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: April 11, 2024
______________________________________________________________________________ Please find attached Keyes & Fox’s March 2024 Regulatory Memorandum dated April 3, 2024 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 3, 2024.
1 Valley Clean Energy Alliance
Regulatory Monitoring Report
To: Valley Clean Energy Alliance (VCE) Board of Directors From:
Sheridan Pauker, Partner, Keyes & Fox LLP
Tim Lindl, Partner, Keyes & Fox LLP
Jason Hoyle, Principal Analyst, EQ Research, LLC
Subject: Monthly Regulatory Update
Date: April 3, 2024
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.
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 territory). Phase 1 of this proceeding will address 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: On March 14, the CPUC issued a Proposed Decision (PD) on Provider of Last Resort (POLR) policies, Financial Security Requirement (FSR) updates, a new financial monitoring process, and modifications to rules regarding CCA and ESP registration and deregistration. Under the Proposed Decision, CCAs will be required to meet a revised minimum FSR amount that is the greater of the current $147,000 or the per-account IOU fee multiplied by the number of CCA customers. For VCE, the minimum FSR will increase from the current level of $147,000 to about $270,000 due to PG&E’s per-account charge that is about 8-times higher than the same charge for SDG&E or SCE.
CCAs will be provided an additional 30 days to comply with the first FSR posting and the new FSR will be due on the first day of the second month following the IOUs’ initial FSR calculation; for example, the first FSR posting would be due January 1 if the IOU FSR calculations are filed in November. Under the Proposed Decision, CCAs will also be subject to financial monitoring by the Commission, which includes providing the Commission with the most recent audited financial statement twice per year, financial health tests that trigger reporting requirements and more stringent Tier 2 financial monitoring for CCAs that fail to satisfy one of the Tier 1 tests. A CCA has 10 days to confidentially report a failure to satisfy one of the Tier 1 financial health tests to the Commission or penalties of up to $1,000 per day apply. The development of guidelines or rules governing a customer’s voluntary transfer from one CCA to another may be considered in a later phase of this proceeding. Finally, the Proposed Decision adopts CalCCA’s recommendations for an enhanced CCA registration process including requirements for submission of a feasibility study and pro forma financial statements, including established annual assumptions, with the Implementation Plan and the creation of milestones for critical implementation actions. CCAs are required to submit a joint Tier 2 advice letter further developing these registration requirements.
Analysis: The Proposed Decision will significantly increase VCE’s FSR amount, at least until PG&E’s billing system automation upgrades are completed (potentially as soon as the end of 2025). The minimum FSR amount will likely increase because negative incremental procurement costs will no longer be netted against administrative costs.
Next Steps: The Proposed Decision may be heard as early as the April 18 Commission meeting. Comments on the Proposed Decision are due April 3 and reply comments are due April 8.
Additional Information: Proposed Decision / Appendix (Mar. 14, 2024); Amended Scoping Ruling and Memo (Jun. 19, 2023); OIR (Mar. 25, 2021); Docket No. R.21-03-011.
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 will establish 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.
2 Recent Developments: In Track B, on March 25, VCE submitted Advice Letter 17-E to expand and modify its AgFIT Pilot as required by D.24-01-032. On March 25, PG&E submitted AL 7222-E on the implementation of PG&E’s expansion of the AgFIT pilot throughout its territory and Advice Letter 7223-E addressing pilot eligibility rules for customers participating in demand response programs. In Track A, on March 27, the CPUC issued a Proposed Decision (PD) addressing the income-graduated fixed charge (IGFC) for residential customers and other requirements of AB 205 (Stats. 2022, ch. 61).
The Proposed Decision will set IGFCs for bundled customers of the IOUs at $6/month for CARE-enrolled customers, $12/month for FERA-enrolled customers, and $24.15/month for all other customers.
Analysis: The Proposed Decision’s IGFCs are significantly lower than many party proposals recommended, and they are expected to reduce volumetric rates for bundled non-CARE/FERA IOU customers of PG&E by an average of $0.047/kWh, SCE by $0.046/kWh, and SDG&E by $0.068/kWh. The Proposed Decision reasons that higher fixed charges and lower volumetric rates supports beneficial electrification and decarbonization policies.
Next Steps: Protests of and responses to VCE’s and PG&E’s Advice Letters are due April 15, and the Advice Letters request effective dates of April 24, 2024. In Track A, a decision on IGFCs can be no earlier than May 9.
Additional Information: Proposed Decision (Mar. 27, 2024); PG&E AL 7223-E (Mar. 25, 2024); PG&E AL 7222-E (Mar. 25, 2024); VCE AL 17-E (Mar. 25, 2024); D.24-01-032 (Jan. 26, 2024); D.23-04-040 on electric rate design principles (May 3, 2023); D.23-04-008 (Apr. 14, 2023); Phase 1 Scoping Memo and Ruling (Nov. 2, 2022); OIR (Jul. 22, 2022); Docket No. R.22-07-005.
PG&E Asset Transfer
Background: This proceeding addresses PG&E’s Application to transfer its non-nuclear generating assets to a new subsidiary, Pacific Generation, and sell up to 49.9% of its equity interest to third-party investors.
Recent Developments: On March 15, the ALJ issued a Proposed Decision that would deny, in its entirety, PG&E’s Application to transfer its non-nuclear generation assets to Pacific Generation. The Proposed Decision concluded that PG&E’s “novel and unprecedented” proposal could increase administrative costs and possibly rates by $3 million per year or more and that there was no information indicating whether the enterprise’s post-transaction cost of debt would be reduced below the current cost of debt by an amount sufficient to offset the increase in administrative costs. The Commission’s other primary concerns, highlighted throughout the Proposed Decision, include:
-PG&E failed to support its claims--there's just not enough on the record here. -This transaction would create more complexity/burden (for the Commission, stakeholders, and the regulatory process generally).
-There are risks related to the Minority Investors (e.g., issues related to conflicts of interest). -This transaction might have jurisdictional impacts.
Analysis: CalCCA recommended that the Commission deny this Application in its entirety. The Proposed Decision adopted this recommendation and drew heavily from CalCCA’s arguments in briefing to justify its rejection of the Application.
Next Steps: The Proposed Decision may be heard as soon as the April 18 Commission meeting. Comments on the Proposed Decision are due April 4 and reply comments are due April 9.
Additional Information: Proposed Decision (Mar. 15, 2024); ALJ Ruling granting Party Status to the tribal governments (Nov. 16, 2023); PG&E Response to Pit River Tribe and Potter Valley Tribe (Nov. 9, 2023); Motions for Party Status of Potter Valley Tribe and Pit River Tribe (Nov. 9, 2023); PG&E Notice (Jun. 8, 2023); ALJ Ruling (Mar. 30, 2023); Scoping Memo and Ruling (Jan. 20, 2023); PG&E Application (Sep. 28, 2022); Docket No. A.22-09-018.
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: No recent development in the past month.
Analysis: N/A
Next Steps: VCE’s next IRP filing will be due no earlier than November 1, 2024, and as late as November 1, 2025; the Commission will set the exact deadline in an amended scoping memorandum that will be issued in this proceeding in mid-2024.
Additional Information: D.24-02-047 (Feb. 20, 2024); PG&E AL 7105-E (Dec. 19, 2023); D.23-12-014 (Dec. 19, 2023); ALJ Ruling and Supporting Material (Oct. 5, 2023); Scoping Memo and Ruling (Aug. 21, 2023); Joint Expedited Petition for Modification (Aug. 9, 2023); Petition for Modification (May 30, 2023); D.23-02-040 on Procurement (Feb. 28, 2023); ALJ Ruling & Reliable and Clean Power Procurement Program: Staff Options Paper (Sep. 8, 2022); D.22-05-015 (May 23, 2022); D.21-06-035 (Jun. 30, 2021); Scoping Memo (Sep. 24, 2020); Docket No. R.20-05-003.
3 NEWDiablo Canyon Cost Recovery
Background: This proceeding will determine the methodology for cost recovery and the allocation of costs and benefits associated with extended operations of the Diablo Canyon Power Plant (DCPP). These costs as well as resource adequacy (RA) and greenhouse gas-free benefits will be allocated to all retail customers, including CCA customers.
Recent Developments: PG&E’s March 29 Application estimates a net revenue requirement of $418.4 million for extended operations at the Diablo Canyon Power Plant (DCPP), of which 55.5% is allocated to retail customers in PG&E’s territory, 36% to retail customers in SCE’s territory, and 8.5% to retail customers in SDG&E’s territory. These costs will be recovered through a public purpose nonbypassable charge estimated at $2.07/month for non-CARE customers in PG&E territory, $1.25/month for non-CARE customers in SCE territory, and $0.87/month for non-CARE customers in SDG&E territory. Additionally, PG&E proposed an adjustment to the associated RA and GHG-free benefits that would increase the share of those benefits allocated within its territory in proportion to the higher share of costs allocated to customers in PG&E territory.
Analysis: Extended operations at the Diablo Canyon facility are considered essential for system reliability in the near term. PG&E’s proposed adjustment to the allocation of benefits would more closely align the allocation of costs and benefits so that while customers in PG&E territory pay slightly higher costs they would also receive slightly more benefits.
Next Steps: Protests or responses are due 30 days from the date the Application first appears in the daily calendar (the Application has not yet been included in the daily calendar).
Additional Information: Application (Mar. 29, 2024); Docket No. A.24-03-018.
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 will be the forum for review of VCE’s next RPS Procurement Plan and RPS Compliance reports.
Recent Developments: Opening comments on the OIR were filed on March 4 and reply comments were filed on March
14. A March 7 ALJ Ruling scheduled the prehearing conference for April 4.
Analysis: N/A
Next Steps: A prehearing conference is scheduled for April 4, which will be followed by a scoping memo and ruling in late Q1 or sometime in Q2.
Additional Information: ALJ Ruling (Mar. 7, 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 is focused on priority issues including RA capacity requirements, SOD framework implementation, and RA compliance and penalties. Track 2 is focused on Central Procurement Entity framework issues, including potential structural modifications, and Track 3 is focused on remaining RA capacity issues.
Recent Developments: Opening comments on Track 1 proposals were filed on March 8 and reply comments were filed on March 22. Party comments focused on issues related to SOD implementation, including whether to adopt hourly load transactability such that LSEs would be allowed to transfer hourly RA obligations to provide liquidity to the RA market (proposed by CalCCA), whether implementation of the SOD framework should be delayed until 2026 or later, whether the Commission should implement waivers for system or flexible RA obligations, the appropriate planning reserve margin, and whether the Commission should require further transparency on IOU management of RA resources. PG&E generally opposes delaying the implementation of SOD, system or flexible RA waivers, and further transparency. In Track 2, on March 18, an ALJ Ruling provided the Energy Division’s Proposed Inputs & Assumptions for use in the Resource Adequacy Loss of Load Expectation (LOLE) Study.
Analysis: N/A
Next Steps: A proposed decision on Track 1 is expected in May and a final decision in June. The Test Year 2024 SOD Month Ahead showings are due to Energy Division on June 1 and September 1. Track 2 begins with an Energy Division report on the CPE framework expected in the first quarter of 2024, and proposals on the CPE framework and coordination with the IRP proceeding are due May 13. A report from the CAISO on local capacity requirements for 2025 is expected on April 4 and comments on the draft report are due April 19.
Additional Information: ALJ Ruling (Mar. 18, 2024); CalCCA Revised Proposal (Feb. 23, 2024); Staff Report (Appendices) on SOD (Jan. 22, 2024); CalCCA Proposal, CalAdvocates Proposal, WPTF Proposal (Jan. 19, 2024); (Scoping Memo and Ruling (Dec. 18, 2023); Cal CCA Opening Comments on OIR (Nov. 8, 2023); ALJ Ruling (Oct. 27, 2023); OIR (Oct. 16, 2023); Docket No. R.23-10-011.
4 Microgrids
Background: This proceeding was opened to implement the requirements of SB 1339 (Stern, 2018), requiring the commercialization of microgrids for distribution customers of the large IOUs. The initial three tracks have concluded, and Track 4 and Track 5 address the establishment of a Microgrid Incentive Program (MIP), potential contributions that microgrids can make to mitigating capacity shortages in the near-term, the development of a multi-property microgrid framework, and examination of the value of resiliency from microgrids.
Recent Developments: On March 27, the ALJ issued a Ruling requesting comment on stakeholder multi-property microgrid tariff proposals’ alignment with the Commission’s nine environmental and social justice (ESJ) action plan goals.
Analysis: N/A
Next Steps: Responses to ESJ questions on tariffs are due April 19. Comments on responses are due May 3 and reply comments are due May 17. The Joint Application for Rehearing is pending.
Additional Information: ALJ Ruling (Mar. 27, 2024); Microgrid Resources Coalition proposal, Green Power Institute proposal, Clean Coalition proposal (Dec. 15, 2023); PG&E MIP Handbook (Oct. 12, 2023); Scoping Memo and Ruling (Jul. 18, 2023); D.23-04-034 on Microgrid Incentive Program Implementation (Apr. 14, 2023); Docket No. R.19-09-009.
PG&E 2023 Phase 1 GRC
Background: Phase 1 General Rate Case (GRC) proceedings set PG&E’s revenue requirement, including functionalizing costs into categories such as electric distribution or generation, and impact the costs recovered through rates from customers (e.g., bundled, unbundled, or both) for a set period (in this case, 2023-2026).
Recent Developments: Opening briefs on Phase II issues (pertaining to energization project costs) were filed on March
22. Analysis: N/A
Next Steps: Reply briefs are due April 5, per a February 12 Ruling. A proposed decision is expected late in the second quarter of 2024.
Additional Information: Case Management Statement (Feb. 26, 2024); Third Amended Scoping Memo and Ruling (Dec. 22, 2023); D.23-11-069 / Appendices (Nov. 17, 2023); Second Amended Scoping Memo and Ruling (Oct. 10, 2023); Illustrative rates (Sep. 27, 2023); Scoping Memo and Ruling (Sep. 5, 2023); PG&E’s Amended Application (Mar. 10, 2022); PG&E Application (Jun. 30, 2021); Docket No. A.21-06-021.
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 nonbypassable 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: CalCCA, San Diego Community Power, and Clean Energy Alliance filed a Joint Prehearing Conference Statement in which the joint CCA Parties recommended the Commission consolidate the IOUs’ ERRA Forecast proceedings for the sole purpose of addressing Track 2 issues, that the Commission not include the Replacement Resource Adequacy costs in Track 2 scoping issues, and that the Track 2 scope include vintaging of utility-owned generation and IOU procurement contracts and also address threshold questions related to fixed generation costs.
The April 2 Scoping Memo and Ruling consolidated all thee major IOUs’ ERRA forecast proceedings for the sole purpose of addressing issues related to the definition of and accounting for fixed generation costs.
Analysis: PG&E’s identified preliminary Track 2 scoping issues are centered on “allocation methodologies for Common Costs and clarification on accounting for outage costs arising from Replacement RA requirements”, which could impact the allocation of PCIA-eligible portfolio costs between bundled and unbundled (i.e. CCA) customers.
Next Steps: Intervenor testimony is due May 8, opening briefs are due June 25, and reply briefs are due July 10. A proposed decision is expected in September.
Additional Information: 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 in the past month.
Analysis: N/A
Next Steps: A proposed decision is expected in early 2024.
5 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: On March 1, CalCCA filed a Motion for Commission Review of certain evidentiary rulings – each related to PG&E’s treatment of excess resource adequacy (RA) during 2022. On March 7, PG&E and CalAdvocates filed a Joint Motion for Adoption of Settlement that would resolve some issues of the moving Parties with respect to utility-owned nuclear generation, require PG&E to provide certain information in its 2024 ERRA Compliance filing as well as update its preliminary statement via advice letters, and under which CalAdvocates would withdraw its recommended disallowances. On March 15, an ALJ Ruling extended the deadline for briefings.
Analysis: N/A
Next Steps: The extended briefing deadlines are April 19 for Opening Briefs and May 20 for Reply Briefs. CalCCA’s Motion for Commission Review remains pending.
Additional Information: ALJ Ruling (Mar. 15, 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: No recent developments in the past month.
Analysis: N/A
Next Steps: Protests and responses to the Application are due April 5.
Additional Information: PG&E 2023 ERRA Compliance Application (Feb. 28, 2024); Docket No. A.24-02-012.
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: Draft Resolution E-5314, issued on March 8, would approve PG&E’s nearly $18.8 million funding request in AL 6883-E (also AL 6883-E-A and AL 6883-E-B) for three-year a technical assistance advisory services program, Transportation Electrification Advisory Services (TEAS), to support medium-and heavy-duty (MDHD) vehicle customers.
Analysis: PG&E’s technical advisory services would support planning and increased adoption of MDHD electric vehicles in the state and provide additional information for further evaluation of electric vehicle charging in this transportation sector.
Next Steps: A scoping memo and ruling from the Assigned Commissioner is expected May 28. The Draft Resolution is scheduled to be heard at the April 18 Commission meeting.
Additional Information: Draft Resolution E-5314 (Mar. 8, 2024); ALJ Ruling (Dec. 27, 2023); OIR (Dec. 20, 2023); Docket No. R.23-12-008.
Demand Response Programs (2023-2027)
Background: This proceeding addresses the IOUs’ Demand Response (DR) Portfolio Applications required under D.17- 12-003 for the years 2023-2027.
Recent Developments: Comments on the Proposed Decision that would sunset the Demand Response Auction Mechanism (DRAM) pilot programs of PG&E, SCE, and SDG&E were filed on March 21 and reply comments were filed on March 26.
Analysis: The Proposed Decision would terminate the DRAM pilots because they were not found to be successful, “particularly in the areas of performance and reliability.” Next Steps: The Proposed Decision on the DRAM may be heard as soon as the April 18 Commission meeting.
6 Additional Information: Proposed Decision on DRAM (Mar. 1, 2024); D.23-12-005 (Dec. 20, 2023); ALJ Ruling (Aug. 24, 2023); D.23-01-006 (Jan. 13, 2023); Scoping Memo and Ruling (Dec. 19, 2022); D.22-12-009 (Dec. 6, 2022); Ruling consolidating Applications (May 25, 2022); PG&E Application (May 2, 2022); Docket No. A.22-05-002.
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 3B will consider building decarbonization efforts regarding the reasonableness of modifying or ending electric line extension allowances, refunds, and discounts for “mixed-fuel” new construction (i.e., building projects that use gas and/or propane in addition to electricity).
Recent Developments: On March 13, TECH Clean California submitted its second Annual Report.
Analysis: N/A
Next Steps: Phase 3B concluded with issuance of D.23-12-037, and an updated scoping memo and procedural schedule is expected.
Additional Information: TECH Clean California Annual Report (Mar. 13, 2024); PG&E AL 7158-E (Jan. 29, 2024); D.23- 12-037 (Dec. 21, 2023); Amended Scoping Memo and Ruling (Jul. 26, 2023); D.23-02-005 (Feb. 3, 2023); D.21-11-002 (Appendices A-E) Decision on Building Decarbonization Phase II (Nov. 9, 2021); D.20-03-027 Establishing Building Decarbonization Pilot Programs (Apr. 6, 2020); 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
R.18-07-003 RPS Rulemaking This proceeding remains open for the limited purpose of considering Final 2023 RPS Procurement Plans.
R.21-10-002 RA Rulemaking
(2023-2024)
The proceeding was closed by D.23-12-038, and closed again by issuance of D.24-03-004 (issued March 12, 2024) denying the California Large Energy Consumers Association’s Petition for Rehearing.
A.21-03-008 PG&E 2020 ERRA
Compliance The proceeding was closed by D.23-12-019 in December 2023.
R.18-12-006 Transportation
Electrification
The proceeding was closed by the December 2023 OIR establishing R.23-12- 008, but it has been re-opened pending resolution of a Petition for Modification of D.22-11-040 filed on November 20, 2023.
R.21-10-001 Utility Safety Culture
Assessments
The proceeding has been inactive since July 2023 and is awaiting issuance of a proposed decision.
R.23-03-007 Wildfire Fund NBC
2024-2026
The next 90-day Notice for the 2025 Wildfire NBC is expected in September 2024.
R.17-06-026 PCIA Rulemaking
The proceeding was closed by D.23-06-006, but SCE’s Petition for Modification of D.23-06-006, filed on September 12, 2023, that requests clarification on certain points regarding the valuation of previously banked RECs remains outstanding.
I.15-08-019
Investigation into
PG&E Organization,
Culture, and
Governance
This proceeding was opened as part of an investigation into whether PG&E’s organizational culture and governance prioritize safety, and currently serves to monitor the progress of PG&E in improving its safety culture. On May 19, 2023 the CPUC issued D.23-05-009 adopting the Safety Policy Division’s Modified Staff Report and closing the proceeding.
A.20-06-011 PG&E
Regionalization Plan
D.22-06-028 closed the proceeding. PG&E will continue to convene quarterly “town hall” meetings in each region and conduct broader meetings with the Regionalization Stakeholder Group. PG&E’s Q4 2023 Quarterly Report A.20-10-011
Commercial EV
Real-Time Pricing
Pilot
Opt-in enrollment for the real-time pricing export compensation pilot was extended and now expected to begin by February 28, 2025. A status update is due by August 28, 2024. D.23-07-003 closed the proceeding.