PG&E AL 7972-E (Aug. 28, 2026); Scoping Memo and Ruling (Aug. 3, 2026); Ruling (Jun. 18, 2026); Application (May 15, 2026); Docket No. A.26-05-007.
IRP Rulemaking (2025)
Background: This proceeding governs the biennial Integrated Resource Plan (IRP) process, including load serving entity (LSE) procurement requirements, the establishment of a variety of state- and LSE-level load and procurement forecasts, greenhouse gas (GHG) reduction targets, ongoing reliability obligations, and the Commission’s oversight of the IOUs’ bundled procurement plans. This proceeding continues the work of R.20-05-003 and will be the primary forum for most future CPUC work on the Reliable and Clean Power Procurement Program framework (RCPPP).
Recent Developments: Opening comments on the RCPPP were filed on August 14. CalCCA’s comments recommended against the adoption of Staff’s newly proposed Option 3 for reasons that include the Option’s potential for market interference and increased costs, and instead recommended adoption of Option 1 based on planning flexibility, accounting for load uncertainty and improved coordination across multiple compliance proceedings. VCE submitted its 2026 IRP on July 29. On August 17, an ALJ Ruling provided notice of a mid-September Energy Division staff workshop to discuss the IOUs’ bundled procurement plans (BPPs) and set deadlines for party comments on the BPPs. On August 28, Energy Division provided its 2030-2031 ELCC Study and Staff Memo and expects to have indicative Effective Load Carrying Capability (ELCC) values for 2032 by mid-September. On August 31, the CPUC issued a Ruling requesting
3 comments on recommended electricity resource portfolios for use in the CAISO’s 2027-2028 Transmission Planning Process (TPP).
Analysis: The base case portfolio for the 2026-2027 TPP modifies the GHG targets for 2030 and 2035 to 38 MMT and 30 MMT, respectively, excludes offshore wind for the first time in several years, includes roughly half of the long lead-time (LLT) resources determined by the Commission to be needed in D.24-08-064, increases geothermal resources to 7.2 GW, and sheds 1.8 GW of natural gas capacity by 2045. Notably, the base case portfolio uses the 2024 IEPR load forecast which has limited consideration of changes in data center and electrification loads.
Next Steps: Reply comments on the RCPPP are due September 2. Comments on IRP filings are due September 21. A staff workshop on the IOUs’ BPPs will be held on September 21, comments on the BPPs are due November 13, and reply comments are due November 30. A proposed decision on the IOUs’ proposed BPP updates is expected in Q4.
Comments on the TPP portfolios are due September 28 and reply comments are due October 12.
Additional Information: Ruling (Aug. 31, 2026); 2030-2031 ELCC Study and Staff Memo (Aug. 28, 2026); Ruling (Aug. 17, 2026); VCE’s 2026 IRP (Jul. 29, 2026); Ruling on RCPPP (Jul. 13, 2026); Scoping Ruling (Oct. 28, 2025); OIR (Jul. 2, 2025); Docket No. R.25-06-019.
PG&E 2027 Phase 1 GRC
Background: Phase 1 General Rate Case (GRC) proceedings determine PG&E’s overall revenue requirement and classification of costs by function for a set period (in this case, 2027-2030).
Recent Developments: Opening briefs were filed on July 2 and reply briefs were filed on July 23. On August 4, the CPUC issued a Proposed Decision that would grant PG&E authority to track new revenue requirements effective January 1, 2027, as an interim accounting measure (note this Proposed Decision does not resolve any substantive issues in the proceeding). On August 11, a Ruling granted PG&E’s motion for an update phase, allowing the Company to submit update testimony on labor cost changes and new tax costs, as well as granting party requests for an extended deadline for intervenor testimony.
Analysis: CalCCA’s briefing, while spanning a range of cost allocation and cost reduction issues, focused on proposals for re-vintaging eight hydro assets and removing 13 hydro assets from PG&E’s revenue requirement that erroneously remain on PG&E’s books. These issues of focus are detailed in CalCCA’s ex parte presentation submitted August 13.
Next Steps: The Proposed Decision authorizing PG&E to track revenue requirements may be heard as soon as the Commission’s October 8 meeting. Party proposals for an updated schedule for the update phase were filed September 1, and intervenor testimony on the update phase is due October 30. A proposed decision is expected in March 2027.
Additional Information: Ruling (Aug. 11, 2026); Proposed Decision (Aug. 4, 2026); Ruling (Jun. 18, 2026); Ruling (Apr. 24, 2026); Ruling on schedule (Feb. 26, 2026); Amended Scoping Memo and Ruling (Jan. 26, 2026); Ruling (Jan. 16, 2026); Resolution SPD-37 (Dec. 10, 2025); Ruling (Nov. 24, 2025); CalAdvocates/SBUA Motion (Nov. 6, 2025); Ruling (Sep. 25, 2025); Scoping Memo and Ruling (Jul. 31, 2025); Application (May 16, 2025); Docket No. A.25-05-009.
PG&E Billing System Modernization
Background: This proceeding addresses PG&E’s plan to upgrade its legacy billing system, some portions of which date back to the mid-1990s. PG&E proposed a three-stage upgrade that would ultimately be complete in Q4 2029 and cost an estimated $761.3 million.
Recent Developments: On July 9, PG&E and the Joint CCAs filed a Joint Motion for adoption of a settlement agreement, which was supported in comments filed by the City and County of San Francisco and partially opposed in comments filed jointly by CalAdvocates, The Utility Reform Network, and Small Business Utility Advocates. Opening briefs were filed on July 16 and reply briefs were filed on August 13. On August 25, the settling parties filed a Motion and Comments requesting the record be re-opened to admit additional information addressing party comments in opposition to the settlement motion.
Analysis: The proposed settlement, if approved by the Commission, would clear the path for implementation of PG&E’s long-overdue billing system improvements and eventually allow CCAs in PG&E’s service territory to implement many required advanced dynamic rates and load management standards. The Joint CCAs’ settlement recommendation include multiple specific changes related to bill presentation, data quality and access, reporting, rate implementation projects, CCA service fee updates, and PG&E’s proposed functionalization of the BMI revenue requirement, all of which support their efforts to ensure that PG&E’s billing system and cost allocation proposals do not confer an unfair competitive advantage upon PG&E.
Next Steps: Responses to the August 25 Motion are due September 9.
Additional Information: Motion (Aug. 25, 2026); Joint Motion (Jul. 9, 2026); Joint Case Management Statement (May 7, 2026); (Ruling (Mar. 10, 2026); Ruling (Feb. 5, 2026); Ruling (Feb. 3, 2026); Ruling (Dec. 12, 2025); Ruling (Nov. 18, 2025); Ruling (Sep. 11, 2025); Joint Case Management Statement (Aug. 20, 2025); D.25-08-008 (Aug. 19, 2025); Joint CCA Testimony (Jun. 30, 2025); Scoping Memo (Mar. 27, 2025); Application (Oct. 23, 2024); Docket No. A.24-10-014.
4 Disconnections and Reconnections
Background: This proceeding addresses approaches to the disconnection and reconnection of electric customers with a focus on improving energy access and cost containment.
Recent Developments: Public Participation Hearings on the joint emergency Motion to reduce the statewide temperature threshold for suspending utility disconnections from 100°F to 90° were held on August 6. On August 20, the CPUC issued D.26-08-009 extending the IOUs’ Arrearage Management Payment Plan to eligible residential customers until February 1, 2027 to synchronize with the sunset date for the Percentage of Income Payment Plan Pilot.
Analysis: N/A.
Next Steps: Public Participation Hearings will be held on August 6. A ruling or proposed decision on the joint emergency Motion is expected.
Additional Information: D.26-08-009 (Aug. 20, 2026); Ruling (Jun. 4, 2026); Joint Emergency Motion (May 28, 2026); PG&E Arrearage Management Plan Annual Report (May 1, 2026); CBO Pilot Recommendations (Dec. 11, 2025); Ruling granting extension (Oct. 21, 2025); Ruling (Oct. 13, 2025); D.25-06-012 (Jun. 17, 2025); Phase 2 Scoping Memo (Jul. 15, 2022); OIR (Jul. 20, 2018); Docket No. R.18-07-005.
PG&E Diablo Canyon 2027 & VPF
Background: During the period of extended operations for the Diablo Canyon Nuclear Plant, PG&E submits an annual application forecasting its costs, market revenues from CAISO, net costs allocated to ratepayers of each large IOU, and its plan for use of volumetric performance fees (VPFs) in the upcoming calendar year.
Recent Developments: On August 28, PG&E submitted the Joint Meet and Confer Report in which parties agreed evidentiary hearings are not needed but that disputed issues remain.
Analysis: Disputes among parties remain on the appropriate level of operations and maintenance costs, RA substitution capacity forecast and costs, whether the non-bypassable charge and rate proposals should be approved, whether the VPF spending plan should be approved, and as to whether PG&E’s testimony satisfies the requirements of previous decisions. These disputes directly impact both the costs and benefits that VCE’s customers receive from extended operations of the Diablo Canyon facility.
Next Steps: A proposed decision is expected in late October.
Additional Information: Joint Meet and Confer Report (Aug. 28, 2026); Scoping Memo and Ruling (Jun. 16, 2026); Application (Mar. 27, 2026); Docket No. A.26-03-031.
PG&E 2023 Phase 2 GRC
Background: Phase 2 General Rate Case (GRC) proceedings determine PG&E’s marginal cost of service and revenue requirement allocation among customer classes for a set period (in this case, 2023-2026). This proceeding is also considering extension of existing dynamic rate pilots (including VCE’s AgFIT pilot, now expanded across PG&E territory) and other real-time pricing (RTP) pilots as well as post-pilot dynamic rates required by the CEC’s Load Management Standards.
Recent Developments: On July 10, PG&E submitted a second settlement status report indicating that 30 settlement conferences were held as of July 10, including 13 between June 9 and July 10, the majority of which have been held by the Marginal Costs and Revenue Allocation (MCRA) settlement subgroup. The third settlement status report was submitted on August 7, indicating that an additional 23 settlement conferences were held since the second status report was submitted and that some contested issues were nearing settlement in principle. A July 22 Ruling confirmed that testimony in response to PG&E’s RTP Pilot stop-gap proposal is due September 30 from CalAdvocates and October 30 from other intervenors.
Analysis: According to the settlement status reports, CalCCA and PG&E have reached a preliminary agreement on two of the contested items raised in CalCCA’s testimony in the Primary Track of this proceeding.
Next Steps: Additional settlement status reports are due September 4 and October 2. Rebuttal testimony in the Primary Track is due October 9, and a meet and confer will be held October 19. A Ruling on the need for evidentiary hearings in the Primary Track is expected November 20. Testimony on PG&E’s RTP Pilot stop-gap proposal is due September 30 for CalAdvocates and October 30 for other intervenors.
Additional Information: Third Status Report (Aug. 7, 2026); Ruling (Jul. 22, 2026); Second Status Report (Jul. 10, 2026); Ruling modifying schedule (Jun. 17, 2026); PG&E Supplemental Testimony (Jun. 8, 2026); Motion for bifurcated track (Nov. 6, 2025); PG&E Testimony and Change Tables (Oct. 29, 2025); Scoping Memo (Mar. 21, 2025); Application (Sep. 30, 2024); Docket No. A.24-09-014.
Demand Response Enhancements
Background: This proceeding seeks to enhance demand response (DR) resources by updating guiding principles, policies, and data system and process requirements. Demand response development is closely connected to the
5 implementation of dynamic rates and real-time pricing (RTP), similar to VCE’s AgFIT Pilot, but across all customer classes.
Recent Developments: On July 7, a Ruling modified the bridge-year funding schedule to eliminate testimony, evidentiary hearing, and briefs from the schedule.
Analysis: N/A.
Next Steps: A proposed decision on bridge-year funding is expected during Q3.
Additional Information: Ruling (Jul. 7, 2026); Joint Case Management Statement (Jun. 11, 2026); Ruling (Apr. 8, 2026); D.26-03-016 on Flex Alert Funding (Mar. 26, 2026); Ruling on Staff Proposal on IOUs Bridge Year Funding (Mar. 10, 2026); Scoping Memo and Ruling (Feb. 12, 2026); OIR and Guiding Principles (Sep. 29, 2025); Docket No. R.25-09- 004.
Advanced Electric Rate Design
Background: This proceeding will establish advanced electric rate design policies, including rate structures and components such as time-of-use (TOU), demand charges, and the design of demand flexibility and dynamic rates.
Additionally, rate design options to support electrification for large commercial and industrial (C&I) customers, as well as rate design options for data centers and other large load customers will also be addressed.
Recent Developments: No recent developments.
Analysis: N/A.
Next Steps: A scoping memo and ruling is expected soon.
Additional Information: Ruling (May 22, 2026); OIR (Apr. 10, 2026); Docket No. R.26-04-009.
PG&E 2024 ERRA Compliance
Background: The annual ERRA Compliance proceeding reviews the utility’s compliance with CPUC-approved standards for generation-procurement and cost recovery activity occurring in the prior year, such as energy resource contract administration, least-cost dispatch, fuel procurement, and balancing account entries.
Recent Developments: No recent developments.
Analysis: N/A.
Next Steps: The parties anticipate the next step in this proceeding will be the issuance of a Proposed Decision.
Additional Information: Joint Settlement Motion (May 22, 2026); Ruling (Feb. 2, 2026); Ruling requiring supplemental testimony (Dec. 22, 2025); Joint Status Conference Statement (Nov. 25, 2025); Scoping Memo and Ruling (May 2, 2025); PG&E 2024 ERRA Compliance Application (Feb. 28, 2025); Docket No. A.25-02-013.
PG&E 2025 ERRA Compliance
Background: The annual ERRA Compliance proceeding reviews the utility’s compliance with CPUC-approved standards for generation-procurement and cost recovery activity occurring in the prior year, such as energy resource contract administration, least-cost dispatch, fuel procurement, and balancing account entries.
Recent Developments: No recent developments.
Analysis: N/A.
Next Steps: Intervenor testimony is due September 9, a joint status conference is scheduled for October 30, and a proposed decision is expected in 2Q 2027.
Additional Information: Scoping Memo and Ruling (May 26, 2026); Application (Feb. 27, 2026); Docket No. A.26-02- 019.
Climate Credit OIR
Background: This rulemaking will explore potential approaches to supporting customer affordability through cap-and-trade program proceeds returned to electric consumers via the state Climate Credit. The proceeding is divided into two tracks, and the current Track 1 has a Phase 1A and a Phase 1B. Phase 1A addressed the timing of the distribution of climate credits in 2026 and Phase 1B addresses broader changes in the residential Climate Credit.
Recent Developments: A July 9 Ruling adjusted the schedule. Parties filed opening comments on July 24 and reply comments on August 17 on topics related to Phase 1B. CalCCA’s comments emphasized the importance of equal treatment for bundled and unbundled customers, recommended the existing non-volumetric Climate Credit methodology be retained, and requirements that party proposals recommending changes include demonstration of justifications and benefits. Also on August 17, a Ruling provided direction for party proposals.
Analysis: N/A.
Next Steps: Party proposals on potential changes to the Climate Credit are due September 14, and a proposed decision is expected in Q1 2027.
6 Additional Information: Ruling (Aug. 17, 2026); Ruling (Jul. 9, 2026); D.26-04-036 (May 4, 2026); D.26-03-013 (Mar. 25, 2026); Scoping Memo and Ruling (Feb. 3, 2026); Ruling (Oct. 31, 2025); OIR (Aug. 20, 2025); Docket No. R.25-07-013.
Distribution Interconnection Rules
Background: This rulemaking will review and refine distribution-level interconnection rules under Electric Rule 21, particularly those for distributed energy resources (DER) for PG&E, SCE, SDG&E and the small and multijurisdictional electric utilities. Phase 1 will consider interconnection timelines and evaluation screens, and the interconnection process for resources not interconnecting under the net billing or net metering tariffs. Subsequent phases are undefined at present, but may address issues related to interconnection processes, pathways, and standards; sharing of upgrade costs; net billing and net metering interconnections; among other topics.
Recent Developments: On July 14, the CPUC issued a Ruling requiring the IOUs to provide information on Rule 21 interconnection applications.
Analysis: The Ruling specifically requests information necessary for the Commission to evaluate whether the $800 application fee for projects other than net metering or net billing represents the actual cost for the IOUs to process an interconnection application.
Next Steps: A scope for Phase 2 will be developed based on comments and workshop feedback from Phase 1.
Additional Information: Ruling (Jul. 14, 2026); Resolution E-5436 (May 4, 2026); Scoping Memo and Ruling (Mar. 3, 2026); OIR (Jul. 25, 2025); Docket No. R.25-08-004.
Building Decarbonization
Background: This proceeding explores reduction of greenhouse gas (GHG) emissions associated with energy use in buildings. The current Phase 4 will consider whether modifications to electric line extension rules would assist under-resourced customers, electric baseline allowance modifications to encourage building decarbonization, and new programmatic approaches to building decarbonization.
Recent Developments: On July 23, the CPUC issued a Scoping Ruling re-opening and amending Phase 3B for consideration of whether the implementation of D.23-12-037 creates an undue and disproportionate burden on the California Tribal Nation and Tribal members in response to a letter from the Morongo Band of Mission Indians. An August 14 Ruling provided notice of the Commission’s August 25 Tribal consultation.
Analysis: The amended scope specifically addresses whether D.23-12-037 should be amended to provide an exemption from the Decision’s elimination of the subsidy for electric line extensions for mixed-fuel new construction for buildings located on Tribal lands.
Next Steps: A proposed decision on the amended scope is expected in Q4 2026.
Additional Information: Ruling (Aug. 14, 2026); Scoping Ruling (Jul. 23, 2026); (Ruling on Extension (Apr. 7, 2026); Scoping Ruling (Mar. 30, 2026); PG&E AL 7642-E (Jul. 15, 2025); D.25-06-034 (Jun. 20, 2025); PG&E AL 5074-G/7615- E (Jun. 5, 2025); Scoping Memo and Ruling (Jul. 1, 2024); OIR (Feb. 8, 2019); Docket No. R.19-01-011.
City and County of San Francisco Municipalization
Background: The City and County of San Francisco (City or CCSF) filed this Petition in 2021 for a determination by the CPUC of just compensation for acquisition by the City of PG&E property (PG&E distribution and transmission assets to serve San Francisco) pursuant to Public Utilities Code §1401-1421.
Recent Developments: No recent developments.
Analysis: N/A.
Next Steps: PG&E’s opening testimony is due October 20 and intervenor testimony is due December 22.
Additional Information: CCSF Notice of Testimony (Apr. 20, 2026); Ruling (Apr. 2, 2026); PG&E Motion (Mar. 30, 2026); Ruling (Mar. 10, 2026); Ruling (Feb. 18, 2026); Ruling on CCSF Motion to Compel (Jan. 12, 2026); D.25-10-039 (Nov. 6, 2025); Amended Scoping Memo (Jul. 1, 2025); Petition (Jul. 27, 2021); Docket No. P.21-07-012.
EV Rates & Infrastructure
Background: This rulemaking is the successor to R.18-12-006 and will focus on issues related to 1) timely energization of electric vehicle (EV) charging, 2) transportation electrification grid planning to support charging infrastructure deployment, 3) deployment of behind-the-meter (BTM) charging infrastructure to support state goals, 4) vehicle-grid integration (VGI), and 5) ongoing transportation electrification policy development and collaboration.
Recent Developments: No recent developments.
Analysis: N/A.
Next Steps: N/A.
Additional Information: VGI Workshop Report (May 27, 2026); PG&E AL 7884-E Technical Assistance Program Handbook (Apr. 6, 2026); Resolution E-5434 (Feb. 27, 2026); D.25-12-005 (Dec. 5, 2025); Ruling (Oct. 14, 2025);
7 Ruling (Oct. 1, 2025); Joint Report on the CPUC’s Submetering and Telematics Workshop (Jun. 16, 2025); Scoping Memo and Ruling (Apr. 12, 2024); OIR (Dec. 20, 2023); Docket No. R.23-12-008.
Other Dockets
The following table identifies other tracked dockets that are closed or inactive.
Docket Name Status
R.19-09-009 Microgrids
D.24-11-004 adopting implementation rules for multi-property microgrid tariffs closed the proceeding. An Application for Rehearing was denied by D.25-06- 067, and CalSSA’s Petition for Modification remains pending.
R.23-03-007 Wildfire Fund NBC
2024-2026
D.25-12-006 set the 2026 Wildfire NBC at $5.91/MWh - a slight decrease from the 2025 WF NBC charge of $5.95/MWh.