March 25, 2026

Regulatory Update for March 25, 2026

(Covering March 18, 2026 - March 24, 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)

Federal Regulatory Agencies

• Federal Energy Regulatory Commission (FERC)

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

• California Independent System Operator (CAISO)
• Midcontinent Independent System Operator (MISO)
• Southwest Power Pool (SPP)

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.) 24-03-019 (Application of Southern California Edison Company (U338E) to Establish Marginal Costs, Allocate Revenues, and Design Rates)

This decision addresses Southern California Edison Company’s 2024 General Rate Case Phase 2 proceeding.  The decision approves nine settlement agreements: (1) the Marginal Cost and Revenue Allocation Settlement Agreement, (2) the Amended Streetlight and Traffic Control Rate Group Settlement Agreement, (3) the Small Commercial Rate Design Settlement Agreement, (4) the Master Meter Rate Design Settlement Agreement, (5) the Residential Rate Design Settlement Agreement, (6) the Agricultural and Pumping Rate Group Design Settlement Agreement, (7) the Large Power Rate Group Rate Design Settlement Agreement, (8) the Economic Development Rate Settlement Agreement, and (9) the Electric Vehicle Rate Design Settlement Agreement. However, this decision denies approval of the Vehicle to Grid Rate Proposal Settlement Agreement and approves Southern California Edison Company’s uncontested proposals.  This decision does not adopt Southern California Edison Company’s PRIME Plus proposal, The Utility Reform Network’s proposal to increase the baseline allowance, or Solar Energy Industries Association’s proposal regarding transmission marginal costs.

A.24-12-011 (In The Matter of the Application of Southern California Gas Company (U 904 G) for Authorization to Implement Revenue Requirement for Costs to Enable Commencement of Phase 2 Activities for Angeles Link

This decision denies the application of Southern California Gas Company (SoCalGas) requesting $266 million of cost recovery from natural gas ratepayers for Phase 2 Activities related to the Angeles Link Hydrogen Project. The Commission concluded that SoCalGas could not recover costs related to a project that is not used and useful or has demonstrated direct benefits to natural gas ratepayers as end users, as required by Decision (D.) 22-12-055.

Voting Meeting

The CPUC held a voting meeting in Sacramento, California, on Thursday, March 19, 2026, at 11:00 a.m. PT.  The energy-related results from the agenda are below:

Item 2. Resolution (Res) G-3617

This Resolution addresses Southwest Gas Corporation Advice Letter (AL) 1338-G, filed on July 29, 2025, which requests Commission approval of one biomethane procurement contract pursuant to the Renewable Gas Standard, as established in D.22-02-025.  Approved.

Item 5. A.24-05-008 (Application of Pacific Gas and Electric Company (PG&E) to Submit Its 2024 Risk Assessment and Mitigation Phase (RAMP) Report)

This decision closes PG&E’s 2024 RAMP proceeding, the initial phase of PG&E’s 2027 Test Year General Rate Case (GRC), A.25-05-009, filed on May 15, 2025.  PG&E’s RAMP Report, filed with its application in this proceeding, contains PG&E’s detailed assessment of its top safety risks, risk mitigation programs and projects and the associated expenditures to address those risks for the 2027 to 2030 GRC period.  According to the Proposed Decision (PD), PG&E’s RAMP Report employs a new cost-benefit approach that permits a more logically sound “apples-to-apples” comparison of mitigation options than the now-superseded risk-spend efficiency approach used in previous RAMP applications.  Signed, D.26-03-010.

Item 6. A.25-06-012 (In the Matter of the Application of Southern California Gas Company (SoCalGas) Regarding Year 31 (2024–2025) of Its Gas Cost Incentive Mechanism)

This decision approves SoCalGas’s request for a shareholder reward of $8,374,056 for Year 31 (2024–2025) of the company’s Gas Cost Incentive Mechanism performance.  The Public Advocates Office at the Commission verified that SoCalGas’s recorded procurement annual actual costs were $42,142,370 below the benchmark, which results in a reward of $8,374,056 to SoCalGas’s shareholders and a ratepayer savings benefit of $33,768,315 in lower gas costs.  Signed, D.26-03-011.

Item 8. A.25-02-001 (In the Matter of the Application of Shell California Pipeline Company LLC (Shell California) for Authority to Withdraw Its Pipeline from Public Utility Service)

This decision approves Shell California’s Application to withdraw the Carson, California to the Los Angeles International Airport and the Carson to Van Nuys, California petroleum pipelines from common carrier service and terminate its status as a public utility upon fulfilling specific conditions.  Signed, D.26-03-012. 

Item 9. Rulemaking (R.) 25-07-013 (Order Instituting Rulemaking to Improve the California Climate Credit)

This decision orders the large electric investor-owned utilities to pause the distribution of the 2026 electric residential Climate Credit so that a forthcoming decision can direct when in 2026 these credits should be distributed.  The residential electric Climate Credit is provided on customer bills in April and October, which on average statewide are relatively low-billed months. The current phase of this proceeding is considering moving the 2026 residential electric Climate Credit to high-billed summer months to maximize its affordability impact. A proposed decision addressing that matter is anticipated in March 2026. Pausing the spring Climate Credit will allow the Commission to include it in these considerations.  Signed, D.26-03-013.

Item 12. Res E-5411

This Resolution addresses San Diego Gas & Electric Company’s (SDG&E) request for review of CPUC staff’s denial of SDG&E AL 4475-E, through which SDG&E sought to open a memorandum account to track actual incremental administrative and/or procurement costs during a mass involuntary return of customers to Provider of Last Resort service.  While the Commission declines to review CPUC staff’s denial of SDG&E’s request to immediately open a memorandum account, the Resolution clarifies that the AL to be submitted in the event of an involuntary return shall be classified as Tier 1.  Approved.

Item 13. Res E-5452

This Resolution approves, with modifications, the request from Southern California Edison Company (SCE) to establish a new vehicle-grid integration (VGI) program within its existing Low Carbon Fuel Standard (LCFS) Implementation Plan.  On April 29, 2025, SCE filed AL 5536-E, requesting to (1) include a new VGI program in SCE’s existing LCFS Implementation Plan, and (2) exempt the requirements of Public Utilities Code Section 851 as it applies to the LCFS holdback credit sales.  The VGI proposal consists of two major components.  First, the proposal presents the Orchestrated Charging and Advanced Resiliency for Distribution (ORCHARD), which would integrate a software layer into SCE’s Distributed Energy Resource Management System that would optimize customer electric vehicle (EV) charging times.  ORCHARD would offer each participant an annually declining incentive, starting at $50 for the customer’s first year of enrollment and fully withholding the incentives by the customer’s fifth year of enrollment.  Second, the proposal would offer rebates to some participants to cover the costs associated with installing bidirectional charging equipment.  Approved.

Item 15. Res E-5440

This Resolution adopts, with modifications, the proposals of PG&E, SCE, and SDG&E (the IOUS) to establish Integration Capacity Analysis (ICA) remediation plans and baseline reporting pursuant to D.24-10-030.  ALs PG&E 7686-E, SCE 5614-E, and SDG&E 4710-E contain separate proposals from each IOU on remediation plans and baseline reporting for their respective ICAs.  Further, the Resolution establishes requirements for tracking and reporting issues with ICA that have been identified by the IOUs, parties, and prior orders of the Commission.  The progress of the ICA remediation plans and all additional reporting are ordered to be included in the Biannual ICA Reports and Quarterly ICA Workshops also established under D.24-10-03. Held to April 9, 2026.

Item 17. A.25-06-007 (Application of SCE to issue, sell, and deliver one or more series of debt securities and guarantee the obligations of others in respect of the issuance of debt securities, the total aggregate principal amount of such indebtedness and guarantees not to exceed $10,125,000,000 and to execute and deliver one or more indentures; to sell, lease, assign, mortgage, or otherwise dispose of or encumber utility property; to issue, sell and deliver in one or more series, an aggregate amount not to exceed $1,405,000,000 par or stated value of preferred equity, and guarantee the obligations of others in respect of the issuance of that preferred equity)

This decision grants SCE authority pursuant to California Public Utilities Code §§ 816, 817, 818, 821, 823, 830, and 851 to, among other things, issue debt securities secured by utility property and accounts receivable not to exceed $9,850,000,000 and preferred equity not exceeding $1,155,000,000; use debt enhancements, caps, collars, swaps, and hedges to lower cost of debt securities; guarantee obligations of regulated affiliates and governmental entities; renew and/or refund commercial paper and other floating or variable rate debt securities; and arrange credit agreements or other credit facilities for the purpose of issuing debt.  Signed, D.26-03-015.

Item 19. A.24-09-010 (Application of Liberty Utilities (CalPeco Electric) LLC (Liberty) for Authority to Among Other Things, Increase Its Authorized Revenues for Electric Service, Establish Marginal Costs, Allocate Revenues, and Design Rates, as of January 1, 2025)

This decision adopts and modifies an uncontested multi-party Settlement Agreement regarding revenue requirements issues and addresses Liberty’s Test Year 2025 GRC to increase its authorized revenues, allocate revenues and design rates.  This decision authorizes Liberty’s revenue requirement of $231,938,000, representing an 11.4% increase over the currently authorized revenue requirement of $208,147,000.  Signed, D.26-03-017.

Item 20. A.24-06-001 (Application of SDG&E for Approval of: (i) Contract Administration, Least-Cost Dispatch and Power Procurement Activities in 2023, (ii) Costs Related to Those Activities Recorded to the ERRA, Portfolio Allocation Balancing Account, Power Charge Indifference Adjustment Undercollection Balancing Account, Transition Cost Balancing Account, Local Generating Balancing Account, and Modified Cost Allocation Mechanism Balancing Account in 2023, and (iii) Costs Recorded in Related Regulatory Accounts in 2023)

This decision grants, with the modifications, the application of SDG&E for approval of its ERRA Compliance for Record Period 2023.  SDG&E, in discussion with the intervenors to this application, agreed to update its valuation of its Resource Adequacy portfolio, to correct its accounting of its Renewables Portfolio Standard compliance position, and to allocate the revenue from certain battery energy storage systems to a broader set of customers.  This decision adopts those proposed changes.  This decision finds that SDG&E’s prudently managed activities resulted in a recording of the net undercollection of $214.580 million (though this number excludes the amounts in two accounts whose balances are confidential).  Finally, this decision authorizes SDG&E to recover the stranded costs from its Green Tariff Shared Renewables programs from all ratepayers via the Public Purpose Programs charge. Held to April 9, 2026.

Item 21. R.20-05-012 (Order Instituting Rulemaking Regarding Policies, Procedures and Rules for the Self-Generation Incentive Program and Related Issues)

This decision denies the Petition for Modification of D.21-06-005 filed by ENGIE North America, Inc.  The petition requested that wastewater treatment plants be exempted from a Self-Generation Incentive Program requirement that on-site renewable biogas used in internal combustion engine projects contain at least 96% methane.  Signed, D.26-03-018.

Item 22. A.09-09-022 (In the Matter of the Application of SCE for a Certificate of Public Convenience and Necessity for the Alberhill System Project)

This decision grants SCE’s request for a certificate of public convenience and necessity to construct the proposed Alberhill System Project subject to the Mitigation Monitoring, Compliance and Reporting Plan.  Signed, D.26-03-019.

Item 24. Res E-5443

This Resolution approves PG&E’s relocation agreement with Meritage Homes to accommodate the Machado Ranch Project, which requests approval under Electric Rule 15.I.3 of an Actual Cost Contract (ACC) and Assignment and Consent of the ACC from Signature Homes, Inc. to Meritage Homes for the Machado Ranch development project in the City of Manteca, San Joaquin County, California.  Approved.

Item 25. A.25-01-003 (In the Matter of the Application of Crimson California Pipeline L.P. for Authority to Withdraw a Segment of Its Seal Beach Pipeline from Public Utility Service)

This decision approves Crimson California Pipeline L.P. to withdraw the southern segment of the Seal Beach Pipeline from public utility service, pursuant to California Public Utilities Code section 851.  Signed, D.26-03-020. 

Item 52. A.24-04-017 (Application of LS Power Grid California, LLC (LS Power) for a Certificate of Public Convenience and Necessity Authorizing Construction of the Power Santa Clara Valley Project)

This decision grants LS Power’s request for a certificate of public convenience and necessity authorizing the construction of the Power Santa Clara Valley Project, configured as Alternative Combination 1 and subject to the mitigation measures identified in the Mitigation Monitoring, Compliance, and Reporting Program.  This decision also certifies that the Final Environmental Impact Report for this project meets the requirements of the California Environmental Quality Act (CEQA), and that the benefits of the Power Santa Clara Valley Project outweigh and override the significant and unavoidable impacts for the reasons stated in Appendix A of the PD.  Finally, this decision establishes a maximum cost cap of $1,592,760,000 and grants LS Power exemptions from certain Commission affiliate transaction rules and reporting requirements.  Signed, D.26-03-042.

Item 53. A.24-05-014 (Application of LS Power for a Certificate of Public Convenience and Necessity Authorizing Construction of the Power the South Bay Project)

This decision grants LS Power’s request for a certificate of public convenience and necessity authorizing the construction of the Power the South Bay Project, as proposed and subject to the mitigation measures identified in the Mitigation Monitoring, Compliance, and Reporting Program.  This decision also certifies that the Environmental Impact Report prepared for this project meets the requirements of CEQA and adopts the CEQA Findings and Statement of Overriding Considerations contained in Attachment A of the PD.  Further, this decision finds that the ability of the proposed project to improve system reliability and address system overload in the San Jose, California area outweighs its significant and unavoidable impacts on air quality.  Finally, this decision grants LS Power exemptions from certain Commission affiliate transaction rules and reporting requirements.  Signed, D.26-03-043.

Item 54. Res E-5447

This Resolution approves PG&E AL 7653-E.  PG&E requests Commission approval of a non-standard Engineering, Procurement and Construction (EPC) Agreement with STACK Infrastructure, Inc. (STACK) under the exceptional case provisions of Electric Rules 15 and 16.  The EPC Agreement is part of the contractual framework supporting the energization of STACK’s new 90 megawatt (MW) data center load in San Jose, California and governs STACK’s construction of the Ringwood Switching Station and the subsequent transfer of that facility to PG&E.  The scope of AL 7653-E is limited to approval of the EPC Agreement for the customer-built Ringwood Switching Station.  AL 7653-E does not cover cost estimates, cost allocation and responsibility, or refunds to STACK.  Those issues were addressed in PG&E’s prior AL 7569-E and were approved with modification in Res E-5420, adopted by the Commission on October 30, 2025.  The Commission already approved the underlying energization project in Res E-5420 and adopted a modified refund framework to protect ratepayers. Approved. 

Item 55. Res E-5433

This Resolution approves, with modifications, PG&E AL 7667-E, which requests Commission approval of an agreement to support the energization of a new 49 MW data center and computing lab load in Sunnyvale, California, as requested by Sunnyvale Technology Partners LLC c/o Menlo Equities (Menlo Equities).  According to the Resolution, this agreement facilitates the construction of new transmission facilities to serve Menlo Equities’ load.  The Commission approves the AL with modifications, finding the agreement necessary and largely appropriate to energize this new load. Approved.

Court of Appeal Upholds Net Energy Metering (NEM) Successor Tariff

On March 9, 2026, the California Court of Appeal upheld the CPUC’s Net Billing Tariff, adopted in 2022 as a successor NEM 2.0 tariff, finding that the CPUC acted within its authority.  More information on this decision may be found in our blogpost here.

CALIFORNIA ENERGY COMMISSION (CEC)

2026 Integrated Energy Policy Report (IEPR) Update

The CEC is seeking comments on the Draft Scoping Order for the 2026 IEPR Update.  According to the Notice, the 2026 IEPR Update will include an updated 15-year electricity demand forecast, an assessment of the challenges and opportunities for geothermal development in California, and a discussion of progress toward energy equity and environmental justice.  Written comments on the Draft Scoping Order are due to the Docket Unit under Docket No. 26-IEPR-01 by 5:00 p.m. PT on March 25, 2026.  The Notice also includes a proposed 2026 IEPR Update schedule, which will be available on the 2026 IEPR Update page and subject to regular updates.  The initial proposed schedule is as follows:

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 initial 2026 IEPR Update workshop schedule is now available (and remains subject to change).  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, 2pm – 4pm

June 19, 2026: Commissioner Workshop on Geothermal Energy (Part 1), 10am – 5pm

June 30, 2026: Commissioner Workshop on Energy Equity & Environmental Justice, 1pm – 5pm

July 9, 2026: Commissioner Workshop on Geothermal Energy (Part 2), 1pm – 5pm

August 5, 2026: Commissioner Workshop on Forecast Inputs and Assumptions, 10am – 5pm

August 31, 2026: Commissioner Workshop on Load Modifier Inputs and Assumptions, 9am – 4:30pm

November 12, 2026: Commissioner Workshop on Load Modifier Draft Results, 10am – 5pm

December 16, 2026: Commissioner Workshop on Overall Forecast Results, 10am – 5pm

Staff Workshop on Fusion Research and Development Innovation Initiative

The CEC will host a remote-access staff workshop on April 2, 2026, from 9:00 am to 11:30 am PT to discuss implementation of its new Fusion Research and Development Innovation Initiative, created pursuant to SB 80 (Caballero, 2025).  The purpose of the initiative is to accelerate the development and growth of fusion energy by advancing fusion science and technology.  The staff workshop will facilitate a discussion on fusion energy research needs and barriers and identify opportunities that could be supported by grant funding under the Fusion Research and Development Innovation Initiative.  Documents for the workshop, including an agenda and access details, will be available here.  Written comments may be submitted to the docket 26-ERDD-01 by April 16, 2026.

Staff Workshop on Offshore Wind Port Development Program

The CEC hosted a remote workshop on March 17, 2026, to present an overview of the Proposition 4 Offshore Wind Port Development Program, including a summary of related statutes, the processes the CEC will follow, and preliminary considerations for developing a future grant solicitation.  The workshop agenda is available here.  Written comments are due to the Docket Unit by 5:00 p.m. PT on May 22, 2026.

Workshops on EV Charger Reliability Reporting and on Interoperability Standards

Workshop on Roaming and Interoperability

The CEC will host a remote workshop on March 25, 2026, from 10:00 a.m. to 12:30 p.m. PT to present and discuss concepts related to standardizing communications for Plug & Charge and the EV charging experience.  The goal is to gather industry inputs as the CEC considers options for establishing minimum standards that enhance the reliability and driver experience across California’s public EV charging infrastructure.  Presentations and a workshop agenda and access details are available on the docket, here.  Written comments can be submitted to the CEC by 5:00 p.m. PT on April 15, 2026.

Workshop on the Regulations for Improved EV Charger Recordkeeping and Reporting, Reliability, and Data Sharing

On Thursday, March 26, 2026, from 10:00 a.m. to 12:00 p.m. PT, the CEC will host a staff workshop to explain the recently adopted Regulations for Improved EV Charger Recordkeeping and Reporting, Reliability, and Data Sharing (EV Charger Data and Reliability Standards), which will take effect on April 1, 2026.  A detailed workshop agenda and attendance details are available here.

CEC Business Meetings

The next CEC Business Meeting is scheduled for April 8, 2026.  The agenda and supporting materials will be posted here at least ten days prior to the meeting.

MINNESOTA PUBLIC UTILITIES COMMISSION (MPUC)

At its March 26, 2026, agenda meeting, the MPUC will consider (1) approval of Xcel Energy’s (Xcel) Power Purchase Agreements (PPAs) for its generator projects for MISO Expedited Resource Addition projects, authorization for the company to recover costs incurred under the PPAs through its Fuel Clause Rider, and whether to require Xcel to apply an imputed debt cost estimate to PPA projects (Docket No. E002/RP-24-67), and (2) acceptance of the certificate of need application and referral to the Court of Administrative Hearings for the PowerOn Midwest 765 kV and 345 kV High Voltage Transmission Line Project (Docket No. E002, ET2, ET6675/CN-25-117).

PACIFIC NORTHWEST (OPUC, WUTC, BPA)

Washington Utilities and Transportation Commission (WUTC)

On March 24, 2026, the WUTC held an open meeting to discuss PacifiCorp’s 2025 Clean Implementation Plan (Docket No. UE-250617), specifically to discuss whether to issue an order approving the plan subject to conditions proposed by WUTC staff. More information about the staff’s recommendation is here.  Additionally, utilities in Washington have weighed in on the WUTC’s investigation into how federal tax law changes impact clean energy projects in the state, the comment period for which closed on March 20. Utilities generally voiced concerns about limited transmission capacity and the challenge it poses as utilities work to meet state greenhouse gas targets. Local coverage is here.

The Washington legislature continues to consider a pair of bills, SB 6171 and HB 2515, that would require Emerging Large Energy Use Facilities (ELEUFs) to purchase their energy and pay for needed infrastructure through new tariffs or contracts developed by the state’s utilities.  Under the bills, starting in 2031, ELEUFs commencing operation after July 1, 2026, must certify to the state that 80% of the energy used to serve their load in the prior year came from renewable or non-emitting resources, and that they purchased the electricity and renewable energy certificates to substantiate that certification in a “single transaction.”  The laws require ELEUFs to serve their load using 100% renewable or non-emitting resources beginning in 2035.  There has been no movement on SB 6171 in the Senate.  Additionally, there have been no developments regarding HB 2515 following its return to the House Rules Committee for a third reading on March 12, 2026.

Bonneville Power Administration (BPA)

On March 18 and 19, 2026, BPA held workshops regarding its TC-27 proceeding, intended to continue discussions on the Grid Access Transformation for proposed changes to BPA’s processes for evaluating and expanding the Federal Columbia River Transmission System.  Following the workshops, BPA intends to conduct a TC-27 Terms and Conditions Tariff Proceeding to set and/or modify the terms and conditions of BPA’s Open Access Transmission Tariff specifically related to the proposed changes that are developed through the pre-proceeding workshop process. The TC-27 Tariff Proceeding webpage is here.

Federal Agencies

FEDERAL ENERGY REGULATORY COMMISSION (FERC)

March 2026 Commission Meeting

FERC held its March 2026 Commission Meeting on March 19, 2025. Among other things, FERC issued the following orders:

Reliability Standards

FERC unanimously approved two final rules on grid reliability. The first rule updates 11 Critical Infrastructure Protection standards to enable secure use of virtualization technologies. The second rule addresses strengthening baseline cybersecurity for low‑impact grid systems with new password protocols and intrusion‑detection measures. FERC also approved an updated definition of “control center” to help utilities better identify and protect high‑risk assets.

Electric Quarterly Report (EQR) Changes

FERC approved a new final rule on EQR reporting that adopts the XBRL‑CSV standard as the required format for all EQR filings. As part of the rule, FERC will now require RTOs and ISOs to produce reports containing market participant transaction data, representing an expansion of mandatory data‑reporting obligations beyond traditional EQR filers. The rule also includes modifications and clarifications to existing EQR reporting requirements, such as extending the due date for EQRs to four months after the end of a quarter.

Return on Equity (ROE) New England Transmission Owners Order

FERC issued an order addressing a D.C. Circuit remand of a previous FERC opinion on a complaint challenging the base ROE of transmission owners in New England (NETOs), as well as three other complaints challenging NETOs’ base ROE. The order grants the first complaint, denies the three other complaints, and requires NETOs to establish a 9.57% base ROE. 

State of the Markets Report

FERC published its 2025 State of the Markets Report. FERC, in its report, found:

• Rising natural gas and wholesale electricity prices;
• Increasing natural gas demand and higher electricity demand;
• Peak load forecasts suggest faster peak growth rate driven by large load additions;
• More electricity generation capacity additions than retirements across different resource types. Most capacity additions came from non-conventional resources, while retirements primarily came from coal and natural gas units; and
• Proposed natural gas pipeline capacity additions and certificated storage projects grew and more transmission line miles completed.

CALIFORNIA INDEPENDENT SYSTEM OPERATOR (CAISO)

Stakeholder Initiatives: Upcoming Meetings and Deadlines

Distributed Generation Deliverability Assessment Results Posted

The CAISO has posted the 2025-2026 Deliverability for Distributed Generation Study Results Report.  The eligible distributed generation facilities in grid areas, where the CAISO’s distributed generation facilities seeking an initial or increase in deliverability status must apply for deliverability status assignment as described in the report.

2025-2026 Transmission Planning Process

The CAISO will make the draft transmission plan available here by the end of the day on March 31, 2026.  Additionally, the CAISO will host a hybrid public stakeholder meeting for transmission planning process to discuss the draft.  The stakeholder meeting will take place on April 7, 2026.  Meeting registration details can be found here.      

Draft Flexible Capacity Needs Assessment 2027

The CAISO will hold a public stakeholder call on April 2, 2026, to discuss the 2027-2029 draft Flexible Capacity Needs Assessment and the availability assessment hour requirements. More details on the call can be found here.

2027 and 2031 Local Capacity Technical Study Draft Results Call

The CAISO is conducting the local capacity technical study of the ISO tariff and will hold a stakeholder call on April 9, 2026, to present and discuss the proposed final 2027 and 2031 local capacity technical study results. The results will be posted to the 2027 local capacity requirements website. The stakeholder call details can be found here.

New Stakeholder Process: Commitment Cost Bidding Flexibility Workshop

The CAISO has scheduled a Commitment Cost Bidding Flexibility stakeholder workshop on March 26, 2026, to revising enhancements to commitment cost offer mitigation. The CAISO has committed to pursuing implementation of existing policy approved by the CAISO Board of Governors to support more bidding flexibility with a dynamic market power test for commitment offers. Meeting details can be found here.

MIDCONTINENT INDEPENDENT SYSTEM OPERATOR (MISO)

Cost Allocation Orders for Department of Energy (DOE) Coal Plant Emergency Orders

Following emergency orders from DOE to keep coal plants online in MISO under the Federal Power Act section 202(c), FERC issued a pair of orders that allocates the related coal plant costs across MISO’s Midwest region, where the coal plants are located. FERC in its order noted “the most reasonable reading of the DOE Order’s intended scope is that the emergency necessitating the continued operation” of the plants in Local Resource Zones 1-7 and that, because those zones were the beneficiaries of the plants being kept online, it was appropriate to allocate costs to those zones.

SOUTWEST POWER POOL (SPP)

Tariff Revisions for System Support Resource (SSR) Program

FERC approved SPP’s proposal to create an SSR program to serve as a backstop mechanism that temporarily keeps certain retiring generators online when their withdrawal would otherwise cause short‑term reliability risks. Under the revised tariff, SPP will use its Resource Retirement Study process to determine whether a unit is needed for system reliability and, if no viable alternatives exist, may enter into a voluntary, time‑limited SSR Agreement with the generator owner. These agreements allow SPP to dispatch the resource for reliability needs and set compensation based on going‑forward costs. FERC found the tariff revisions just and reasonable, consistent with cost‑causation principles and past precedent, and accepted SPP’s requested effective date subject to a compliance filing specifying the actual implementation date.

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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.