May 13, 2026

Regulatory Update for May 13, 2026

(Covering May 6, 2026 - May 12, 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

• California Public Utilities Commission (CPUC)
• California Energy Commission (CEC)
• Minnesota Public Utilities Commission (MPUC)
• Pacific Northwest (OPUC, WUTC, BPA)
• Florida

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)
• 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

Resolution E-5467. This Resolution approves San Diego Gas & Electric’s request for approval of a utility-owned energy storage contract procured to address 2026 and 2027 summer reliability. The contract is a Membership Interest Purchase Agreement with RWE AG subsidiary, RWE Clean Energy Asset Holdings, Inc., for the purchase of Westside Canal 2A, LLC, a 119-megawatt project and an associated 10-year Long-Term Services Agreement. This Resolution approves the requested relief in Advice Letter (AL) 4736-E.

Voting Meeting

The CPUC will hold a voting meeting in San Francisco, California, on Thursday, May 14, 2026, at 11 a.m. PT. The energy-related items on the agenda are below:

Item 5. Application 25-06-026 (In the Matter of the Application of Crimson California Pipeline L.P. for Authority to Increase Rates Application No. for Its Crude Oil Pipeline Services).

This decision approves the unopposed request by Crimson California Pipeline L.P. (Crimson) to increase the rates it charges for transportation of crude petroleum products on its Southern California Pipeline System by 10% beginning August 1, 2025. The Commission further authorizes the retroactive charge and collection of the difference between rates billed and the approved rate beginning August 1, 2025, including interest calculated at the 90-day commercial paper rate. This decision also denies Crimson’s request in its Miscellaneous Filing for an additional 3.16% rate increase beginning August 1, 2025.

Item 8. Application 22-05-022 (Application of Pacific Gas and Electric Company for Review of the Disadvantaged Communities – Green Tariff, Community Solar Green Tariff and Green Tariff Shared Renewables Programs).

This decision adopts a process to implement the customer community renewable energy tariff adopted by Decision (D.) 24-05-065. Following the United States Environmental Protection Agency’s August 2025 termination of California’s Solar for All award and the resulting current lack of available external funding, this decision supersedes D.24-05-065 regarding a nonparticipating customer-funded adder. The decision also addresses Green Tariff program oversight and cost recovery, Disadvantaged Communities-Green Tariff funding and program evaluation, and program reporting for California Shared Renewables Portfolio programs.

Item 9. Application 26-01-007 (Application of Southern California Edison Company for Woolsey Fire Recovery Bond Financing Order Pursuant to Public Utilities Code Section 850).

This Financing Order grants the request by Southern California Edison Company (SCE) for authority under Public Utilities Code Sections 850 and 850.1 to issue Recovery Bonds. This Financing Order authorizes SCE to issue Recovery Bonds to recover approximately $1.951 billion of Wildfire Expense Memorandum Account costs related to the Woolsey Fire. According to the decision, the outcomes leads to ratepayer savings of approximately $811 million compared to traditional utility financing mechanisms on a net present value basis, with the precise amount of savings depending on several factors not known at this time, such as the terms, the number and size of the tranches, and interest rates on the Recovery Bonds.

Item 17. Rulemaking 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, on procedural grounds. The petition sought to extend or remove the end date of the Bioenergy Market Adjusting Tariff and proposed other programmatic changes. According to the decision, the petition fails to meet the requirements of Rule 16.4 of the California Public Utilities Commission’s Rules of Practice and Procedure because these modifications could have and should have been sought within one year of the issuance of D.20-08-043.

Item 20. Application 24-03-018 (Application of Pacific Gas and Electric Company to Recover in Customer Rates the Costs to Support Extended Operation of Diablo Canyon Power Plant from September 1, 2023, through December 31, 2025, and for Approval of Planned Expenditure of 2025 Volumetric Performance Fees).

This decision grants, in part, the petition for modification of D.24-12-033, dated October 27, 2025, filed by the Alliance for Nuclear Responsibility. Accordingly, D.24-12-033 is modified, so that the updated final Resource Adequacy (RA) Market Price Benchmark (MPB) as opposed to forecast RA MPB is used to calculate RA substitution capacity costs when assessing whether the actual costs and expenses necessary to operate Diablo Canyon Power Plant fall within the 115% of the forecasted costs under Public Utilities Code Section 712.8h(1). This approach will apply to all annual Diablo Canyon Power Plant cost forecast proceedings through 2030, not just the 2025 revenue requirement approved in D.24-12-033.

Item 24. Application 24-08-002 (Application of PacifiCorp for Approval of its 2025 Energy Cost Adjustment Clause and Greenhouse Gas-Related Forecast and Reconciliation of Costs and Revenue).

This decision approves the November 10, 2025, Joint Motion for Approval of Written Settlement filed by PacifiCorp d/b/a Pacific Power the California Farm Bureau Federation, and the Public Advocates Office at the CPUC, requesting Commission approval and adoption of the all-party partial settlement (Settlement) regarding the remaining scoped issues in PacifiCorp’s 2025 Energy Cost Adjustment Clause. The Settlement resolves all the issues raised with respect to the application.

Item 25. Application 24-09-001 (Application of Southwest Gas Corporation for Authority to Increase Rates and Charges for Gas Service in California, Effective January 1, 2026).

This decision grants the uncontested Joint Motion to Adopt a Settlement Agreement, filed by Southwest Gas Corporation (Southwest Gas), the Public Advocates Office, and Small Business Utility Advocates. The Settlement Agreement resolves certain issues material to Southwest Gas’ application for authorization to increase rates and charges for gas service in California, effective January 1, 2026.

Item 26. Application 24-07-020 (Application of Pacific Gas and Electric Company (PG&E) for Approval of Peak Day Supply Standard Pursuant to Decision 23-11-069).

This decision approves a proposed settlement (Settlement Agreement) reached between PG&E and the solitary protestant, The Utility Reform Network (TURN), regarding PG&E’s use of a Peak Day Gas Supply Standard (PDSS) for the winter seasons in years 2024/2025 through 2026/2027. PG&E and TURN jointly seek Commission approval of their proposed Settlement Agreement, which resolves all issues in this proceeding. The decision approves the use of the proposed PDSS as set forth in the proposed Settlement Agreement and the parties Joint Motion for Approval of a Settlement Agreement for the period requested.

Upcoming Events

Rule 17 Backbilling Workshop.

The Energy Division will host a virtual workshop on May 18, 2026, at 10 a.m. to facilitate the development of an Investor-Owned Utilities and Community Choice Aggregators consensus-based proposal on how to address uncollected revenue from the application of Rule 17 backbilling limitations for both bundled and unbundled customers. An agenda and any additional materials will be distributed closer to the workshop.

Workshop for Developing a Distribution System Operator (DSO)-led DER Orchestration Framework.

On Thursday, May 21, 2026, from 10 a.m.-5 p.m., the CPUC will host a Workshop in Track 2 of the Distributed Energy Resources (DER) proceeding regarding developing a DSO-Led DER Orchestration framework.  The workshop will be held both in-person at the CPUC Auditorium and remote.  Additional details are available on the High DER proceeding docket, R.21-06-017.

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 will run from May through December 2026, as follows:

May 20, 2026: Staff Workshop on Forms & Instructions, 2 p.m.-4 p.m. PT. Written comments are due to the Docket Unit by 5 p.m. PT on June 3, 2026, and should reference Docket No. 26-IEPR-02.

June 19, 2026: Commissioner Workshop on Geothermal Energy (Part 1), 10 a.m.-5 p.m. PT

June 30, 2026: Commissioner Workshop on Energy Equity & Environmental Justice, 1 p.m.-5 p.m. PT

July 9, 2026: Commissioner Workshop on Geothermal Energy (Part 2), 10 a.m.-5 p.m. PT

August 20, 2026: Commissioner Workshop on Forecast Inputs and Assumptions, 1 p.m.-5 p.m. PT

August 31, 2026: Commissioner Workshop on Load Modifier Inputs and Assumptions, 9 a.m.-4:30 p.m. PT

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

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

Draft 2025 IEPR

On April 23, 2026, the CEC issued a Notice of Availability and Request for Comments regarding the Draft 2025 Integrated Energy Policy Report. As set forth in the July 2025 Scoping Order and as summarized in the Notice of Availability, the Draft 2025 IEPR contains in-depth discussions regarding advancing clean energy deployment; electricity and gas forecast; and provides a load-shift goal update. Written comments are due to Docket No. 25-IEPR-01 before 5 p.m. on May 15, 2026.

Resource Planning and Reliability

On May 4, 2026, the CEC hosted a workshop regarding summer energy reliability. Staff from the CEC, California ISO, CPUC, CALFIRE, Western Electricity Coordinating Council, California Department of Water Resources, among others, provided information regarding anticipated summer conditions. Written comments are due to the Docket Unit by 5 p.m. PT on May 18, 2026. 

Workshop on SB 237 Assessment

The CEC announced that it will host a workshop on May 18, 2026, to evaluate the recommendations and strategies put forward by Vice Chair Siva Gunda in the June 27, 2025 letter to California Governor Newsom regarding Senate Bill 237. A link to the Draft SB 237 Assessment, titled “Supporting the Transition Away from Petroleum Fuels,” is available here. The workshop will be remote-access only and login details are available here, along with an agenda.

Electric Program Investment Charge (EPIC)

On April 2, 2026, the CEC circulated a “Save the Date” for the CEC’s annual EPIC Symposium indicating that the event is scheduled for Tuesday, September 29, 2026, at the California Natural Resources Agency building (715 P Street) in Sacramento, California. More details will be provided when made available by the CEC.

CEC Business Meetings

The next CEC business meeting is scheduled for May 13, 2026, from 10 a.m.-3 p.m. PT. The agenda and supporting materials are available here. 

CALIFORNIA AIR RESOURCES BOARD (CARB)

Concepts for Potential Carbon Regulations

CARB posted a preliminary compilation of potential and partial regulation concepts to establish the new Carbon Capture, Removals, Utilization, and Storage (CCUS) Program through a document titled Concepts for Potential Regulations for Establishing the Carbon Capture, Removals, Utilization, and Storage Program. Under Senate Bill 905, CARB seeks public input as part of its pre-rulemaking activity for the development of the CCUS Program through an upcoming rulemaking. CARB released draft rulemaking concepts that identify potential definitions for CCUS and Carbon Dioxide Removal (CDR), as well as initial regulatory concepts for reporting, monitoring, financial responsibility, and protocols that further support CCUS and CDR inclusion in California's climate policies. CARB will accept written comments through June 5, 2026, at 11:59 PM PST.

MINNESOTA PUBLIC UTILITIES COMMISSION (MPUC)

At its May 15, 2026, weekly agenda meeting, the MPUC will consider Xcel Energy’s petition for approval of its Large General Time of Day Service Customer and Large Peak Controlled Time of Day Service Tariffs, which will involve consideration of many elements, including approval of associated rider revisions, the use of an Incremental Cost Test, a determined demand size threshold, modifications to the minimum ESA term length, and the establishment of a separate customer class for super-large customers (Docket No. 25-289). The MPUC hearing will represent the first consideration of a state utility’s large customer tariff following passage of Minn. Stat. Section 216B.1622, which directs the MPUC to define what constitutes a “very large customer” and set the characteristics of the customer class by December 15, 2026.

PACIFIC NORTHWEST (OPUC, WUTC, BPA)

Bonneville Power Administration (BPA)

On May 11, 2026, BPA held a workshop to review its Network Integration Transmission Service business practice manual (BPM), the clean version of which is here. More information about changes to its BPM is here. Additionally, on May 12, 2026, BPA’s Transmission Services held a system planning meeting to provide customers and interested parties with the opportunity to discuss and share feedback on the 2027 planning studies and development of the 2027 plans of service. More information is here.

Oregon Public Utilities Commission (OPUC)

On May 7, 2026, the OPUC approved Portland General Electric’s (PGE) data center rate framework, pursuant to House Bill 3546, which requires the OPUC to establish a separate class for data centers, cryptocurrency miners, and similar large load customers. The OPUC’s Order No. 26-154 approved several provisions of PGE’s proposed data center class, such as minimum transmission and generation demand requirements, a fixed distribution charge for customers with at least 1 MW of load, contract terms, and exit fees. The order also established a dedicated interconnection queue for data center customers and focused on shifting growth costs to large load users, while also adding safeguards for emissions compliance. A number of resolutions adopted within the order were done by stipulation, such as the agreement to open an investigation to address new load connection costs. Local coverage is here.

Washington Utilities and Transportation Commission (WUTC)

On May 14, 2026, the WUTC will hold its regular public meeting to discuss Avista Corporation’s petition for an order approving the 2027-2030 demand and resource supply forecast as directed by the Climate Commitment Act (UE-260067), and Northwest Natural Gas Company d/b/a NW Natural’s tariff revisions to Tariff WN U-6, Schedule 308 (Washington Climate Commitment Act Recovery Mechanism), which would decrease revenue by $9.2M or 8.4% (UG-260133). The full agenda is here.

FLORIDA

Florida Large Load Cost Responsibility

Florida Governor Ron DeSantis signed legislation that requires large load customers (those with a monthly peak load of 50 MW or more) to bear their own full cost of service to avoid shifting those costs onto the general body of ratepayers. The bill notes that such cost includes connection, incremental transmission, incremental generation, and other infrastructure costs; operations and maintenance expenses; and any other costs required to serve a large load customer.

The bill states that the Florida Public Service Commission may approve public utility tariffs that include industry-accepted ratemaking and other financial tools, including:

• Contributions in aid of construction or other required customer infrastructure investments that may be returned, in whole or in part, to such customers over time;
• Demand charges;
• Incremental generation charges;
• Financial guarantees;
• Minimum load factors;
• Take-or-pay provisions or provisions requiring payment for contracted capacity, regardless of a large load customers’ actual electricity use or demand; and
• Minimum period of service contract requirements, including early termination fees or other fees for violation of such contracts.

Federal Agencies

FEDERAL ENERGY REGULATORY COMMISSION (FERC)

FERC to Act on Large Load Interconnection Docket

FERC issued a statement that it will take action by June 2026 on the Advance Notice of Proposed Rulemaking (ANOPR) proceeding initiated by the U.S. Secretary of Energy. The ANOPR requested that FERC consider changes to large load interconnection, including increasing demand from data centers.

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

CALIFORNIA INDEPENDENT SYSTEM OPERATOR (CAISO)

Stakeholder Initiatives: Upcoming Meetings and Deadlines

Save the Date: Resource Interconnection Standards Fair

The CAISO will host the annual Resource Interconnection Standards Fair on Tuesday August 11, 2026. The fair will take place to provide stakeholders with the opportunity to learn more about the CAISO’s interconnection process and recent changes affecting Cluster 16, in preparation of the Cluster 16 window opening on October 1, 2026. Meeting registration details can be found here.

Extended Day-Ahead Market Congestion Revenue Allocation Phase 2

The CAISO revised the schedule for the upcoming working group meetings for Phase 2 of the Extended Day-Ahead Market Congestion Revenue Allocation initiative. The working group meetings will take place May 11, June 2, and June 24, 2026. More details about the meetings can be found here.

PJM INTERCONNECTION LLC (PJM)

Maryland Complaint Against PJM Cost Allocation Rules

The Maryland Office of People’s Counsel filed a complaint against PJM asking FERC to find that PJM’s existing cost allocation rules for baseline transmission projects are unjust and unreasonable because they impose costs on Maryland’s electric customers not commensurate with benefits received. The Office of People’s Counsel argues that over the next decade Maryland customers will pay about $1.6 billion in additional costs for transmission projects, driven primarily by the energy needs of data centers located outside of Maryland, resulting from PJM’s hybrid load-ratio share and solutions-based distribution factor transmission cost allocation methodology for assigning transmission cost responsibility across sub-regions of PJM. The Office of People’s Counsel asks for a refund effective date 60 days from filing.

ISO NEW ENGLAND (ISO-NE)   

Energy Forecast Report

ISO-NE published its annual Forecast Report of Capacity, Energy, Loads, and Transmission (CELT Report), which for the first time included behind-the-meter battery energy storage systems (BTM BESS). ISO-NE stated that although these resources are not visible to ISO-NE in its control room, the ISO keeps track of them to monitor demand. ISO-NE notes that while there is currently about 111 MW of BTM BESS, less than 1 MW in size across the ISO, ISO-NE expects about 173 MW of BTM BESS to be added over the next 10 years, mostly in Massachusetts.

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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.