Item 9
1 VALLEY CLEAN ENERGY ALLIANCE
Staff Report – Item 9
To: Board of Directors
From: Keyes & Fox, Regulatory Consultant
Subject: Regulatory Monitoring Report – Keyes & Fox
Date: February 12, 2026
______________________________________________________________________________ Please find attached Keyes & Fox’s January 2026 Regulatory Memorandum dated February 4, 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 February 4, 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: February 4, 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 month.
NEWDemand Response Enhancements
Background: This proceeding will enhance demand response (DR) resources statewide by updating guiding principles, policies, and data system and process requirements. Demand response development is closely connected to the implementation of dynamic rates and real-time pricing (RTP), similar to VCE’s AgFIT Pilot but across all customer classes.
Recent Developments: A December 30 Ruling requested comments on the Staff Proposal to extend Flex Alert funding to 2026. Comments in response to the Ruling were filed on January 20 and reply comments were filed on January 30.
Analysis: Flex Alerts are issued during times of peak demand and grid stress as a request for voluntary reductions in electricity use. The program’s contract ended in 2025, and the current proposal is to extend the program through 2026 at the same $22 million budget level.
Next Steps: A scoping memo is expected. A Staff Proposal on Data Systems and Processes is expected during the first quarter of 2026.
Additional Information: Ruling and Staff Proposal (Dec. 30, 2025); OIR and Guiding Principles (Sep. 29, 2025); Docket No. R.25-09-004.
IRP Rulemaking (2025)
Background: This new 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: On January 14, the CPUC issued a Proposed Decision requiring 2029-2032 electric resource procurement and transmitting portfolios for the 2026-2027 Transmission Planning Process. Under the Proposed Decision, VCE is responsible for procuring a total of 22 MW which are additional to prior Mid-Term Reliability (MTR) procurement requirements, with 7 MW by 2030 and 15 MW by 2032. On January 16, the ALJ issued a Ruling setting the IRP filing requirements for LSEs. The deadline for filing individual LSE IRPs is currently June 1, 2026, but CalCCA plans to submit a request for the filing deadline to be extended to six months from when the final modeling data are made available. The IRP filing is based on achieving a statewide GHG emissions limit of 25 million metric tons (MMT) in 2035 and 8 MMT by 2045.
Analysis: The additional procurement requirements are intended to encourage LSEs to procure resources that are eligible for the expiring federal tax credit and to bolster reliability, but resource requirements are unchanged from prior MTR procurements and there are no carve-outs for resources with specific characteristics such as long-lead times or long-duration storage. LSEs must file an IRP with at least one portfolio that conforms to standard assumptions, but additional portfolios are allowed for LSEs that choose to include their own assumptions, such as for electrification- and data center-driven load growth. This approach to the IRP requirements will allow the Commission to compare and consolidate LSEs’ IRP data based on standardized assumptions, while also preserving alternative scenarios to better plan for future uncertainty.
Next Steps: The Proposed Decision may be heard as soon as the February 26 Commission meeting. Comments on the Proposed Decision are due February 6 and reply comments are due February 11. VCE’s next IRP filing is due June 1,
2 2026, but the deadline may be extended. Comments on IRP filings are due July 15. IOUs’ Bundled Procurement Plan updates are now due June 1, comments on proposed updates are expected to be due in Q3, and a proposed decision adopting updated BPPs is now expected in Q4. An ALJ ruling on the “good faith effort” standard for LSE compliance with procurement requirements was expected in Q4 of 2025 but is delayed.
Additional Information: IRP Ruling (Jan. 16, 2026); Proposed Decision (Jan. 14, 2026); Ruling (Jan. 2, 2026); PG&E AL 7798-E (Dec. 30, 2025); PG&E AL 7790-E (Dec. 19, 2025); Scoping Ruling (Oct. 28, 2025); Ruling (Sep. 30, 2025); OIR (Jul. 2, 2025); Docket No. R.25-06-019.
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 January 7, the CPUC issued a Ruling setting the schedule for the Dynamic Rate Options track. The Ruling generally granted PG&E’s November 6, 2025, Motion to first address extension of Hourly Flex Pricing (HFP) pilots before they expire in 2027, and then to address post-pilot dynamic rates in the future. The Ruling declined to adopt PG&E’s proposed schedule for full consideration of post-pilot dynamic rates. On January 23, PG&E submitted its Errata testimony. On January 27, an ALJ Ruling revised the procedural schedule that was suspended by an early January Ruling.
Analysis: The Dynamic Rate Options track is relevant to VCE’s AgFIT pilot and potential future extension of this pilot.
Under the January 7 Ruling, PG&E will be submitting testimony supporting “stop-gap” RTP pilot extension, and there will be future opportunities for other parties to file responsive testimony and participate in hearings. PG&E’s November 6, 2025 Motion stated that its testimony on the “stop-gap” extension of the pilots may include “significant” proposed changes to HFP Pilot rate design.
Next Steps: Intervenor testimony is due March 9, rebuttal testimony is due July 10, a meet and confer will be held July 20, and a Ruling on the need for evidentiary hearings is expected August 7. PG&E’s testimony on dynamic rate pilots is due June 8, 2026, and intervenor testimony is due October 30, 2026, or 60 days after the release of the Mid-Term and M&E RTP pilot results. Evidentiary hearings, if necessary, will follow.
Additional Information: Ruling (Jan. 27, 2026); Ruling (Jan. 7, 2026); Ruling (Jan. 2, 2026); Motion for bifurcated track (Nov. 6, 2025); PG&E Testimony and Change Tables (Oct. 29, 2025); Ruling (Oct. 9, 2025); Ruling (Aug.18, 2025); Request for scoping amendment (Jun. 12, 2025); PG&E AL 7588-E (May 2, 2025); Scoping Memo (Mar. 21, 2025); Application (Sep. 30, 2024); Docket No. A.24-09-014.
PG&E 2026 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 January 15, CalCCA filed an Application for Rehearing (AFR) of D.25-12-027 and PG&E filed a Response on January 27. The AFR challenges, as legal error, the Commission’s use of the new methodology established in the PCIA-ERRA Reform proceeding in June 2025 to adjust the valuation of the market-price benchmark for Resource Adequacy in the Power Charge Indifference Adjustment in this proceeding. The AFR also addresses the valuation of PG&E’s pre-2019 banked RECs in this proceeding and requests an oral argument. Additionally, PG&E recently filed two advice letters required by D.25-12-027: 7820-E addressing PG&E’s implementation of an “interim” Slice-of-Day methodology for valuing the capacity in its PCIA portfolio, and 7829-E addressing PG&E’s tracking of the pre-2019 banked RECs it will use for bundled customers Renewables Portfolio Standard compliance in 2026.
Analysis: The AFR challenges several key components of the ERRA Forecast rates which resulted in rate increases of 24% for residential customers and 65% for residential CARE customers.
Next Steps: If the AFR’s request for oral argument is granted, parties will be notified at least 10 days in advance.
Additional Information: PG&E Response (Jan. 27, 2026); CalCCA Application for Rehearing (Jan. 15, 2026); PG&E AL 7797-E (Dec. 30, 2025); D.25-12-027 (Dec. 23, 2025); Scoping Ruling (Oct. 29, 2025); PG&E Fall Update (Oct. 15, 2025); Ruling (Sep. 24, 2025); Scoping Memo and Ruling (Jul. 31, 2025); PG&E 2026 ERRA Forecast Application (May 15, 2025); Docket No. A.25-05-011.
PCIA/ERRA Reform
Background: This Rulemaking considers updates and reforms to the Energy Resource and Recovery Account (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,
3 Track 2’s scope was revised to consider issues related to the valuation of pre-2019 RECs arising from 2026 ERRA forecast proceedings, and an additional Track 3 will be initiated later in 2026 to review broader issues.
Recent Developments: The Track 2 prehearing conference was held on January 23. An Amended Scoping Memo was issued on February 3 formalizing the Track 2 issued related to the IOUs’ use of pre-2019 banked RECs and their valuation in the PCIA.
Analysis: Track 2 of this proceeding was added specifically to address issues related to the IOUs’ use of pre-2019 banked RECs and their valuation with respect to ERRA proceedings and the PCIA. PG&E’s use of pre-2019 banked RECs was approved on an interim basis in its 2026 ERRA Forecast proceeding without a corresponding PCIA credit provided to departed now-CCA customers, which results in increased CCA customer costs and decreased bundled customer costs.
Next Steps: Testimony is due March 2, reply testimony is due March 23, a potential staff proposal may be issued by March 27, the evidentiary hearing (if needed) begins April 28, any settlement is due May 15, and a proposed decision is expected by July 31.
Additional Information: 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.
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 will consider 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 will address the planning reserve margin and coordination with the integrated resource plan proceeding.
Recent Developments: Track 1 proposals were filed by parties on January 23. Proposals from PG&E, CalCCA, and other parties supported allowing energy-only resources to count towards the charging sufficiency of energy storage resources. CalCCA also proposed coordination with the California Energy Commission to separate data center load from the RA forecast and to only use actual load rather than forecast load to set RA obligations. One group of Joint Parties proposed a methodology for including long-duration energy storage resources (i.e., resources that discharge over 8 or more hours) in the SOD framework, and CalAdvocates’ proposed a method for addressing multi-day storage resources that have a charge and discharge cycle longer than 24 hours.
Analysis: Track 1 proposals on counting energy-only resources towards energy storage charging sufficiency will increase the flexibility of charging storage resources, enable more storage resources to be fully valued for RA, and make more efficient use of energy-only resources. Proposals addressing long-duration and multi-day storage resources will fill additional regulatory gaps in the SOD framework, improve alignment between the RA requirements and the reliability procurement requirements, and enable LSEs to plan for the future RA compliance needs when these resources eventually come online.
Next Steps: A workshop on party proposals will be held on February 10-11. An Energy Division report on RA transactability issues is due February 6, transactability proposals are due February 20, and a workshop on transactability will be held February 24. Opening comments on party proposals are due March 6, and reply comments are due March 20. A Track 1 proposed decision is expected in May 2026.
Additional Information: Demand Response Load Impact Protocols (LIP) Filing Guide (Dec. 23, 2026); Scoping Memo (Dec. 12, 2025); OIR (Oct. 15, 2025); Docket No. R.25-10-003.
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: On January 16, an ALJ Ruling extended the deadline for intervenor and rebuttal testimony on post-2027 electrical undergrounding to February 27 and April 14, respectively. The extension accounts for filing deadlines on related topics established in Resolution SPD-37. On January 26, the Assigned Commissioner issued an Amended Scoping Memo and Ruling expanding the scope to include SB 254’s provisions on wildfire mitigation accounting and requesting party comments. On February 3, the ALJ issued a ruling requiring PG&E to file supplemental information by February 13 addressing the questions in the ruling related to various issues including overhead maintenance and poles, vegetation management, new business, transformer purchases, clean energy strategy, data centers, and historical and forecast demand data.
Analysis: N/A; CCA issues to be addressed in intervenor testimony due February 13.
4 Next Steps: Comments on the amended scope are due February 6. Intervenor testimony on most issues in this proceeding is due February 13; intervenor testimony on post-2027 electrical undergrounding is due on February 27.
PG&E will also file supplemental information by February 13 addressing the questions in the February 3 ruling.
Additional Information: 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.
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: On January 26, VCE’s Amended Confidentiality Motion was filed, as required by D.25-12-025.
Analysis: N/A.
Next Steps: A ruling establishing the requirements for the 2026 RPS Procurement Plan filing is expected in May.
Additional Information: VCE Amended Confidentiality Motion (Jan. 26, 2026); D.25-12-025 (Dec. 26, 2025); VCE RPS Compliance Report (Aug. 1, 2025); VCE 2025 Draft RPS Plan (Jun. 30, 2025); Ruling on 2025 RPS Plans (Apr. 17, 2025); Notice of RPS Plan Approval (Apr. 3, 2025); Scoping Memo and Ruling (May 9, 2024); OIR (Feb. 1, 2024); Docket No. R.24-01-017.
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: A Ruling revising the procedural schedule was issued on February 2, requiring PG&E to file supplemental testimony on March 11, 2026, and parties to file supplemental reply testimony on April 10.
Analysis: Supplemental testimony will address customer-specific vintaging associated with customers who have opted out of CCA service, then opted back in to CCA service, then moved within the incumbent CCA service area.
Next Steps: PG&E will file supplemental testimony on March 11.
Additional Information: 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 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: The ALJ issued an email Ruling on February 3 cancelling the evidentiary hearings scheduled for February 9 - 11, and notifying parties that a subsequent ruling will be issued for party input on a revised proceeding schedule and supplemental testimony.
Analysis: PG&E noted during the February 3 status conference that it now anticipates delays in BMI project milestones (specifically, it is now targeting a deployment date for the end state billing solution in Q2 2030 rather than Q4 2029, as originally anticipated). In light of this change, parties advocated for supplemental testimony and a delay in hearings, which the ALJ granted.
Next Steps: A ruling is expected soon requesting party input on a revised proceeding schedule and supplemental testimony.
Additional Information: 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.
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.
Recent Developments: The prehearing conference was held on January 16. On January 20, the Commission issued Draft Comment Resolution E-5436: Increased Funding to Maintain and Expand the California Distributed Generation Statistics Website and Orders to Improve Data Collection Quality in the Investor-Owned Utilities’ Online Interconnection Application Interfaces. The Draft Resolution increases funding for the Distributed Generation Statistics Website to $2.6
5 million under a three-year contact and directs the large IOUs to revise their online interconnection application websites to resolve ongoing data quality issues and increase the comprehensiveness of available data.
Analysis: The Distributed Generation Statistics Website provides policymakers, customers, and installers with current information from interconnections applications submitted to the large IOUs. The increased funding and other updates under this Draft Resolution will improve the website’s usefulness for planning with near-real time data on and increase the speed of processing interconnection applications.
Next Steps: The Draft Resolution may be heard as early as the February 24 Commission meeting. A scoping memo and ruling is expected.
Additional Information: Draft Comment Resolution E-5436 (Jan. 20, 2026); OIR (Jul. 25, 2025); Docket No. R.25-08- 004.
City and County of San Francisco Municipalization
Background: The City and County of San Francisco (SF or 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 system within SF transmission assets needed for operational control, a substation and related assets) pursuant to Public Utilities Code §1401-1421.
Recent Developments: A January 12 ALJ Ruling partly granted CCSF’s Motion to compel PG&E responses, requiring PG&E to provide to CCSF current (2021) revenue and rate base data that PG&E has already provided to Commission Staff, but denying the remainder of the request. On February 2 parties filed comments on updating the procedural schedule.
Analysis: N/A.
Next Steps: Reply comments on updating the procedural schedule are due February 12, and the updated schedule for testimony will be specified in a future ruling.
Additional Information: 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.
Utility Safety Culture Assessments
Background: This rulemaking will define safety culture concepts and determine how the safety culture of PG&E and other utilities in California will be assessed and evaluated. The CPUC’s Office of Energy Infrastructure Safety will conduct annual wildfire safety-specific assessments of investor-owned utilities as required by AB 1054, and an independent third-party evaluator will conduct safety culture assessments every five years per SB 901. Phase 1 of this proceeding focused on developing safety culture assessments for the large electric and natural gas IOUs, and Phase 2 will develop safety culture assessments for small multi-jurisdiction utilities (SMJUs) and the gas storage operators.
Recent Developments: Party proposals on utility safety culture assessment for SMJUs and gas storage operators were submitted on January 30, and an ALJ Ruling scheduled a workshop on February 6 for presentations on party proposals.
Analysis: N/A.
Next Steps: A workshop on SMJU and gas storage safety culture assessment proposals will be held February 6. PG&E’s first third-party evaluation is scheduled for August 1, 2028. Annual reports are due August 1 of each year between third-party evaluations.
Additional Information: Ruling (Jan. 27, 2026); Scoping Memo and Ruling (Aug. 26, 2025); D.25-01-031 (Jan. 23, 2025); OIR (Oct. 7, 2021); Docket No. R.21-10-001.
Climate Credit OIR
Background: This rulemaking will explore potential approaches to maximize the effectiveness at supporting customer affordability of 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 will address the timing of the distribution of climate credits in 2026 and Phase 1B will address broader changes in the residential Climate Credit.
Recent Developments: On February 3, the Assigned Commissioner issued a Scoping Memo and Ruling defining the issues for Phase 1A and Phase 1B and requesting comments on questions in the Ruling. In Phase 1A, the CPUC expects to issue a proposed decision in mid-February directing the IOUs to pause distribution of 2026 climate credits until a second decision later in Phase 1A determines whether moving the 2026 Climate Credits to a high-billed month or months would benefit customer affordability.
Analysis: The changes to the state’s Climate Credit under consideration in this proceeding may impact customer electric bills in multiple ways. The immediately forthcoming proposed decision will temporarily halt Climate Credit distributions this year pending further consideration of potential changes over the next couple of months. Potential changes to the Climate Credit under consideration in Phase 1B are focused on affordability and include eligibility to receive the credit, the timing of its distribution, number of annual distributions, and the methodology used to calculate the credit.
6 Next Steps: A proposed decision pausing distribution of 2026 Climate Credits is expected no later than February 13.
Comments on questions presented in the ruling are due March 2 and reply comments are due March 9. A proposed decision on moving the 2026 Climate Credits to a high-billed month is expected by March 27.
Additional Information: Scoping Memo and Ruling (Feb. 3, 2026); Ruling (Oct. 31, 2025); OIR (Aug. 20, 2025); Docket No. R.25-07-013.
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: No recent developments.
Analysis: N/A.
Next Steps: Heat-based disconnection threshold proposals must be implemented by May 1.
Additional Information: 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.
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: The Technical Assistance Program Handbook is due April 6.
Additional Information: D.25-12-005 (Dec. 5, 2025); Ruling (Oct. 14, 2025); Ruling (Oct. 1, 2025); PG&E Mid-Term Report (Sep. 15, 2025); Joint Report on the CPUC’s Submetering and Telematics Workshop (Jun. 16, 2025); Joint Report on the Vehicle-Grid Integration Workshop (Jun. 16, 2025); Scoping Memo and Ruling (Apr. 12, 2024); OIR (Dec. 20, 2023); Docket No. R.23-12-008.
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: No recent developments.
Analysis: N/A.
Next Steps: N/A.
Additional Information: 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.
Other Dockets
The following table identifies other tracked dockets that are closed or inactive.
Docket Name Status
A.25-03-015 Diablo Canyon 2026
This proceeding was closed by D.25-12-007, but reopened in response to two Applications for Rehearing (SLOMFP, CARE).
R.20-05-003 IRP
This proceeding was superseded by the new IRP docket, but it remains open to consider the additional procurement requested in ACP-CA’s July 2025 Motion, which is expected to be resolved in Q1 2026.
R.19-09-009 Microgrids
D.24-11-004 adopting implementation rules for multi-property microgrid tariffs and closing the proceeding was issued November 18. Proceeding reopened for pending Application for Rehearing and Petition for Modification.
7 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.
A.22-05-002
Demand Response
Programs (2023-
2027)
D.24-04-006, issued April 24, 2024, ended the Demand Response Auction Mechanism (DRAM) pilot programs of PG&E, SCE, and SDG&E and closed the proceeding. The proceeding was reopened to consider a pending Application for Rehearing.
A.21-06-021 PG&E 2023 Phase
1 GRC
A Proposed Decision to close this proceeding is scheduled to be heard at the February 26 Commission meeting.
A.22-02-015 PG&E 2021 ERRA
Compliance
This proceeding was closed in June 2025 with issuance of D.25-06-045, but was reopened in response to an August 2025 Application for Rehearing.
R.21-03-011 POLR The proceeding was closed in January 2026 with issuance of D.26-01-022.