Item 8
1 VALLEY CLEAN ENERGY ALLIANCE
Staff Report – Item 8
To: Board of Directors
From: Keyes & Fox, Regulatory Consultant
Subject: Regulatory Monitoring Report – Keyes & Fox
Date: February 23, 2025
______________________________________________________________________________ Please find attached Keyes & Fox’s January 2025 Regulatory Memorandum dated February 5, 2025 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 5, 2025
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, Principal Analyst, EQ Research, LLC
Subject: Monthly Regulatory Update
Date: February 5, 2025
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.
PG&E 2025 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 December 20, the CPUC issued D.24-12-038 on PG&E’s 2025 ERRA Forecast. PG&E’s 12- month net revenue requirement for 2025 is approximately $2.25 billion, 17% less than the adopted 12-month revenue requirement for 2024. This revenue requirement results in a decrease of bundled residential customers‘ rates of about 2% or 0.7 cents per kilowatt-hour (cents/kWh) to a total rate of 34.6 cents/kWh, and a decrease in CCA residential customers’ of about 4.4% or 0.9 cents/kWh to a total rate of 19.7 cents/kWh. On December 30, PG&E submitted AL 7469-E on its rate changes effective January 1, 2025. With the GHG Revenue Return included, the rate for residential CCA customers declines 2.1% to $0.26590/kWh and the rate for CCA CARE customers declines 19.2% to $0.09033/kWh. Excluding the GHG Revenue Return, the rate for residential CCA customers declines 1.4% to $0.29117/kWh and the rate for CCA CARE customers declines 14.8% to $0.11587/kWh.
Analysis: The Decision agrees with CalCCA and would reject PG&E’s effort to alter how the resource adequacy market price benchmark is accounted for in rates. This is a significant result that protects departed customers from paying more than their fair share in PCIA rates. At the same time, the Decision also sets the stage for a future rulemaking where the Commission would consider issues related to the valuation of PG&E’s and the other IOUs’ capacity portfolios for the purposes of setting rates. The Decision also adopted PG&E’s proposed modification to its common cost allocation methodology, but agreed with CalCCA that the modification should only apply on a going forward basis (allocations of costs starting in 2025).
Next Steps: The proceeding is closed.
Additional Information: PG&E AL 7469-E (Dec. 30, 2024); D.24-12-038 (Dec. 20, 2024); PG&E Fall Update (Oct. 23, 2024); Joint Case Management Statement (Sep. 27, 2024); Scoping Memo and Ruling (Aug. 1, 2024); ALJ Ruling (Jun. 13, 2024); PG&E’s Amended Application (May 24, 2024); PG&E 2025 ERRA Forecast Application (May 15, 2024); Docket No. A.24-05-009.
Diablo Canyon Cost Recovery
Background: This proceeding will establish rates effective January 1, 2025 to recover the forecast costs associated with extended operations of the Diablo Canyon Power Plant (DCPP) during the September 2023-December 2025 time period. Customers across the state – including CCA customers - will pay for the costs of extended operations at DCPP, and will be allocated the resource adequacy (RA) and greenhouse gas (GHG)-free benefits associated with those operations. PG&E proposes, in its application, certain changes to the allocation of RA and GHG-free benefits to load serving entities (LSEs). It also proposes specific uses for the volumetric performance fee revenue it will collect from customers in 2025.
Recent Developments: On December 20, the CPUC issued D.24-12-033 on PG&E’s revenue requirement to support extended operations at the Diablo Canyon Power Plant (DCPP) and approving the first year of 2025 volumetric performance fees spending, subject to PG&E making a compliance filing providing more detail on its volumetric performance fee spending plan. The Decision rejects PG&E’s attempt to modify Resource Adequacy and Greenhouse-Gas Free attribute allocations from Diablo Canyon.
2 Analysis: The Decision approves the joint IOUs’ proposal to establish the DCPP non-bypassable charge (NBC) that applies to all Commission jurisdictional customers based on approved net costs, of which 44.9% is allocated to customers in PG&E’s territory. The impact of these charges is estimated to increase system average bundled service rates by 1.4% and the system average rate for CCA and direct access customers by 2.4% in PG&E’s territory, effective starting January 1, 2025.
Next Steps: The Application is closed.
Additional Information: D.24-12-033 (Dec. 20, 2024); PG&E AL 7295-E-A (Aug. 30, 2024); ALJ Ruling (Aug. 27, 2024); ALJ Ruling (Aug. 15, 2024); Scoping Memo and Ruling (Jun. 18, 2024); PG&E AL 7295-E (Jun. 12, 2024); ALJ Ruling (May 15, 2024); Amended Application (Apr. 8, 2024); Application (Mar. 29, 2024); Docket No. A.24-03-018.
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 is focused on developing safety culture assessments for the large investor-owned electric and natural gas corporations, and Phase 2 of this proceeding will be focused on developing safety culture assessments for the small multi-jurisdiction utilities and the gas storage operators.
Recent Developments: On January 23, the CPUC issued D.25-01-031 adopting a Safety Culture Assessment Framework for PG&E, SCE, SDG&E, and SoCalGas. The framework includes two components: (1) a Comprehensive Assessment of each investor-owned utility’s safety culture, conducted once every four years by a third-party independent evaluator; and (2) an annual Self-Evaluation conducted by each utility in the three intervening years to monitor improvement; both of which are guided by the Utility Safety Culture Improvement Framework adopted in the Decision.
Analysis: The large IOUs’ safety culture will be evaluated every four years by an independent third party, and each year in between evaluations the IOUs are required to report on progress towards addressing the evaluation recommendations, best practices implemented, and advancements in strategic planning for safety culture improvements.
Next Steps: Phase 2 of the proceeding is expected to begin later this year. 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: D.25-01-031 (Jan. 23, 2025); ALJ Ruling (Jun. 10, 2024); ALJ Ruling (May 8, 2023); Scoping Ruling with procedural schedule (Apr. 28, 2022); Order Instituting Rulemaking (Oct. 7, 2021); Docket No. R.21-10-001.
Demand Flexibility
Background: This rulemaking was opened to update the CPUC’s rate design principles and guidance for advancing demand flexibility, and the proceeding may also modify, consolidate, or eliminate existing dynamic rate pilots. Phase 1- Track A established an income-graduated fixed charge (IGFC) for residential rates for all investor-owned electric utilities in accordance with Assembly Bill 205 (Stats. 2022, ch. 61). Phase 1-Track B first adopted rate design and demand flexibility principles and then expanded VCE’s AgFIT Pilot throughout PG&E distribution territory.
Recent Developments: Final Resolution E-5354 (PG&E AL 7351-E, 7351-E-A, 7351-E-B) on Implementation of Pacific Gas and Electric Company’s Income-Graduated Fixed Charges Pursuant to Ordering Paragraph 3(c) of Decision 24-05- 028 was approved at the January 30 meeting. On December 13, the Energy Division approved VCE’s Advice Letter 20- E indicating its intent to participate in PG&E Expanded Pilot 2, which applies the VCE AgFIT model to specified commercial, industrial, and residential customers.
Analysis: N/A.
Next Steps: A proposed decision on Track B Working Group 1 proposals regarding rate design for marginal generation capacity costs was expected by the end of 2024 but is delayed.
Additional Information: Final Resolution E-5354 (Feb. 4, 2025); VCE AL 20-E (Nov. 8, 2024) approved by Energy Division on Dec. 13, 2024); Disposition Letter on VCE AL 17-E (Sep. 3, 2024); PG&E AL 7351-E (Aug. 13, 2024) and AL 7351-E-A (Sep. 13, 2024); D.24-05-028 (May 15, 2024); D.24-01-032 (Jan. 26, 2024); Phase 1 Scoping Memo and Ruling (Nov. 2, 2022); OIR (Jul. 22, 2022); Docket No. R.22-07-005.
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 January 17, PG&E submitted the Joint Prehearing Conference Statement.
3 Analysis: The Joint Statement recommends a list of issues to be considered in this proceeding, such as the reasonableness of the forecast costs and cost recovery proposal; whether PG&E adequately considered alternative initiatives or approaches; whether the proposed upgrades will include any anti-competitive design elements or have any anti-competitive impacts; and whether the upgrades will support corrections to the current bill presentation that facilitate greater transparency and foster fair competition.
Next Steps: A procedural schedule is expected to be issued in Q1 2025.
Additional Information: Joint Prehearing Conference Statement (Jan. 17, 2025); Application (Oct. 23, 2024); Docket No.
A.24-10-014.
Clean Power SF Municipalization
Background: The City and County of San Francisco (SF or City) filed this Petition 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. Briefing was filed in August of 2022.
Recent Developments: On January 24, the ALJ issued a Ruling requesting comments on a proposed schedule for serving testimony and party responses to questions intended to facilitate the development of a complete valuation and identify needed information to be included in testimony.
Analysis: N/A.
Next Steps: Comments on the Ruling are due February 24 and reply comments are due March 11. The remaining schedule depends in part on comments from parties in response to the Ruling.
Additional Information: ALJ Ruling (Jan. 24, 2025); ALJ Ruling (Oct. 28, 2024); ALJ Ruling requesting comments (Mar. 27, 2024); Amended Scoping Memo and Ruling (Dec. 22, 2023); Petition (Jul. 27, 2021); Docket No. P.21-07-012.
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 December 24, D.24-12-035 adopted, with modifications, 2024 RPS Procurement Plans. VCE submitted its Final 2024 RPS Procurement Plan on January 22, as required by D.24-12-035.
Analysis: N/A
Next Steps: A ruling initiating the process for 2025 RPS Procurement Plans is expected in Q2 2025.
Additional Information: VCE Final 2024 RPS Procurement Plan (Jan. 22, 2025); D.24-12-035 (Dec. 24, 2024; Scoping Memo and Ruling (May 9, 2024); OIR (Feb. 1, 2024); Docket No. R.24-01-017.
RA Rulemaking (2025-2026)
Background: This proceeding considers resource adequacy (RA) requirements for LSEs and will address the 2025 and 2026 RA compliance years, local RA procurement obligations for the 2025-2028 compliance years, and further development of the 24-hour Slice-of-Day (SOD) framework. Track 1 was focused on priority issues including RA capacity requirements, SOD framework implementation, and RA compliance and penalties. Track 2 was focused on Central Procurement Entity (CPE) framework issues, including potential structural modifications. Track 3 is focused on remaining RA capacity issues, including what planning reserve margin (PRM) the Commission should require for LSE RA procurement obligations. The Commission issued D.24-06-004 on Track 1 on June 26, 2024.
Recent Developments: On December 12, the CPUC issued D.24-12-003 in which it declined to eliminate the CPE framework or to eliminate local RA procurement requirements. But the Decision did make some changes to the CPE framework, including eliminating the options for LSEs to self-show resources to the CPE without compensation and increasing the timeframe to one year in advance for CPE allocations. On December 23, the ALJ issued a Ruling providing the Energy Division’s Revised Slice of Day Tool Analysis. On January 21, the ALJ issued a Ruling providing Energy Division’s Track 3 proposals, including its revised PRM proposals. Party Track 3 proposals were filed on January
17. Analysis: D.24-12-003’s adopted modifications to the central procurement entity (CPE) framework, such as eliminating the non-compensated self-show option of the CPE framework and locking in CPE allocations to load-serving entities (LSEs) one year earlier should increase certainty in the market and support LSE procurement. Consideration of Energy Division’s and other parties’ Track 3 Proposals is ongoing. Energy Division’s PRM proposals—which will require that LSEs procure some percentage of RA above and beyond the amount needed to serve their expected load—are of particular importance given the challenges in the RA market.
Next Steps: Comments on all Track 3 Proposals are due March 3 and reply comments are due March 17.
4 Additional Information: ALJ Ruling (Jan. 21, 2025); ALJ Ruling & SOD Study (Dec. 23, 2024); D.24-12-003 on Track 2 (Dec. 12, 2024); Track 3 Scoping Memo and Ruling (Nov. 4, 2024); D.24-06-004 (Jun. 26, 2024); Scoping Memo and Ruling (Dec. 18, 2023); OIR (Oct. 16, 2023); Docket No. R.23-10-011.
IRP Rulemaking
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, and ongoing reliability obligations.
Recent Developments: On January 10, the CPUC issued a Proposed Decision recommending to the CAISO for its 2025- 2026 Transmission Planning Process (TPP) the analysis of two electricity portfolios: a reliability- and policy-driven base case portfolio and a sensitivity portfolio.
Analysis: The base case portfolio in the Proposed Decision is based on a GHG emission target of 25 million metric tons (MMT) by 2035, includes LSE resources submitted in the 2022 IRP, and mostly relies on the same modeling assumptions as the adopted preferred system plan portfolio. The portfolio achieves 99% clean energy serving retail load by 2035, with a portfolio of approximately 63 GW of new storage and clean energy to come online between now and 2035.
Next Steps: The Proposed Decision may be heard as early as the February 20 Commission meeting. Comments on the Proposed Decision were due January 30 and reply comments were due February 4. By March 1, 2025, the CPUC may request that the Division of Water Resources exercise the centralized procurement mechanism for long-lead-time resources.
Additional Information: Proposed Decision (Jan. 10, 2025); D.24-09-006 (Sep. 17, 2024); D.24-08-064 on central procurement of LLT resources (Aug. 29, 2024); Amended Scoping Memo and Ruling (Correction/Clarification) (Apr. 18, 2024); D.24-02-047 (Feb. 20, 2024); D.23-12-014 (Dec. 19, 2023); D.23-02-040 on Procurement (Feb. 28, 2023); Docket No. R.20-05-003.
Provider of Last Resort Rulemaking
Background: A Provider of Last Resort (POLR) is the utility or other entity that has the obligation to serve all customers (PG&E currently serves in this role for VCE’s service area). Phase 1 of this proceeding concluded in April 2024 and addressed POLR service requirements, cost recovery, and options to maintain GHG emission reductions in the event of an unplanned customer migration to the POLR. Phase 2 will build on Phase 1 to set the requirements and application process for non-IOU entities to serve as the POLR. Phase 3 will address specific issues not resolved in Phase 1 or 2.
Recent Developments: Comments on the Phase 2 Threshold Questions were filed January 10 and reply comments were filed January 24.
Analysis: Threshold questions in Phase 2 explore whether there is any interest from an IOU in transferring its POLR responsibilities to a non-IOU LSE, whether there are any non-IOU LSEs interested in becoming a POLR, if and to what extent the Commission has jurisdiction over a non-IOU LSE POLR, as well as the minimum requirements, application process, and other implementation matters related to a non-IOU LSE POLR.
Next Steps: A ruling on the need for legal briefs is expected in Q1 2025 and resolution of the Threshold Questions is expected in Q2 2025, after which the primary topic areas will be addressed. The first revised FSR posting under D.24- 04-009 is due March 1, 2025, and subsequent FSR postings are due July 1 and January 1 of each year.
Additional Information: Scoping Memo and Ruling (Oct. 24, 2024); ALJ Ruling (Aug. 6, 2024); Joint CCA Advice Letter on new registration (Jul. 17, 2024); Joint CCA Advice Letter on financial modeling and reporting guidelines (Jul. 1, 2024); D.24-04-009 / Appendix (Apr. 22, 2024); OIR (Mar. 25, 2021); Docket No. R.21-03-011.
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).
Recent Developments: No recent developments.
Analysis: N/A
Next Steps: A Scoping Memo setting a procedural schedule is expected in early 2025.
Additional Information: Application (Sep. 30. 2024); Docket No. A.24-09-014.
PG&E 2024 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.
5 The April 2 Scoping Memo and Ruling consolidated all three major IOUs’ ERRA forecast proceedings for the sole purpose of addressing issues related to the definition of and accounting for “fixed generation costs” in a Track 2.
Recent Developments: Parties filed briefs in this proceeding on February 3; reply briefs are due February 17.
Analysis: N/A
Next Steps: A proposed decision is expected in April 2025.
Additional Information: Scoping Memo & Ruling (Oct. 11, 2024); ALJ Ruling on Track 2 schedule (May 1, 2024); Joint CCA Motion (Apr. 26, 2024); IOU Motion (Apr. 25, 2024); Scoping Memo and Ruling (Apr. 2, 2024); Joint Prehearing Conference Statement (Mar. 26, 2024); PG&E AL 7180-E (Feb. 15, 2024); D.23-12-022 (Dec. 19, 2023); ALJ Ruling (Dec. 18, 2023); ALJ Ruling (Nov. 20, 2023); Market Price Benchmarks (Oct. 2, 2023); Scoping Ruling and Memo (Sep. 15, 2023); ERRA Trigger Application (Jul. 28, 2023); CalCCA Protest (Jun. 16, 2023); PG&E 2024 ERRA Forecast Application (May 15, 2023); Docket No. A.23-05-012.
PG&E 2021 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: This case is fully briefed and a proposed decision is expected.
Additional Information: ALJ Ruling (Nov. 9, 2023); ALJ Ruling (Sep. 27, 2023); ALJ Ruling on schedule (Jan. 6, 2023); Assigned Commissioner’s Scoping Memo and Ruling (Aug. 9, 2022); PG&E 2021 ERRA Compliance Application (Feb. 28, 2022); Docket No. A.22-02-015.
PG&E 2022 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: This case is fully briefed and a proposed decision is expected.
Additional Information: ALJ Ruling (Sep. 3, 2024); ALJ Ruling (Jul. 26, 2024); ALJ Ruling (May 22, 2024); ALJ Ruling (May 16, 2024); ALJ Ruling (Apr. 16, 2024); PG&E and CalAdvocates’ Joint Motion for Settlement (Mar. 7, 2024); CalCCA Motion (Mar. 1, 2024); ALJ Ruling (Feb. 15, 2024); ALJ Ruling (Sep. 25, 2023); Scoping Memo and Ruling (Jun. 2, 2023); PG&E 2022 ERRA Compliance Application and Notice of Availability (Feb. 28, 2023); Docket No. A.23- 02-018.
PG&E 2023 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: Opening briefs were filed on December 19.
Analysis: There are no disputed factual issues. PG&E and CalCCA indicated interest in discussing settlement terms related to the Humboldt 6 outage.
Next Steps: A proposed decision is expected by mid-March 2025.
Additional Information: Joint Case Management Statement (Nov. 6, 2024); ALJ Ruling (Oct. 21, 2024); Scoping Memo and Ruling (Jun. 12, 2024); Joint Prehearing Conference Statement (Apr. 15, 2024); CalCCA’s Protest (Apr. 5, 2024); PG&E 2023 ERRA Compliance Application (Feb. 28, 2024); Docket No. A.24-02-012.
Building Decarbonization
Background: This proceeding explores reduction of greenhouse gas (GHG) emissions associated with energy use in buildings. D.20-03-027 established the Building Initiative for Low-Emissions Development and the Technology and Equipment for Clean Heating program. D.21-11-002 adopted guiding principles for layering building decarbonization incentives, adopted incentives to help wildfire victims rebuild all-electric, and directed the IOUs to study bill impacts from electrification. 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.
6 Recent Developments: On December 26 the CPUC issued Final Resolution E-5352 providing guidance on determining eligibility for electric line extension subsidies for mixed-fuel new construction projects.
Analysis: N/A
Next Steps: Proposed decisions on Phase 4 Track A and the Phase 4 Track B staff proposal are expected in early 2025.
Additional Information: Final Resolution E-5352 (Dec. 26, 2024); PG&E AL 5004-G/7437-E (Nov. 21, 2024); ALJ Ruling and Track A Staff Proposal (Jul. 18, 2024); Scoping Memo and Ruling (Jul. 1, 2024); OIR (Feb. 8, 2019); Docket No.
R.19-01-011.
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: There is no current procedural schedule for this proceeding.
Additional Information: Final Resolution E-5358 (Dec. 26, 2024); PG&E Semi-Annual VGI Report (Sep. 13, 2024); Resolution E-5326 (Jul. 17, 2024); Letter granting extension (Jun. 5, 2024); ALJ Ruling (Jun. 3, 2024); Vehicle-Grid Integration Forum Report (May 21, 2024); Resolution E-5314 (Apr. 19, 2024); Scoping Memo and Ruling (Apr. 12, 2024); Draft Resolution E-5314 (Mar. 8, 2024); ALJ Ruling (Dec. 27, 2023); 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 and closing the proceeding was issued November 18.
R.23-03-007 Wildfire Fund NBC
2024-2026
The CPUC issued D.24-12-001 (Dec. 9, 2024) adopting a $5.95/MWh Wildfire NBC for 2025 - a slight increase from the 2024 WF NBC charge of $5.61/MWh.
R.17-06-026 PCIA Rulemaking
The proceeding was closed by D.23-06-006. D.24-08-004 (issued Aug. 2, 2024) denied SCE’s Petition for Modification of D.23-06-006 and re-closed the proceeding. Final Market Price Benchmarks (MPBs) for 2024 and forecast 2025 MPBs were issued on October 4.
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 pending Petition for Modification was denied in D.25-01- 041.
A.21-06-021 PG&E 2023 Phase
1 GRC
This proceeding is inactive, but it remains open to provide further guidance on metrics relevant to auditor reports, to consider revising the energization cost recovery mechanism, and to establish reporting requirements for reviewing the reasonableness of PG&E’s interim rate recovery in its next GRC.