December 31, 2025

Regulatory Update for December 31, 2025

(Covering December 17 - December 30, 2025)

Our energy regulatory team has compiled a list of state and federal energy regulatory developments to keep you up to speed on key energy regulatory matters from across the United States. Stoel’s energy regulatory team is always available to answer questions about any of these developments. Click here to meet the energy regulatory team.

Jump to the following jurisdictions:

State Regulatory Agencies

• California Public Utilities Commission (CPUC)
• California Energy Commission (CEC)
• California Air Resources Board (CARB)
• Pacific Northwest (OPUC, WUTC)

Federal Regulatory Agencies

• Federal Energy Regulatory Commission (FERC)

Independent System Operators (ISO) and Regional Transmission Organizations (RTO)

• California Independent System Operator (CAISO)
• PJM Interconnection (PJM)
• Southwest Power Pool (SPP)
• ISO New England (ISO-NE)

Click here to download this update as a PDF

State Regulatory Agencies

CALIFORNIA PUBLIC UTILITIES COMMISSION (CPUC or COMMISSION)[1]

Proposed Decisions and Resolutions

Rulemaking (R.) 24-01-018 (Order Instituting Rulemaking to Establish Energization Timelines)

This decision directs Pacific Gas and Electric Company (PG&E) and Southern California Edison Company (SCE) to establish a standard offer process within the Design and Engineering step of their energization process that establishes an optional Flexible Service Connection1 (FSC) agreement for customers affected by distribution capacity constraints. PG&E and SCE are required to implement ongoing data collection and reporting to facilitate refinement of the standard offer, make associated changes to their Tariff Rules, and file a report summarizing the cost-efficiency of this standard offer process. PG&E and SCE are directed to formalize the preliminary capacity assessment processes that currently allow their prospective customers to evaluate the likelihood of suitable capacity at a particular grid location. SCE is directed to prepare and file a report assessing learnings from the FSC pilot that concludes on January 3, 2026. The proceeding remains open to address Phase II issues.

Application (A.) 23-12-001 (Application of Pacific Gas and Electric Company for Recovery of Recorded Expenditures Related to Wildfire Mitigation, Catastrophic Events, and Other Recorded Costs)

This decision authorizes PG&E to recover $1.416 billion in revenue requirement for costs it incurred in 2022 for wildfire mitigation, vegetation management, and catastrophic events, along with other amounts in various memorandum accounts related to the COVID pandemic, disconnections, climate adaptation, and other matters. This decision approves an uncontested settlement agreement regarding all costs requested for recovery, except the costs for vegetation management. This decision denies recovery of $363.4 million in vegetation management costs. Further, the Decision directs PG&E to submit a Tier 2 Advice Letter (AL) to recover the amounts authorized, with offsetting of the amount already collected in rates by PG&E under the interim rate relief granted in Decision 24-09-003.

Voting Meeting

The CPUC will hold a voting meeting in San Francisco, California on January 15, 2026, at 11:00 a.m. PT. In the meantime, the energy-related results from the December 18 Voting Meeting are below:  

Item 2. Rulemaking (R.) 18-07-003 (Order Instituting Rulemaking to Continue Implementation and Administration and Consider Further Development of California Renewables Portfolio Standard Program)

This decision denies the March 6, 2025 petition to modify D.20-08-043, filed by the Bioenergy Association of California (BAC).  BAC is seeking to extend or remove the end date of the Bioenergy Market Adjusting Tariff (BioMAT) and proposes other programmatic changes, primarily due to underutilization of this high-cost program and availability of other procurement options for bioenergy resources.  The decision contends that maintaining the BioMAT end date, December 31, 2025, as directed by the Commission in D.20-08-043, is in alignment with the October 30, 2024 Governor’s Executive Order N-5-24 on affordability, and will allow Commission resources to be directed toward more effective clean energy programs. Held to January 15.

Item 3. Application (A.) 23-07-008 (In the Matter of the Application of California Resources Production Corporation (CRPC) for a Certificate of Public Convenience and Necessity to Operate as a Gas Corporation in the State of California)

This decision denies A.23-07-008 and the request to hold this proceeding in abeyance made by the cities of Antioch and Brentwood, California.  The decision further denies CRPC’s motion to amend A.23-07-008 and grants for a period of three years CRPC’s motions to file certain materials as confidential under seal. Held to January 15.

Item 4. R.20-08-022 (Clean Energy Financing Tariff On-Bill Pilot Program)

This decision authorizes SCE to recover $7 million to administer its Tariff On-Bill Financing Pilot proposal, with modifications, and denies the proposals put forth by San Diego Gas and Electric (SDG&E), Southern California Gas Company (SoCalGas), and Silicon Valley Clean Energy. Signed, D.25-12-021.

Item 7. Application (A.) 25-04-005 (Application of SoCalGas for Authorization to (1) issue debt securities in an aggregate principal amount of up to $3.3 billion; (2) include certain features in debt securities or enter into certain derivative transactions; (3) hedge issuances of debt securities; and (4) take all other necessary related actions)

This decision grants SoCalGas authority to issue up to $3.3 billion in new debt securities.  This decision also authorizes SoCalGas to take various actions to improve the terms and conditions of SoCalGas’ debt portfolio and lower the cost of financing, and to take additional actions. Signed, D.25-12-022.

Item 8. Resolution (Res). E-5430

This Resolution approves, with modification, SoCalGas AL 6523-G, the joint proposal by SoCalGas, PG&E, SCE, and Center for Sustainable Energy (CSE), known as the Joint PAs.  This Resolution approves, with modification, SCE AL 5617-E, the Joint PAs’ Self-Generation Incentive Program (SGIP) Inflation Reduction Act (IRA) Tax Credit proposal following the changes implemented by the federal House Bill 1 enacted on July 4, 2025. Approved.

Item 9. Application (A.) 24-10-002 (Application of SCE for Authority to Recover Costs Related to the 2018 Woolsey Fire Recorded in the Wildfire Expense Memorandum Account and Catastrophic Event Memorandum Account)

This decision adopts the September 19, 2025 Settlement Agreement regarding the request by SCE for approval and recovery of certain costs associated with the November 2018 Woolsey Fire in Ventura County, California.  The adopted Settlement Agreement includes, among other things, a permanent disallowance of approximately $3.676 billion of SCE’s recorded costs associated with the Woolsey Fire.  The Settlement Agreement reflects a reduction, as SCE’s initial request was $5.43 billion of costs recorded to the Wildfire Expense Memorandum Account (WEMA) for third-party claims, legal costs, and financing costs minus insurance reimbursements and non-jurisdictional costs. Additionally, the settlement includes $83.8 million of costs recorded to the Catastrophic Event Memorandum Account (CEMA), including $82.3 million in capital expenditures and $1.5 million in expense to restore service to customers, repair, replace, or restore damaged facilities, and comply with government orders related to the Woolsey Fire. Signed, D.25-12-023.

Item 10. Application (A.) 24-05-020 (In the Matter of the Application of Bear Valley Electric Service, Inc. (BVES) for a Certificate of Public Convenience and Necessity to Acquire, Own, and Operate the Bear Valley Solar Energy and Battery Storage Projects and Authorize Ratemaking Associated with the Projects Capital Investment and Operating Expenses)

This decision authorizes BVES to own and operate a five megawatt (MW) alternating current / 6.1 MW direct current photovoltaic solar generation facility and a 5 MW/20 megawatt-hour (MWh) battery storage system.  The solar generation facility will be constructed on approximately 21 acres located at 2151 Erwin Ranch Road, Big Bear, California.  The solar project will be interconnected to BVES’ existing system with the construction of 1.8 miles of new 34.5 kilovolt electrical lines.  The battery storage system will be located within the boundaries of BVES’ existing Meadow Substation at 42020 Garstin Drive, Big Bear Lake, California. Signed, D.25-12-024.

Item 11. Rulemaking (R.) 24-01-017 (Order Instituting Rulemaking to Continue Implementation and Administration, and Consider Further Development, of California Renewables Portfolio Standard Program)

This decision adopts, with modifications, the Draft 2025 Renewables Portfolio Standard (RPS) Procurement Plans of the large Investor-Owned Utilities (IOUs), the small and multi-jurisdictional utilities, the Community Choice Aggregators (CCAs), and the Electric Service Providers. Signed, D.25-12-025.

Item 13. Application (A.) 24-09-015 (Application of PG&E for Recovery of Recorded Expenditures in Transmission Revenue Requirement Reclassification Memorandum Account)

This decision authorizes PG&E to recover in rates a revenue requirement of $338.2 million for balances recorded in PG&E’s Transmission Revenue Requirement Reclassification Memorandum Account that reflects jurisdictional reclassification of certain costs from Federal Energy Regulatory Commission (FERC) transmission jurisdiction to CPUC distribution jurisdiction.  This amount includes $372.8 million for recovery of Common, General, and Intangible plant costs and related expense revenue requirements, $7.9 million for two facilities that changed from California Independent System Operator (CAISO) operational control to non-CAISO operational control in 2023 and associated operations and maintenance expense, and a retail offset of $42.6 million associated with facilities reclassified from distribution to transmission in 2023.  The authorized revenue requirement will be recovered in rates beginning January 1, 2026, or the first practicable billing cycle thereafter. Signed, D.25-12-026.

Item 15. Applications (A.) 25-05-011/A.25-09-015 (Application of PG&E for adoption of Electric Revenue Requirements and Rates Associated with its 2026 Energy Resource Recovery Account (ERRA) and Generation Non-Bypassable Charges Forecast and Greenhouse Gas (GHG) Forecast Revenue Return and Reconciliation)

This decision adopts the 2026 ERRA and related forecasted energy costs and the 2026 electric sales forecast for PG&E.  The decision also adopts PG&E’s 2026 forecast revenue requirements for GHG and climate-related costs.  The estimated 12-month gross revenue requirement for 2026 is approximately $4.511 billion, 6.1 percent higher than the adopted 12-month gross revenue requirement for 2025. Signed, D.25-12-027.

Item 16. A.25-05-008 (Application of SCE for Approval of its 2026 ERRA Forecast Proceeding Revenue Requirement)

This decision approves, with modifications, SCE’s amended 2026 ERRA 1 revenue requirement request of $4.689 billion, an increase of $228.250 million, roughly 5.1 percent, above the adopted 2025 ERRA revenue requirement. Signed, D.25-12-028.

Item 17. Application (A.) 24-03-011 (Application of PG&E for Comprehensive Gas Advanced Metering Infrastructure Replacement Program)

This decision grants the Joint Motion for Adoption of Settlement Agreement filed by PG&E, the Public Advocates Office at the CPUC, the Utility Reform Network, and Small Business Utility Advocates.  Specifically, this decision approves and adopts the proposed Settlement Agreement regarding PG&E’s Comprehensive Gas Advanced Metering Infrastructure Replacement Program to replace and upgrade battery-operated Gas Modules installed on customer gas meters that transmit customer gas usage. Signed, D.25-12-029.

Item 32. Rulemaking (R.) 24-09-012 (Order Instituting Rulemaking to Establish Policies, Processes, and Rules to Ensure Safe and Reliable Gas Systems in California and Perform Long-Term Gas System Planning)

This decision designates initial priority neighborhood decarbonization zones, as required by CPUC Code Section 662(a).  By January 16, 2026, PG&E, SoCalGas, and SDG&E shall update the maps they submitted to the Commission on July 1, 2025, to include the initial priority neighborhood decarbonization zones.  This decision does not designate any initial priority neighborhood decarbonization zones within Southwest Gas’s (SWG) service area.  PG&E, SoCalGas, SDG&E, and SWG are also ordered to conduct outreach and host and record one virtual Senate Bill (SB) 1221 information session in each of their service areas by March 15, 2026. Signed, D.25-12-042.

Item 33. Applications (A.) 22-05-015/22-05-016 (Application of SoCalGas for Authority, Among Other Things, to Update its Gas Revenue Requirement and Base Rates Effective on January 1, 2024)

In this application, SDG&E seeks recovery of costs recorded in its Electric and Gas Wildfire Mitigation Plan Memorandum Accounts (WMPMAs) from May 2019 through the end of 2022, above amounts not authorized by the Commission in SDG&E’s 2019 Test Year GRC decision (D.19-05-051).  The amount requested includes recovery of operations and maintenance (O&M) costs totaling $284 million and capital expenditures placed in service during the 2019 to 2022 period of $1,188 million. This decision finds unreasonable and disallows $192.561 million in O&M costs and $242.391 million in capital expenditures. The Commission approves the balance requested of $90.566 million in O&M expenses and $945.248 million in capital expenditures. Held to January 15.

Item 34. Applications (A.) 25-03-010/A.25-03-011/A.25-03-013 (Application of PG&E for Authority to Establish Its Authorized Cost of Capital for Utility Operations for 2026, et al.)

This decision establishes the 2026 ratemaking cost of capital for PG&E, SoCalGas, SCE, and SDG&E. Signed, D.25-12-043.

Item 35. Resolution (Res) E-5413

This Resolution adopts, with modifications, the proposals of PG&E, SCE, and SDG&E to establish a pending loads category in the utility distribution planning process, pursuant to decision D.24-10-030. Approved.

Item 36. Resolution (Res) E-5414

This Resolution adopts, with modifications, the proposals of PG&E, SCE, and SDG&E to establish a scenario planning framework in the distribution planning process.  AL 4675-E contains separate proposals from each of the joint utilities on the scenario planning framework, pursuant to D.24-10-030. Approved.

Upcoming Workshops and Events

High Distributed Energy Resources (DER) Proceeding – Integration Capacity Analysis (ICA) Workshop

Commission staff will host the Fourth Quarter ICA Workshop (required pursuant to D.24-10-030) on Wednesday, December 17, 2025 from 9:00 a.m. to 12:00 p.m. PT.  The workshop will include utility presentations on ICA remediation plans, timelines, and progress updates, along with an overview from the CPUC’s Energy Division and an opportunity for stakeholder input. Workshop registration is available here and questions can be directed to the CPUC’s Grid Planning department (raymond.breault@cpuc.ca.gov).

CALIFORNIA ENERGY COMMISSION (CEC)

2025 Integrated Energy Policy Report (IEPR)

The CEC held a remote access workshop on December 17, 2025 from 9:00 a.m. to 12:00 p.m. PT to discuss energy demand forecast results.  According to the workshop notice, “CEC staff will present the results of the annual electricity and gas demand forecasts and the hourly and peak demand forecast components of the 2025 California Energy Demand Forecast” as well as “electricity results through 2045 for the combination of scenarios proposed for the planning forecast and local reliability scenario.”  Lastly, “[g]as impacts will be presented for a range of additional achievable scenarios.”  Written comments are due to Docket Number (No.) 25-IEPR-03 by 5:00 p.m. PT on December 31, 2025.

RPS Eligibility Guidebook (10th Edition)

The CEC adopted the 10th Edition of its RPS Eligibility Guidebook (RPS Guidebook) at its December 19, 2025 Business Meeting.  The RPS Guidebook describes the eligibility requirements and process for certifying facilities as RPS-eligible and the rules and process for verifying renewable energy certificates for compliance with California’s RPS program.  The RPS Guidebook is revised periodically to reflect statutory, market, and regulatory developments, as appropriate. Versions of the revised draft RPS Guidebook 10th Edition (both clean and redline) are now available in Docket No. 21-RPS-02.

Third Solicitation Under the National Electric Vehicle Infrastructure (NEVI) Program

The CEC announced the opening of its third solicitation for the deployment of electric vehicle (EV) charging stations with publicly accessible, high-powered, direct current fast chargers (DCFCs) to support light-duty EV travel along major corridors in California. 

A pre-solicitation workshop will be held on January 14, 2026 from 9:30 a.m. to 12 p.m.  Additional information and access details are available here.

CEC Business Meetings

The next CEC Business Meeting is scheduled for January 21, 2026.  The agenda will be posted in advance here.

CALIFORNIA AIR RESOURCES BOARD (CARB)

Climate Risk Disclosure Laws Update

On February 26, 2026, CARB will conduct a public hearing to consider approving for adoption the proposed California Corporate Greenhouse Gas Reporting and Climate-Related Financial Risk Disclosure Initial Regulation.  The Notice of Public Hearing to Consider the Proposed California Corporate Greenhouse Gas Reporting and Climate-Related Financial Risk Disclosure Initial Regulation (Notice), Staff Report (Initial Statement of Reasons), and proposed regulatory text were sent to the California Office of Administrative Law (OAL) on December 9, 2025.  These materials are currently available on CARB’s webpage.  OAL published the Notice on December 26, 2025, commencing a 45-day public comment period that will end on February 9, 2026.  Given the holiday season and the strong interest in this program, staff is providing extra time for public review of materials prior to the start of the 45-day formal comment period.

Meetings, Workshops, and Opportunities for Public Comment

CARB is proposing 2025 Amendments to the Area Designations for State Ambient Air Quality Standards.  Written comments on the proposed 2025 Amendments must be received by January 12, 2026 to be considered.  A public hearing is not currently scheduled; however, interested members of the public may request a public hearing on this item.

CARB is opening a public process to solicit feedback to inform implementation of annual GHG standards for fuel cell systems connected under the CPUC’s Net Energy Metering (NEM) tariff for fuel cells (CPUC NEMFC).  The CPUC NEMFC was established by Assembly Bill (AB) 1214, modified by AB 1637, and further modified by SB 155.  AB 1637 directed CARB to establish a schedule of GHG emissions standards for connected fuel cells and mandated that connected fuel cells meet the same requirements for criteria pollutants set in CARB’s Distributed Generation Certification Program.  In 2017, CARB adopted the Fuel Cell Net Energy Metering Greenhouse Gas Emission Standards Regulation (Fuel Cell NEM Regulation), which included annual mandatory emissions standards for 2017 to 2022.  Beyond 2022, the regulation provides that CARB will update the standards every three years using the methodology defined in the regulation.  D.23-11-068 approved a staff proposal that directed modifications to the CPUC NEMFC tariffs.  CARB is opening a public process to evaluate new data, and as necessary, update the schedule of annual GHG emission standards set under the Fuel Cell NEM Regulation.  Public comments will be accepted through January 9, 2026.

PACIFIC NORTHWEST (OPUC, WUTC)

Oregon Public Utility Commission (OPUC)

On December 30, 2025, the OPUC held an agenda meeting with commissioner work sessions regarding (1) the residential customer protection rulemaking docket, specifying conditions under which utilities may disconnect service for nonpayment, establishing timelines and notice requirements, and setting standards for reconnection (Docket No. AR 671), (2) implementation of HB 2475, regarding emergency actions to mitigate energy insecurity (Docket No. UM 2211), (3) a request to cancel Northwest Natural’s Schedule 160, regarding charges for Coos County customers and a proposal for Coos County Pipeline (Docket No. ADV 1789), and (4) revisions to Idaho Power Company’s Schedule 98, regarding the Residential and Small Farm Energy Credit (Docket No. ADV 1806/Advice No. 25-09). The full agenda is here.

Washington Utilities and Transportation Commission (WUTC)

The WUTC rejected Puget Sount Energy’s (PSE) proposed rate request to recover costs related to the Colstrip coal-fired power plant, instead directing PSE to file new tariff sheets that will decrease its revenue by $6.84 million and refund the decrease to customers beginning in January 2026. More information is here. Additionally, on December 22, 2025, the WUTC approved updates to Pacific Power & Light Company’s (PacifiCorp) electric service tariff, a rate case that was required by a prior order to reset the company’s baseline power costs and remove coal from Washington customer rates by January 1, 2026. More information is here. On December 23, 2025, the WUTC held an open meeting covering, in part, the Avista Corporation and PSE filings to implement annual changes to rates under the Colstrip Adjustment Rider, which would result in an average overall bill decrease of $10.65 per month, or 8.4 percent, for Avista customers (UE-250856), and $3.04 per month, or 2.2 percent, for PSE customers (UE-250733). The full agenda is here.

Federal Agencies

FEDERAL ENERGY REGULATORY COMMISSION (FERC)

December Commission Meeting         

FERC held its December Commission Meeting on December 18, 2025. Among other actions, FERC:

• On remands from the D.C. Circuit, issued orders reversing FERC’s previous decisions to order Tenaska Power Services Co. and Shell Energy N.A. (US) to pay refunds for spot market energy sales that exceeded a soft price cap of $1,000 per MWh;
• Denied a request for rehearing made in response to a FERC order that accepted a proposed index-based rate increase;
• Accepted a local gas distribution company’s proposal to update its natural gas quality standards based on its experiences and those of its customers under current standards; and
• Issued draft presidential permits to Texas Pipeline Exports, LLC for the operation of certain natural gas facilities at the international boundary between the United States and Mexico.

Independent System Operators (ISO) and Regional Transmission Operators (RTO)

CALIFORNIA INDEPENDENT SYSTEM OPERATOR (CAISO)

Interconnection Process Enhancements 5.0: Final Proposal Posted

The CAISO posted the final proposal for the Interconnection Process Enhancements 5.0 initiative and will host a virtual stakeholder meeting on January 7, 2026. Written comments are due by the end of the day on January 21, 2026.

Stakeholder Initiatives: Upcoming Meetings and Deadlines

Congestion Revenue Rights Enhancements

CAISO has published a discussion paper on Congestion Revenue Rights Enhancements, available here.

Day-Ahead Market Enhancements

CAISO hosted a Day-Ahead Market Enhancements Configurable Parameters implementation working group meeting on December 18, 2025.  During the working group, CAISO presented analysis results for the set of enforced constraints and the proportion of deployed reserves.  The working group also discussed and responded to stakeholder comments received in the November working group session.  Written comments on the working group session are due January 8, 2026.  Further information is available here.

Cluster 15 Points of Interconnection Heatmap

CAISO has updated the points of interconnection heatmap to include the Cluster 15 Cluster Study scenario in compliance with CAISO Tariff Appendix KK Section 3.6.  Further information is available here.

Final 2026-2028 Policy Roadmap

CAISO has published the 2026-2028 Policy Roadmap, which outlines the policy initiatives and schedules planned for the next three years.  Further information is available here.

Manning - Metcalf 500kV Transmission Line Project

CAISO has posted a list of project sponsors whose applications have been deemed valid for the Manning - Metcalf 500kV Transmission Line Project.  Next, CAISO will consider whether these project sponsors are qualified, and then select which qualified project sponsor should finance, construct, own, operate, and maintain each transmission solution.  Further information is available here.

Storage Design and Modeling

CAISO has posted the updated discussion and issue paper on Uplift and Default Energy Bid (DEB).  This updated discussion and issue paper seeks to capture the problem statements, guiding principles, stakeholder perspectives, and policy recommendations shared during the working group’s process regarding the Uplift and DEB topic group.  The updated discussion and issue paper builds on the materials developed for the Storage Bid Cost Recovery and Default Energy Bid Enhancements initiative in 2024 and the working group meetings held from December 2024 to December 2025 within the Storage Design and Modeling initiative.  Written comments are due January 8, 2026.  Further information is available here.

Congestion Revenue Rights Enhancements

CAISO has published the issue paper and straw proposal for the Congestion Revenue Rights Enhancements initiative.  CAISO will host a virtual stakeholder meeting for this initiative on January 21, 2026 to discuss this paper and give stakeholders an opportunity to ask questions.  Written comments in response to questions identified throughout the issue paper are due February 4, 2026.  Further information is available here.

PJM INTERCONNECTION (PJM)

FERC Directs PJM to Establish Co-Location Rules

FERC issued an order on December 18, 2025, that found PJM’s tariff to be unjust and unreasonable for lacking clear and consistent provisions addressing rates, terms, and conditions of services for generators serving co‑located load and eligible customers taking transmission service on behalf of co-located load. FERC also noted that PJM’s tariff did not include types of transmission service that reflect eligible customers taking service on behalf of co-located loads that are willing and able to limit use of the transmission system under certain conditions.

FERC directed PJM to revise its tariff to set forth the terms and conditions an interconnection customer in PJM seeking to serve co-located load must follow in order to effectuate a co-location agreement. FERC also ordered PJM to require eligible customers taking transmission service on behalf of co-located load to take one of three transmission service options: an interim non‑firm service, a Firm Contract Demand service, or a Non‑Firm Contract Demand service. PJM must submit its compliance filing within 60 days of the order.

PJM 2027/2028 Base Residual Auction

PJM released the results of its 2027/2028 Base Residual Auction, noting it secured 134,479 MW of unforced capacity generation (UCAP) and demand response, and regions under the fixed resource requirement acquired an additional 11,299 MW in UCAP, for a total of 145,777 MW available to serve forecasted peak demand. The price for the auction was at the FERC-approved cap of $333.44 per MW-day.

SOUTHWEST POWER POOL (SPP)

Markets+ Stakeholders Approve Day-Ahead Protocols

SPP Markets+ Stakeholders voted to approve Markets+ protocols. The Interim Markets+ Independent Panel will review and consider the protocols on January 6, 2026.

FERC Dismisses Complaint About SPP Accreditation

FERC dismissed a complaint made by the Sierra Club, Natural Resources Defense Council, and Sustainable FERC project on April 1, 2024, which had argued that SPP’s accreditation methodologies for thermal and renewable resources were unjust and unreasonable. The Commission held that its previous ruling from July 18, 2025, which found that SPP’s newly proposed accreditation methodologies were just and reasonable, rendered the complaint moot.

ISO NEW ENGLAND (ISO-NE)

ISO-NE Statement on U.S. Department of Interior (DOI) Pausing Offshore Wind Leases

The DOI paused the leases for all large-scale offshore wind projects under construction in the United States, citing “national security risks.” As a result, DOI paused leases for five offshore wind projects.

In response, ISO-NE issued a statement regarding two of the projects, which are located in New England: Revolution Wind and Vineyard Wind 1. ISO-NE noted that both projects “have committed to helping meet New England’s demand for electricity” and canceling or delaying these projects would increase costs, risk reliability to the region, and adversely affect New England’s economy and industrial growth, including potential data center development.

Updated Wholesale Market Plan

ISO-NE published its winter update to its Wholesale Market Project Plan, which lists the status of 13 market-related projects. The Wholesale Market Project Plan acts as a companion to ISO-NE’s Annual Work Plan, published in the spring and fall.

Electric Storage Facility (ESF) Trainings

ISO-NE published self-paced training on ESF state of charge and round-trip efficiency to explain the parameters for bidding or offering ESFs into the day-ahead energy market.

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[1] Per the CPUC’s Rules of Practice and Procedure Rule 14.3, comments on proposed decisions are due 20 days after issuance of the proposed decision, and reply comments are due five days thereafter.  Comments on draft resolutions are due 20 days after the draft resolution appears in the CPUC’s daily calendar, per Rule 14.5.