Item 6
1 VALLEY CLEAN ENERGY ALLIANCE
Staff Report – Item 6
To: Board of Directors
From: Keyes & Fox, Regulatory Consultant
Subject: Regulatory Monitoring Report – Keyes & Fox
Date: April 9, 2026
______________________________________________________________________________ Please find attached Keyes & Fox’s March 2026 Regulatory Memorandum dated April 1, 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 April 1, 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: April 1, 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.
NEWPG&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 March 27, PG&E filed its Application for cost recovery of 2027 Diablo Canyon’s extended operations and its plan for VPF expenditures in 2027. The proposed revenue requirement allocated to PG&E’s territory is $340 million, which is expected to increase bundled residential customer’s bills by an average of $1.08 per month.
Analysis: N/A.
Next Steps: Protests or responses to the Application are due 30 days after it is noticed in the Daily Calendar.
Additional Information: Application (Mar. 27, 2026); Docket No. A.26-03-031.
NEWPG&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: On February 27, PG&E filed its 2025 ERRA Compliance Application requesting the Commission find it complied with its Bundled Procurement Plan, and that management of its utility-owned generation portfolio and recorded expenditures are reasonable. PG&E requested that the Commission exclude review of Diablo Canyon Power Plant’s extended operations from the scope and that four generating projects with outages extending past the 2025 review period also be excluded from review in this proceeding.
Analysis: N/A.
Next Steps: Protests or responses to the Application are due April 2.
Additional Information: 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 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 March 25, the CPUC issued D.26-03-013 temporarily pausing distribution of 2026 Climate Credits pending further consideration of potential changes to the 2026 Climate Credit distribution. On March 26, the CPUC issued the second Phase 1A Proposed Decision that orders immediate changes to the Climate Credit to increase its impact on affordability.
Analysis: The April 2026 Climate Credit distribution is temporarily paused, but under the Proposed Decision the full 2026 Climate Credit will be distributed in August and September and be accompanied by customer outreach and education efforts. More permanent potential changes to the Climate Credit will be considered in the upcoming Phase 1B, and they 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.
Next Steps: The Proposed Decision may be heard as soon as the April 30 Commission meeting. Comments on the Proposed Decision are due April 15 and reply comments are due April 20.
2 Additional Information: Proposed Decision (Mar. 26, 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.
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 March 27, the Assigned Commissioner issued a Ruling identifying requirements for and schedule of review for the 2026 RPS Procurement Plans. The Ruling includes some revised requirements related to reporting on IRP planning to better align the RPS Plan with the IRP filing requirements. VCE’s 2026 RPS Plan is due June 12.
Analysis: Several new RPS Plan requirements in this cycle address how the RPs Plan aligns with planned procurement identified in each LSE’s IRP filing and include reporting on progress towards existing and new Mid-Term Reliability procurement requirements.
Next Steps: Draft RPS Plans are due June 12, comments on Draft RPS Plans are due July 13, reply comments and motions to update RPS Plans are due July 27.
Additional Information: Ruling (Mar. 27, 2026); 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.
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: A February 24 Ruling updated the schedule and provided the Energy Division’s Transactability Report. The report examines transactability after the first year of binding SOD compliance based on Year-Ahead (YA) and Month-Ahead (MA) RA filings, transaction and procurement data, and observed market outcomes for the 2025 compliance year. Proposals on transactability issues were filed on March 3. CalCCA’s proposal highlighted that the report did not address the key function of transactability – reducing the over-procurement of RA by LSEs to support affordability. In its March 16 Comments on transactability issues, CalCCA emphasized that the intent underlying transactability is to increase affordability and resource efficiency.
Comments on Track 1 proposals other than transactability were filed March 6 and reply comments were filed March 20. Many parties, including CalCCA, generally supported the adoption of a methodology to account for energy-only resources’ contribution to charging sufficiency for storage resources, although several options were presented.
Several parties, including CalCCA and the Alliance for Retail Energy Markets, made recommendations to limit the inclusion of large loads like data centers in determining RA obligations until certain development thresholds are met.
A March 30 Ruling updated the schedule for the 2028 Loss of Load Expectation (LOLE) Study that will be used to determine the 2028 Planning Reserve Margin (PRM).
Analysis: The Transactability Report found that hourly resource transactions are feasible and could have potentially reduced RA compliance costs by between $2.9 and $7.6 million, but the potential gains do not outweigh the added complexity and risk of unintended consequences. Yet CalCCA’s comments, which evaluated over-procurement of RA, found nearly $37 million in available savings from hourly transactability during the month of September 2025. Proposals to count energy-only resources for charging sufficiency of storage resources will support more efficient use of existing resources like stand-alone solar and reduce RA compliance costs.
Next Steps: A Track 1 proposed decision is expected in May 2026. Draft LOLE studies and PRM proposals are due August 14 and final proposals are due in October.
Additional Information: Ruling (Mar. 20, 2026); CalCCA Transactability issues Comments (Mar. 16, 2026); CalCCA Track 1 Comments (Mar. 6, 2026); CalCCA Transactability proposal Comments (Mar. 3, 2026); Ruling and Transactability Report (Feb. 24, 2026); Scoping Memo (Dec. 12, 2025); OIR (Oct. 15, 2025); Docket No. R.25-10-003.
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’
3 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 March 5, the CPUC issued D.26-02-057 requiring 2029-2032 electric resource procurement and transmitting portfolios for the 2026-2027 Transmission Planning Process. Under the Decision, VCE is responsible for procuring an additional 7 MW by 2030, 7 MW by 2031, and 7 MW of non-fossil fuel resources that are eligible under the resource adequacy program by 2032 for a total of 21 MW. Additionally, by 2032, at least 5 MW of VCE’s total 21 MW obligation must be from long duration energy storage and/or clean firm resources. On March 9, the CPUC issued a Ruling extending the IRP filing deadline for LSEs from June 1 to August 10, 2026.
Analysis: In response to Comments by CalCCA and other parties, the Proposed Decision that led to D.26-02-057 was revised to extend the good-faith effort standard for assessing compliance, clarify that baseline swaps continue to be allowed, to allow energy-only co-located with fully deliverable storage resources as eligible resources, and to remove the 50% cap on storage resources. These revisions increase compliance options, add flexibility, and allow fully deliverable new storage resources that are co-located (i.e., share a single point of interconnection) with existing energy-only solar to count towards the procurement requirement.
Next Steps: VCE’s next IRP filing is due August 10, 2026. Comments on IRP filings are due September 21. LSE procurement compliance filings remain due June 1, 2026. IOUs’ Bundled Procurement Plan (BPP) 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: Ruling (Mar. 9, 2026); D.26-02-057 and Attachment (Mar. 5, 2026); IRP Ruling (Jan. 16, 2026); Scoping Ruling (Oct. 28, 2025); Ruling (Sep. 30, 2025); OIR (Jul. 2, 2025); Docket No. R.25-06-019.
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 implementation of dynamic rates and real-time pricing (RTP), similar to VCE’s AgFIT Pilot, but across all customer classes.
Recent Developments: On February 12, the CPUC issued a Scoping Memo and Ruling which included within the scope 1) bridge-year funding for existing programs, 2) extension of the Flex Alert marketing campaign, 3) guiding principles for DR policies, 4) data systems, communication protocols and data transfer processes to support DR and dynamic rates, and 5) broader DR improvement policies. On March 10, the CPUC issued a Ruling requesting comments on the Staff Proposal on IOUs Bridge Year Funding for 2028-2029. On March 26, the CPUC issued D.26-03-016 authorizing the continuation of the Flex Alert paid media campaign unchanged from prior years through December 31 with a budget of $15 million for this program year that will be shared by the large electric IOUs in proportion to their peak load.
Analysis: Scoping issue 4 pertaining to data systems will be relevant to CCAs’ receipt of data from IOUs to enable DR and dynamic rates. The continuation of the Flex Alert program will support ongoing efforts to encourage voluntary reductions in power use during times of grid stress.
Next Steps: Comments on the Staff Proposal are due April 15 and reply comments are due May 6. A Staff Proposal on Data Systems and Processes is expected during the first quarter of 2026.
Additional Information: 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); Ruling and Staff Proposal (Dec. 30, 2025); OIR and Guiding Principles (Sep. 29, 2025); Docket No. R.25-09-004.
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 an additional Track 3 will be initiated later in 2026 to review broader issues.
Recent Developments: A February 20 Ruling invited comments identifying and prioritizing issues to be included in Track 3 and specifically addressing data confidentiality or data access issues, and comments were filed on March 27. On March 27, a Ruling issued the Staff Report on valuation of pre-2019 banked RECs in which Staff agreed that pre-2019 banked RECs have value for departed load (i.e., CCA) customers and proposed several options to determine that value.
Analysis: A valuation for pre-2019 banked RECs will reduce PCIA charges and customer bills for CCAs with customers who departed IOU generation service after 2019.
Next Steps: The evidentiary hearing (if needed) begins April 28, any settlement is due May 15, and a proposed decision is expected by July 31. Comments on Track 3 issues are due March 27.
4 Additional Information: 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.
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: A February 3 Ruling required PG&E to submit supplemental information on several topics, including overhead maintenance and poles, vegetation management, clean energy strategy, and data centers. A February 26 Ruling granted an extension for party responses to the supplemental information provided by PG&E (extended to March 13) and for PG&E’s reply (extended to April 7). On March 3, the Assigned Commissioner issued a Second Amended Scoping Memo and Ruling adding issues related to Assembly Bill 2666 (Stats. 2024, Ch. 413) to the scope of this proceeding. Specifically, the new scope includes the following questions:
1. Should the Commission establish guidelines for PG&E to calculate and report its actual rates of return to the Commission in this GRC decision? If so, what should those guidelines include?
2. Should the Commission adopt processes to adequately track PG&E’s actual rate of return relative to its forecasted rate of return and require PG&E to identify the cost categories where projected costs differed from actual costs in this GRC decision? If so, what should those processes include?
3. Should the Commission require PG&E to provide the application’s impact on PG&E’s annual revenue requirement for each year that the capital expenditures described in the application are expected to remain in the application’s rate base if the application is approved or conditionally approved? If so, should the Commission require PG&E to provide supporting workpapers and calculations for the net present value and other estimates, and what capital expenditures or projects should be identified?
4. Parties including CalCCA submitted comments on these newly scoped questions on March 17 recommending implementation of AB2666 requirements for reporting tracking and of IOUs’ actual versus forecasted rates of return be addressed in a comprehensive rulemaking proceeding.
Analysis: N/A.
Next Steps: Track 1 evidentiary hearings begin April 27, opening briefs are due June 19, reply briefs are due July 10. A proposed decision is expected in March 2027.
Additional Information: 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.
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 January 20, the Commission issued Draft Comment Resolution E-5436 that directs the large IOUs to revise their online interconnection application websites to resolve ongoing data quality issues and expand the comprehensiveness of available data. On March 3, the Assigned Commissioner issued a Scoping Memo and Ruling defining the scope of Phase 1 to consider interconnection timelines and evaluation screens, and the interconnection process and fees for resources not interconnecting under the net billing or net metering tariffs.
Analysis: The initial phase of this proceeding will address a limited set of issues related to the interconnection of large-scale projects that provide electricity to the grid rather than primarily for behind-the-meter uses. Phase 1 issues cover issues defined in two of the eight categories of interconnection-related issues.
Next Steps: Party comments in response to the Scoping Memo are due April 30 and reply comments are due May 29.
The Draft Resolution was held over from the February 26 Commission meeting to the March 19 meeting and again to the April 30 Commission meeting.
Additional Information: Scoping Memo and Ruling (Mar. 3, 2026); Draft Comment Resolution E-5436 (Jan. 20, 2026); OIR (Jul. 25, 2025); Docket No. R.25-08-004.
5 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: On February 18, a Ruling revised the schedule and set the timeframes for the City’s amended and restated opening testimony as well as responsive testimony. A March 10 Ruling provided schedule dates.
Analysis: After many years of discovery and procedural motions, this proceeding is moving forward with the testimony phase on the appraised value of PG&E’s lands, property, and rights in San Francisco.
Next Steps: CCSF’s amended and restated testimony is due April 20, PG&E’s opening testimony is due October 20 and intervenor testimony is due December 22.
Additional Information: 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: On February 27, the CPUC issued Resolution E-5434, approving, with modifications, PG&E’s request in Advice Letter 7378-E for a Phase 1 extension until June 30 to complete demonstration and data collection activities. The Resolution also grants PG&E’s request to modify the Phase II Vehicle-to-Everything Microgrid Pilot scope, converting it into a Hybrid Support Model that closes enrollment, returns unused incentive funds to ratepayers, and adopts the use of non-pilot funds for technical support.
Analysis: N/A.
Next Steps: The Technical Assistance Program Handbook, which provides program implementation guidance in accordance with D.22-11-040, is due April 6.
Additional Information: Resolution E-5434 (Feb. 27, 2026); 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.
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: Intervenor testimony was submitted March 9.
Analysis: CalCCA’s testimony focused on PG&E’s proposed increases to its CCA service fees and its proposal to request future escalations of these fees via the informal Advice Letter process. CalCCA argued the Commission should reject these proposals. CalCCA also argued that the Commission should require PG&E to update its outdated and excessive Provider of Last Resort (POLR) fee.
Next Steps: 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 the extension of (and potential changes to) dynamic rate pilots is due June 8, and intervenor testimony is due October 30, 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 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: PG&E filed supplemental testimony on March 11.
Analysis: N/A.
6 Next Steps: N/A.
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: A February 3 Ruling postponed evidentiary hearings, and a February 5 Ruling requested party feedback on a draft schedule. A March 10 Ruling revised the procedural schedule.
Analysis: N/A.
Next Steps: Rebuttal to supplemental testimony is due April 28, a joint case management statement is due May 7, evidentiary hearings begin on June 8, opening briefs are due July 16, and reply briefs are due August 13.
Additional Information: 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.
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.
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.