October 14, 2026

Regulatory Update for October 14, 2026

(Covering October 7, 2026 - October 13, 2026)

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

Federal Regulatory Agencies

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

Click here to download this update as a PDF

State Regulatory Agencies

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

Proposed Decisions and Resolutions

Application (A.) 25-02-013 (Application of Pacific Gas and Electric Company for Compliance Review of Utility Owned Generation Operations, Portfolio Allocation Balancing Account Entries, Energy Resource Recovery Account Entries, Contract Administration, Economic Dispatch of Electric Resources, Utility Owned Generation Fuel Procurement, and Other Activities for the Record Period January 1 Through December 31, 2024)

In this proceeding, the California Public Utilities Commission (Commission) evaluated whether Pacific Gas and Electric Company (PG&E) met the standard for compliance under the Energy Resources Recovery Account regulatory compliance process for the 2024 Record Year. The decision approves an all-party settlement agreement between PG&E, the Public Advocates, and California Community Choice Association, resolving all contested issues scoped into this proceeding. In doing that, the decision also finds that PG&E has acted as a reasonable and prudent manager in compliance with applicable tariffs and Commission directives and thus approves PG&E’s 2024 Energy Resources Recovery Account Compliance application.

Voting Meeting

The CPUC held a voting meeting on October 8, 2026 in Sacramento, California, at 11:00 a.m. PT. The energy-related results are below:

Item 2. Resolution E-5455

This resolution approves PG&E Advice Letter (AL) 7785-E, filed on December 18, 2025, requesting Commission approval of an exceptional case agreement between PG&E and Google LLC to support the energization of a new 250-megawatt (MW) transmission-level retail electric load at 230 kilovolts in San Jose, California. The resolution approves the AL with modifications, requiring additional ratepayer protections. Held to October 29.

Item 4. Rulemaking (R.) 15-05-006 (Order Instituting Rulemaking to Develop and Adopt Fire-Threat Maps and Fire-Safety Regulations)

This decision partially grants a petition for modification of Decision (D.) 17-12-024, filed by Southern California Edison Company (SCE), for modifications to the boundaries of the High Fire-Threat District in its service territory. SCE’s proposed addition of 47 areas to the High Fire-Threat District is approved while removal of 61 areas from the High Fire-Threat District is denied. The Commission’s Safety Policy Division is directed to hold a workshop in 2027 on future proposed modifications to the Commission’s High Fire-Threat District Map. Some incremental costs may result from implementation of the Commission’s fire-safety regulations; cost recovery for any such costs is consistent with D.17-12-024. Signed, D.26-10-003.

Item 6. Resolution G-3622

This resolution approves in part and modifies in part the California Energy Commission’s (CEC) ALs 12-G and 10-G-A, filed on August 8, 2025 and October 3, 2025, respectively. These ALs contain proposed Gas Research, Development, and Demonstration (RD&D) Investment Plans (Gas RD&D Plans or Plans) for Fiscal Years 2024–2025 (the 2024 Plan) and 2025–2026 (the 2025 Plan). This resolution approves, in part, the CEC’s Gas RD&D Plans with proposed budgets of $24 million each for its 2024 Plan and its 2025 Plan, totaling $48 million. This resolution reviews the CEC’s 2024 Plan and 2025 Plan against a list of consolidated requirements from prior decisions and resolutions. This resolution finds that CEC Plan omissions can be remedied with additional information and directs the CEC to submit its revised 2024 and 2025 Gas RD&D Plans via Tier 2 ALs within 90 days. Held to October 29.

Item 7. Rulemaking (R.) 24-10-005 (Order Instituting Rulemaking to Consider Proposed Changes to General Order 95 to Modernize the Rules and Regulations Governing the Design and Construction of Overhead Electric and Communications Facilities in California)

General Order (GO) 95 provides rules governing the design, construction, and maintenance of overhead lines for electric and communications facilities in California. This decision (a) modifies GO 95 to adopt a new methodology based on Load and Resistance Factor Design in place of Working Stress Design, (b) revises GO 95 language accordingly, and (c) requires utilities to participate in a workshop and write a subsequent workshop report. Signed, D.26-10-004.

Item 8. Application (A.) 24-01-020, et al. (In the Matter of the Application of SFPP, L.P. for Authority to Increase Rates for Transportation of Refined Petroleum Products)

In its consolidated applications, SFPP, L.P. (SFPP) seeks to increase its existing rates and charges for intrastate transportation of refined petroleum products for the period covering 2021–2024. This decision finds that SFPP’s connected terminals are pipeline system jurisdictional assets per Public Utilities Code section 227. Because SFPP’s rate increase applications and evidence do not include the revenue and cost information associated with these jurisdictional terminal assets, this decision finds that SFPP’s applications do not comply with all applicable sections of the Public Utilities Code. Held to October 29.

Item 9. Application (A.) 25-05-009 (Application of Pacific Gas and Electric Company for Authority, Among Other Things, to Increase Rates and Charges for Electric and Gas Service Effective on January 1, 2027)

This decision sets a January 1, 2027 effective date for PG&E’s General Rate Case (GRC) revenue requirement, even if the Commission adopts the final decision authorizing the 2027 GRC revenue requirement after that date. If the Commission adopts a decision authorizing the 2027 revenue requirement after January 1, 2027, PG&E is authorized to use the GRC Gas Distribution Memorandum Account, the GRC Electric Memorandum Account, and the GRC Gas Transmission and Storage Memorandum Account to track and recover any over-collection or under-collection. Signed, D.26-10-005.

Item 11. Application (A.) 25-04-014 (Application of San Diego Gas & Electric Company to Revise its 2024–2031 Energy Efficiency Rolling Portfolio Business Plan)

This decision rejects the application of San Diego Gas & Electric Company (SDG&E) to modify its energy efficiency business plan and withdraw from administering regional energy efficiency programs, for both electric and natural gas customers, in its service area. The decision finds that the application is both premature and unsupported by the record. SDG&E is required to continue performing administrative duties to deliver its regional energy efficiency program portfolio, including its codes and standards programs. SDG&E is encouraged to modify or cancel underperforming programs and/or rebalance its regional portfolio budget in order to continue to improve the performance of its energy efficiency portfolio overall. Signed, D.26-10-006.

Item 13. Application (A.) 25-04-020 (Application of Southern California Gas Company to Recover Costs Recorded in the Transmission Integrity Management Program Balancing Account from January 1, 2019 to December 31, 2023)

This decision grants Southern California Gas Company’s (SoCalGas) request for cost recovery in the amount of $81.3048 million as part of its Transmission Integrity Management Program Balancing Account. The Commission disallows $92.4952 million from the original requested amount. Held to October 29.

Item 14. Application (A.) 25-05-004 (Application of Southern California Gas Company for Incremental Funding for Customer Information System Replacement Program)

This decision denies SoCalGas’s request for incremental funding to implement its Customer Information System Replacement Program (CIS Replacement Program). The Commission finds that parties to this proceeding have provided evidence that the costs of SoCalGas’s CIS Replacement Program are not likely to exceed the authorized amount the utility has been approved to seek ratepayer recovery for, as provided by the Commission in D.24-12-074. Signed, D.26-10-008.

Item 15. Resolution E-5483

This resolution approves PG&E’s AL 7860-E, the Diablo Canyon Extended Operations Balancing Account (DCEOBA) True-Up AL, filed pursuant to Senate Bill 846 and D.23-12-036, and denies the protest filed by The Utility Reform Network (TURN). PG&E’s AL 7860-E trues-up PG&E’s recorded Diablo Canyon Power Plant extended operations costs and market revenues to the Commission-adopted forecast for the record period September 1, 2023 through December 31, 2025. This resolution finds that PG&E’s recorded DCEOBA costs, totaling approximately $1,224.1 million, are below 115 percent of the approximately $1,325.4 million forecast approved in D.24-12-033, so that no further reasonableness review of those costs is required under Public Utilities Code section 712.8(h)(1). This resolution also finds that TURN’s proposal to apply the 115 percent threshold separately to each individual cost category, rather than to PG&E’s total recorded costs, is not supported by the statute. Approved.

Item 18. Rulemaking (R.) 19-03-009 (Order Instituting Rulemaking to Implement Senate Bill 237 Related to Direct Access)

This decision denies Alliance for Retail Energy Markets, California Coalition of Large Energy Users, Direct Access Customer Coalition, Regents of the University of California, Shell Energy North America (U.S.), L.P., and Western Power Trading Forum’s petition for modification of D.21-06-033. According to the decision, the petition fails to satisfy the requirements of Rule 16.4(b) and 16.4(d) of the Commission’s Rules of Practice and Procedure. Signed, D.26-10-011.

Item 20. Resolution E-5476

The Avoided Cost Calculator (ACC) is used in cost-effectiveness analysis of Distributed Energy Resource programs and policies. This resolution provides a link to the final 2026 ACC and related documentation and data files, consistent with policies adopted in D.16-06-007, D.19-05-019, D.22-05-002, D.24-07-015, D.24-08-007, and D.25-11-005. The documentation provides additional details about this update, including a comparison of the 2024 and 2026 ACC outputs. This resolution describes the data and major modeling updates to the 2026 ACC. Approved.

Item 24. Resolution E-5469

This resolution approves PG&E’s contract amendment to the Bioenergy Renewable Auction Mechanism Program power purchase agreement (PPA) with Burney Forest Products to extend the term of the PPA from October 31, 2027 to October 31, 2032. Approved.

Item 47.  Application (A.) 25-06-017 (Application of Liberty Utilities (CalPeco Electric) LLC (Liberty) for Authority to Recover Costs Related to the 2020 Mountain View Fire Recorded in the Wildfire Memorandum Account)

This decision authorizes Liberty to recover approximately $58.05 million in costs related to the 2020 Mountain View Fire recorded in Liberty’s Wildfire Expense Memorandum Account, plus up to an additional $3.375 million in additional financing costs related to the five-year recovery period, along with 75 percent of the five unresolved claims. Liberty shall use a Tier 2 AL process for approval of the Wildfire Expense Memorandum Account costs related to the unresolved Mountain View Fire claims paid after January 23, 2026. A five-year amortization period will be used by Liberty to recover the authorized Wildfire Expense Memorandum Account costs through a volumetric surcharge on customer bills. Held to October 29.

Item 48. Rulemaking (R.) 22-12-011 (Order Instituting Rulemaking to Address Biomethane Procurement Cost Allocation)

This decision finds that all investor-owned gas utility customers should pay a share of the above-market costs of the Renewable Gas Standard (RGS) program. However, the allocation of costs is not extended to non-core customers at this time, pending further assessment of whether an exemption (either in whole or in part) should apply to non-core customers. An additional process on this matter is needed to identify whether and how to implement cost allocation in a way that avoids emissions leakage and encourages industry to stay in California. This decision orders the joint gas utilities to lead a workshop process and subsequently file an application that considers recommendations coming out of the workshop as to whether and how these issues should be addressed. Held to October 29.

Item 48A. Rulemaking (R.) 22-12-011 (Order Instituting Rulemaking to Address Biomethane Procurement Cost Allocation)

This Alternate Proposed Decision (APD) finds that all investor-owned gas utility customers should pay a share of the above-market costs of the RGS program and allocates costs to both core and non-core customers. The APD similarly directs the utilities to lead a workshop process and subsequently file an application. Held to October 29.

Events

Interconnection Discussion Forum

Energy Division staff will host the next Interconnection Discussion Forum (IDF) on Tuesday, November 3, 2026 from 1:00 p.m. to 4:00 p.m. PT. The IDF provides an informal venue for utilities, developers, and other stakeholders to explore a variety of issues related to interconnection practices and policies. It is generally scheduled quarterly. The November IDF meeting will focus on interconnection issues relating to community solar, under both the Wholesale Distribution Access Tariff and Electric Rule 21. Additional details are available on the Rule 21 website, here.

CALIFORNIA ENERGY COMMISSION (CEC)

2026 Integrated Energy Policy Report (IEPR) Update

The CEC has set the following preliminary schedule for the 2026 IEPR. The schedule is available on the 2026 IEPR Update page.

Task/Event Date
• Final 2026 IEPR Update Scoping Order released April 2026
• Adopt order instituting informational proceeding May 2026
• Public workshops on specific topics May–December 2026
• Release draft 2026 IEPR Update October 2026
• Release proposed 2026 IEPR Update January 2027
• Adopt 2026 IEPR Forecast January 2027
• Adopt 2026 IEPR Update February 2027

The CEC’s 2026 IEPR Update workshop schedule (which remains subject to change) is set forth below. According to the workshop schedule, all workshops will be held via Zoom and the remaining workshops through December 2026 will run as follows:

November 12, 2026: Commissioner Workshop on Load Modifier Draft Results, 10:00 a.m. – 5:00 p.m. PT.

December 14, 2026: Commissioner Workshop on Overall Forecast Results, 10:00 a.m. – 5:00 p.m. PT.

CEC Announces Release of $28 Million in EV Fast Charger Incentives

On October 7, 2026, the CEC announced, in partnership with the California Electric Vehicle Infrastructure Project (CALeVIP), that it is opening a new application window through January 14, 2027 for the release of $28 million in incentives for direct-current fast chargers, with awards of up to $100,000 per charging port. 

Eligible projects must be ready to build, including having an issued permit and final utility service design. Priority will be given to projects located in disadvantaged, low-income, and tribal communities. Additional information is available on the CALeVIP website, available here.

Interoperability Workshop

The CEC will host a remote-access workshop on November 4, 2026 from 9:00 a.m. to 1:00 p.m. PT to solicit stakeholder feedback on advancing energy interoperability standards in California. The workshop will focus on alignment among communication protocols and standards, including OpenADR 3.1, Matter, IEEE 2030.5, ISO 15118, Open Charge Point Interface, and Open Charge Point Protocol, to support scalable, privacy-preserving automation and consumer-authorized control. The CEC seeks input from stakeholders including original equipment manufacturers, utilities, aggregators, Distributed Energy Resources (DER) providers, consumer advocates, and other interested parties regarding interoperability for the Market Informed Demand Automation Server, Demand Side Grid Support, load flexibility, electric vehicle supply equipment, and customer energy management systems. Additional workshop information, including login details, is available here.

Opt-In Certification Program: Emergency Rulemaking

The CEC has changed the date for the public workshop regarding proposed emergency regulations for the Opt-In Certification Program that will be set forth in Title 20, California Code of Regulations, sections 1875-1882, and Appendix B. The workshop will now be held via Zoom on November 2, 2026 from 1:00 p.m. to 4:00 p.m. PT. According to the revised workshop notice, the proposed changes include, among other things:

  • incorporation of the statutory presumption of net economic benefits;
  • incorporation of new statutory requirements for applicants to provide evidence of property rights to the proposed location and consultation with the fire suppression authority; and
  • clarification of the procedures for suspension and early termination of a project application, restructure local agency reimbursement, refine the community benefits agreement process, address post-certification change in project ownership or operational control, and update the Appendix B information requirements applicable to the Opt-In Certification Program.

The CEC also extended the deadline to provide written comments on the proposed emergency regulations. Comments are now due to the Docket Unit by 5:00 p.m. PT on November 10, 2026.

Wave and Tidal Energy

The CEC released the Draft Senate Bill 605 Wave and Tidal Energy Report to the Governor and Legislature and held a remote-access workshop on September 30, 2026 to present and gather feedback on the draft report. The meeting schedule for the workshop is available here. Written comments on the draft report are due to the Docket Unit by 5:00 p.m. PT on November 3, 2026.

CEC Business Meetings

The next CEC business meeting is scheduled for October 19, 2026. The meeting agenda and supporting materials are available here.

MINNESOTA PUBLIC UTILITIES COMMISSION (MPUC)

At its October 14, 2026 weekly agenda meeting, the MPUC will consider: (1) approval of Minnesota Power’s 2026 Annual Capacity Revenue and Expense Rider (Docket No. E015/AA-26-195); (2) how to resolve Minnesota Power’s request to include in rate base the amount claimed as prepaid pension asset (Docket Nos. E015/GR-21-335; E015/GR-23-155); and (3) approval of Dooley’s Gas Pipeline Co. LLC’s Petition for an Interruptible Gas Service Agreement with Riverview LLP serving the Stevens Milk Plant (Docket No. G6915/M-26-298).

Additionally, on September 23, 2026, the MPUC issued a Notice of Commission Investigation regarding Investigation into Rate-Regulated Electric and Natural Gas Utility Service Affordability (Docket No. E,G999/CI-26-341). Three informational sessions are scheduled for 9:30 a.m. to 12:30 p.m. CT on October 13, 2026, November 2, 2026, and December 8, 2026. The notice is accessible here.

Federal Agencies

FEDERAL ENERGY REGULATORY COMMISSION (FERC)

October Commission Meeting

FERC noticed its October 15, 2026 Commission meeting, which will take place at 10:00 a.m. EST. FERC stated it will consider, among other things:

  • EL25-92-001 | McKenzie Electric Cooperative, Inc. v. Basin Electric Power Cooperative: This proceeding concerns a request for rehearing from McKenzie Electric Cooperative, Inc. (“McKenzie”) asking FERC to find its May 21 order denying McKenzie’s complaint to be arbitrary and capricious and not in accordance with the law given that FERC failed to conduct a reasoned analysis to determine whether Basin Electric Power Cooperative’s evasion of federal jurisdiction is compatible with the public interest, as required under section 204 of the Federal Power Act.
  • RR26-3-000 | North American Electric Reliability Corporation (NERC): This proceeding concerns NERC’s submission of its 2027 Business Plans and Budgets, the Western Interconnection Regional Advisory Board, and proposed budget amendments.
  • ER24-2045-005 | PJM Interconnection, LLC (PJM): This proceeding concerns PJM’s compliance filings with Order Nos. 2023 and 2023-A.
  • EL26-84-000, QF26-1177-001 | IGS CTS, LLC: This proceeding concerns a petition for declaratory order requesting a partial waiver of FERC regulations related to qualifying facilities given the inadvertent failure to timely file notices of self-certification.

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

CALIFORNIA INDEPENDENT SYSTEM OPERATOR (CAISO)

Stakeholder Initiatives: Upcoming Meetings and Deadlines

PG&E and CAISO Disagree Over Definition of “Large Load”

At an October 1 meeting over the CAISO’s definition of “large load,” included in the CAISO draft large loads enhancements proposal, representatives from the CAISO and PG&E disagreed over the proposed definition. CAISO’s draft proposal, intended to respond to FERC’s June 2026 show-cause order regarding large load interconnections, defines “large load” as “an end user located at a single site interconnecting to the CAISO-controlled grid, and that has a peak of 50 MW or greater.” The CAISO contends that the proposed definition is consistent with every other ISO or RTO proposed definition for large loads. PG&E is displeased with the definition and asserts that “interconnecting to the CAISO-controlled grid” is ambiguous, given that end users do not interconnect directly to ’s facilities and are instead served by eligible customers through points of interconnection with the grid.

The CAISO’s draft large loads enhancement proposal further includes sections regarding the large load application process, operational requirements, and large load service agreements. As for cost shifting among transmission customers, the proposal emphasizes improved transparency about the assignment of network upgrades and their associated costs, which will provide important information to state public utility commissions to identify which transmission costs are caused by which transmission customers and appropriately suballocate those costs at the retail level. As such, pro forma agreements would ensure that eligible customers bear the risk and are ultimately responsible for the costs incurred to provide transmission service, including the cost of network upgrades.

Large Loads Initiative Stakeholder Meeting

The second hybrid stakeholder meeting will be held on October 19, 2026. However, registration for the in-person meeting is now closed. Online meeting details can be found here.

Registration for Joint Market Seams Workshop

The fourth market seams workshop jointly held by the CAISO and Southwest Power Pool (SPP) is scheduled for October 22, 2026, from 9 a.m. to 2:30 p.m. MDT. The workshop will focus on the Western leading relief process and Enhanced Curtailment Calculator. Interested parties may register for the meeting here.

Draft 2027–2029 Infrastructure Policy Roadmap

The CAISO published the 2027–2029 Infrastructure Policy Roadmap for the 2026 Infrastructure Catalog and Roadmap process on October 8. The draft summarizes the infrastructure policy initiatives and associated schedules planned for the next three years. A public stakeholder meeting will be held on October 15 to review the draft roadmap and to discuss planned infrastructure policy initiatives. The related materials and meeting information can be found here.

PJM INTERCONNECTION LLC (PJM)

FERC Rejects Interim Resource Adequacy Service (IRAS) Framework

FERC rejected, among other things, PJM’s proposed tariff revisions for its new IRAS framework. Under IRAS, load-serving entities seeking to use Network Integration Transmission Service to serve new large loads would have to designate sufficient new capacity resources to serve the new large loads. FERC noted that PJM’s proposal is intended to address the capacity shortfall that, absent the entrance of new capacity resources, would prevent PJM from satisfying the PJM Region Reliability Requirement starting in the 2027/2028 Delivery Year. But FERC rejected the IRAS proposal and PJM’s Bring Your Own New Capacity arrangements, finding that these proposals are either outside of the Commission’s authority or have not been sufficiently demonstrated to be just and reasonable and not unduly discriminatory or preferential.

NEW YORK INDEPENDENT SYSTEM OPERATOR (NYISO)

Reliability Needs Assessment (RNA)

NYISO published a draft of its 2026 RNA, which evaluates the reliability of the New York bulk electric grid through 2036, considering forecasts of peak power demand, planned upgrades to the transmission system, and changes to the generation mix over the next ten years.

The RNA identifies three Reliability Needs: a statewide resource deficiency beginning in 2033, a transmission-constrained deficiency in New York City beginning in 2032, and a related need in the Lower Hudson Valley also beginning in 2032. NYISO states the findings indicate that maintaining a reliable grid will require at least 1,850 MW of new generation resources appropriately coupled with transmission capability, and that in-state transmission alone will not resolve the statewide need.

--------------------

[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.

Media Contact

Jamie Moss (newsPRos)
Media Relations
w. 201.493.1027 c. 201.788.0142
Email

Practice Areas

Industries

Chapters

Jump to Page