October 21, 2026

Regulatory Update for October 21, 2026

(Covering October 14, 2026 - October 20, 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)
• California Air Resources Board (CARB)
• Minnesota Public Utilities Commission (MPUC)

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)
• PJM Interconnection LLC (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

Rulemaking (R.) 22-11-013 (Order Instituting Rulemaking to Consider Distributed Energy Resource Program Cost-Effectiveness Issues, Data Access and Use, and Equipment Performance Standards)

This decision establishes the guiding principles of accuracy, consistency, and transparency for the Avoided Cost Calculator used in cost-effectiveness analysis for Distributed Energy Resources (DER) policies and programs. The decision also establishes a Distributional Equity Analysis as a companion to existing cost-effectiveness evaluations for DER.

Application (A.) 18-05-007 (In the Matter of the Application of Southern California Edison Company for a Certificate of Public Convenience and Necessity: Eldorado-Lugo-Mohave Series Capacitor Project)

This decision partially grants Southern California Edison Company’s (SCE) unopposed request to modify Decision (D.) 25-10-012, increasing the maximum reasonable and prudent cost (MRPC) of its Eldorado-Lugo-Mohave Series Capacitor Project by $17 million to a total of $312 million. The $15.9 million that SCE incurred in excess of its approved MRPC without prior approval is denied.

Application (A.) 24-06-001 (Application of San Diego Gas & Electric Company for Approval of: (i) Contract Administration, Least-Cost Dispatch and Power Procurement Activities in 2023, (ii) Costs Related to those Activities Recorded to the Energy Resource Recovery Account, 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 authorizes San Diego Gas & Electric Company (SDG&E) to recover the net total of $3,022,040 in costs recorded to its Green Tariff and Shared Renewables (GTSR) balancing account from former GTSR customers and denies SDG&E’s request to recover the net total of $1,592,844 recorded to its GTSR memorandum accounts. This decision finds that Senate Bill (SB) 43 limits SDG&E from recovering GTSR-related costs from former participants in GTSR or to its own shareholders.

Application (A.) 26-02-005 (Joint Application of Pacific Gas and Electric Company, SCE, and SDG&E Requesting Commission Approval of Proposals for a BCR Calculation Methodology, Audit Methodology, and Cost Recovery Conditions as Specified in Resolution SPD-37)

This decision builds on Resolution SPD-15 and Resolution SPD-37 implementing SB 884, codified at Public Utilities Code section 8388.5. The SB 884 program is one of several regulatory pathways through which utilities may seek authorization to recover costs associated with undergrounding investments. Unlike traditional regulatory pathways, however, SB 884 establishes a voluntary, expedited framework for the review of 10-year undergrounding plans designed to substantially reduce wildfire risk, improve reliability, and achieve cost efficiencies. The program’s longer-term planning horizon is intended to facilitate economies of scale, a sustainable supply chain, and declining undergrounding costs over time, ultimately benefiting ratepayers through more efficient and cost-effective wildfire risk reduction. This decision further implements the SB 884 framework by (1) adopting a standardized methodology for calculating Benefit-Cost Ratios that is consistent with the Commission’s Risk-Based Decision-Making Framework, (2) determining the audit framework for verifying any undergrounding costs recorded to the program’s one-way balancing account were properly recorded therein, and (3) adopting certain additional conditions (additional Phase 2 Conditions) to ensure that any costs ultimately recorded in the balancing account are just and reasonable.

Rulemaking (R.) 18-07-005 (Order Instituting Rulemaking to Consider New Approaches to Disconnections and Reconnections to Improve Energy Access and Contain Costs)

This decision addresses Phase 2 issues on disconnection caps and pilot programs and considers solutions for reducing disconnection rates. This decision conditionally lifts the disconnection cap established in D.20-06-003 for Southern California Gas Company (SoCalGas) and updates the disconnection caps for Pacific Gas and Electric Company (PG&E), SCE, and SDG&E. This decision authorizes limited, conditional increases in annual disconnection caps for PG&E, SCE, and SDG&E in 2027 and 2028, subject to a compliance filing and ongoing monitoring.

Rulemaking (R.) 23-03-007 (Order Instituting Rulemaking to Set Wildfire Fund Non-Bypassable Charge in 2024, 2025, and 2026)

This decision adopts a $0.00545/kWh rate amount for the 2027 Wildfire Fund Non-Bypassable Charge in order to collect $860 million from January 1, 2027 through December 31, 2027. Given the projected $42.4 million over collection through 2026, this will result in a 2027 annual revenue requirement of $902.4 million for the Wildfire Fund Non-Bypassable Charge.

Voting Meeting

The CPUC will hold a voting meeting on October 29, 2026 in San Francisco, California, at 11:00 a.m. PT. The energy-related items on the agenda 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 transmission-level retail electric load at 230 kilovolts in San Jose, California. The resolution approves the AL with modifications, requiring additional ratepayer protections.

Item 4. 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.

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.

Item 7. 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 SoCalGas’s 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.

Item 8. Rulemaking (R.) 25-08-013 (Order Instituting Rulemaking to Establish Policies, Processes, and Rules Regarding Autonomous Vehicle Passenger Transportation Service)

This decision resolves the Track One issues that have been categorized as Autonomous Vehicle Program Requirements and Administration. In a subsequent decision, the Commission will resolve the remaining Track One issue that deals with the requirements for the Autonomous Vehicle transport of unaccompanied minors.

Item 10. Resolution E-5474

This resolution approves updates to the Database for Energy-Efficient Resources (DEER) for program year (PY) 2028 and a revised version of DEER for PY2026 and PY2027, in compliance with D.15-10-028 and D.21-05-031, and Resolutions E-4818, E-5152, E-5221, and E-5350. This update also directs forward-looking research and addresses significant transitions for the DEER and measure package system maintenance and operation. All updated DEER assumptions, methods, values, and supporting documentation are available on the DEER Module on the California Energy Data and Reporting System.

Item 15. Application (A.) 25-07-001 (Application of Southern California Gas Company on Behalf of its Customers, for Approval of Gas Line Extension Allowances)

This decision grants in part and denies in part the application of SoCalGas on behalf of its customers, for approval of gas line extension allowances. This decision also approves SoCalGas’s request to revise Tariff Rule Nos. 20 and 21, SoCalGas’s update to the non-residential gas line extension allowance multiplier of 3.1, and SoCalGas’s request to establish a two-way balancing account to track costs associated with approved gas line extension allowances. Finally, this decision approves the calculation of SoCalGas’s forecasted revenue requirement but directs SoCalGas to update its revenue requirement calculations to account for the fact that only five of the original nine projects are approved by this decision.

Item 19. Application (A.) 22-05-015/16 (Application of Southern California Gas Company/San Diego Gas & Electric Company for Authority, Among Other Things, to Update its Gas Revenue Requirement and Base Rates Effective on January 1, 2025)

This decision denies the November 25, 2025 petition to modify D.24-12-074, Decision Addressing the 2024 Test Year General Rate Cases of Southern California Gas Company and San Diego Gas & Electric Company (the Decision), filed by the Natural Resources Defense Council, CALSTART, Inc., Powering America’s Commercial Transportation, Advanced Energy United, Tesla, Inc., Walmart Inc., the City of San Diego, Electrify America, LLC, EVgo Services, LLC, and the Electric Vehicle Charging Association (Joint Petitioners). Joint Petitioners request modification of the Decision to remove the funding cap for the Electric Rule 45 Electric Vehicle Infrastructure Memorandum Account and ensure that Rule 45 remains open to all eligible applications through at least the current rate case cycle, as required by Public Utilities Code section 740.19. Joint Petitioners’ request is denied because the Commission does not find that Petitioners presented any new or changed facts within the meaning of Rule 16.4(b). The decision also finds that the Joint Petitioners used the petition for modification improperly to allege legal errors outside the 30-day window for an application for rehearing.

Item 20. Resolution E-5484

This resolution approves PG&E’s request in AL 7936-E to enter into a Special Facilities Agreement, referred to hereafter as “Agreement,” to provide redundant distribution-level electric service to the Customer’s existing facilities in Cupertino, California. This Agreement makes certain exceptions to Electric Rule 2 to allow PG&E to design and install the Special Facilities and to make upgrades at Stelling Substation and additional distribution upgrades on an actual cost basis. Due to the project’s substantial scope, the Agreement will protect existing ratepayers by ensuring that costs associated with the project reflect the actual work performed, as it may be challenging to accurately estimate costs for this scope of work. Additionally, the Customer is not entitled to refunds for the Special Facilities that have been requested and will pay monthly cost-of-ownership charges for Special Facilities or an agreed upon Equivalent One Time Payment. PG&E requests approval under General Order 96-B Energy Industry Rule 5.3.

Item 21. Application (A.) 26-05-002 (Application of Southern California Gas Company (U904G) and San Diego Gas & Electric Company for Authorization to Implement Revenue Requirement to Enable SAP Migration Program)

This decision authorizes SoCalGas and SDG&E (Sempra Utilities) to establish the Systems Applications Products (SAP) Migration Memorandum Account, effective May 1, 2026, to track costs stemming from implementation of the SAP Migration Program Phase 1B, up to a cap of $13.7 million. This decision does not authorize Sempra Utilities to recover costs recorded in the SAP Migration Memorandum Account. Whether, how, and to what extent Sempra Utilities may recover costs tracked in this memorandum account will be determined in a future Commission decision.

Item 22. Application (A.) 25-09-004 (Order Instituting Rulemaking to Enhance Demand Response in California)

This decision authorizes bridge funding for the 2028–2029 demand response (DR) programs operated by PG&E, SDG&E, and SCE (collectively, IOUs), to ensure program continuity while the Commission considers DR reforms in this rulemaking. In addition, the decision modifies the November 1, 2026, filing deadline for the next IOU DR applications to November 1, 2028, to align the applications with the policy updates expected in this rulemaking. The next applications will cover program years 2030–2034. For the Emergency Load Reduction Program pilot, the decision limits pilot sub-groups and reduces the minimum dispatch hours to ensure the pilot’s availability through the bridge-year period, retain continuity for participants, and increase value for ratepayers. Also, the decision exempts the 2028–2029 DR bridge portfolios from the Societal Cost Test requirement while directing the IOUs to implement Societal Cost Test capability in their DR Cost-Effectiveness Reporting Tools by April 1, 2028, in time for the 2030–2034 program cycle.

Item 23. Rulemaking (R.) 21-06-017 (Order Instituting Rulemaking to Modernize the Electric Grid for a High Distributed Energy Resources Future)

This decision orders PG&E, SCE, and SDG&E (IOUs) to retain a consultant to lead a series of working group meetings to vet proposals for a common DER orchestration framework, and prepare a report with recommendations based on stakeholder feedback in the workshops. This decision also directs the IOUs to organize a full-day stakeholder workshop presenting new Load Flexibility Scenarios that they will incorporate as a fourth modeling scenario in the annual Distribution Planning and Execution Process (DPEP) starting with the 2027–2028 cycle. This decision directs the IOUs to hold a workshop to present their proposals for a Load Flexibility Scenario as a fourth scenario within the existing DPEP Scenario Planning Framework. The decision directs the IOUs to file a joint Tier 3 AL within 60 calendar days after the workshop providing the technical basis for Load Flexibility Scenario inputs and proposing implementation timing.

Item 24. Rulemaking (R.) 18-04-019 (Order Instituting Rulemaking to Consider Strategies and Guidance for Climate Change Adaptation)

This decision declines to adopt modifications to existing General Orders or adopt a new General Order to address climate adaptation. Rather, the decision adopts the framework proposed by the Safety Policy Division, with modifications. Upon issuance of this decision, this framework will apply to new applications filed by any IOU that is required to file both climate adaptation Vulnerability Assessments and Risk Assessment Mitigation Phase applications. This currently includes PG&E, SCE, SoCalGas, and SDG&E. As such, all future applications filed by PG&E, SCE, SoCalGas, and SDG&E will be screened through questions related to the five policy areas of Repetitive Loss and Failure, Site Selection, Design and Engineering, Equipment Tolerance, and Climate Risk Modeling to determine if the climate adaptation considerations apply to them. The outcome of this screening will be an annual joint IOU workshop, starting in 2028, to summarize the integration of climate adaptation across the five policy areas into applications filed with the Commission. PG&E, SCE, SoCalGas, and SDG&E are additionally required to file a joint annual report by May 1 of each year with specific information to aid tracking and monitoring of climate adaptation activities, aiding the Commission, its staff, and intervenors in evaluating the efficacy of climate adaptation policy to inform IOU filings.

Item 25. Resolution O-0102

This resolution approves Zenith Energy West Coast Terminals LLC’s (Zenith Terminals) request for authorization to discontinue service at the Alamitos Terminal in accordance with the provisions of General Order 96-B, Energy Industry Rule 5.3.6. This resolution also grants Zenith Terminals authority to file a Tier 1 AL following discontinuance of service at the Alamitos Terminal to remove references to the Alamitos Terminal from its tariff.

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 financing costs related to the five-year recovery period, along with 75% 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.

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.

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.

Item 49. 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)

The decision authorizes PG&E to recover, on an interim rate basis, no more than $456 million in revenue requirement, beginning January 1, 2027, to remain in effect until implementation of a final decision.

Item 50. Application (A.) 22-05-015 (Application of Southern California Gas Company for Authority, Among Other Things, to Update its Gas Revenue Requirement and Base Rates Effective on January 1, 2024)

This decision evaluates SDG&E’s costs recorded in its wildfire mitigation plan memorandum account for 2023 and for SDG&E’s drone program costs from 2019 to 2023. This decision also addresses SoCalGas’s and SDG&E’s Pipeline Safety Enhancement Plan costs carried over from Track 1 of this proceeding, D.24-12-074. For Pipeline Safety Enhancement Program (PSEP) work conducted from August 2014 to July 2019, SDG&E requests $239.196 million in capital expenditures and $1.213 million in O&M costs. The Commission finds $26.159 million of SDG&E’s requested capital expenditures to be unreasonable and therefore approves $213.037 million in capital costs. The Commission’s disallowances also have the effect of denying SDG&E’s certain requested recovery of O&M costs. After accounting for the Interim Rate Recovery SDG&E already collected for the PSEP Balancing Account, as well as the disallowances noted above, the Commission authorizes SDG&E to recover the remaining undercollected revenue requirement through 2026 of $17.3 million via its next scheduled rate change. The 2027 revenue requirement associated with PSEP costs shall be implemented in rates on January 1, 2027, or with the next scheduled rate change for that year, through a Tier 1 AL. For PSEP work conducted from December 2015 to December 2020, SoCalGas requests $453.861 million in capital expenditures and $45.243 million in O&M costs. The Commission finds $98.021 million of SoCalGas’s requested capital expenditures to be unreasonable and therefore approves $355.838 million in capital costs. The Commission also finds $7.883 million of SoCalGas’s requested O&M costs to be unreasonable and therefore approves $37.359 million in O&M costs. After accounting for the Interim Rate Recovery SoCalGas already collected for the PSEP Balancing Account, as well as the disallowances noted above, the Commission authorizes SoCalGas to recover the remaining undercollected revenue requirement through 2026 of $19.812 million via its next scheduled rate change. The 2027 revenue requirement associated with PSEP costs shall be implemented in rates on January 1, 2027, or with the next scheduled rate change for that year, through a Tier 1 AL. To reduce the rate impact and to support rate stability, the Commission authorizes SDG&E and SoCalGas to amortize the balance of the undercollected revenue requirement owed for PSEP costs through 2026 over a period of 12 months.

Item 51. Application (A.) 25-04-006 (Application of Southern California Gas Company for Adoption of a Microgrid Optional Tariff)

The decision denies, without prejudice, SoCalGas’s request for authorization to offer the Microgrid Optional Tariff (MOT), primarily because SoCalGas has failed to meet its burden of demonstrating that the proposed tariff is reasonable and in the public interest. The purpose of MOT was to enable the utility to design, build, own, operate, and maintain behind-the-meter and off-grid microgrid facilities within SoCalGas’s service territory. Because the Commission denies SoCalGas’s request, the decision does not determine the program-design requirements that would apply if the MOT were approved.

Events

Busbar Mapping Webinar

Energy Division staff will host a webinar on the electricity resource portfolios proposed for use in the California Independent System Operator’s (CAISO’s) 2027-2028 Transmission Planning Process on Thursday, October 22, 2026 from 9:00 a.m. to 12:00 p.m. Additional information, including access details and links to related materials, is available here.

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.

Demand Analysis Working Group (DAWG)

On October 16, 2026, the CEC circulated a “save the date” notice for a November 4, 2026 DAWG meeting to discuss the California Energy Demand Forecast load modifier draft results for the 2026 IEPR. The meeting will be held via Zoom and will begin at 1:00 p.m. Additional information, including access instructions, is available here.

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.

Webinar on Enabling Bidirectional EV Charging at Home (V2H)

The CEC will host a webinar on November 10, 2026, from 10 a.m. to 2:30 p.m. to present and discuss commercially available and upcoming V2H solutions. The webinar will feature presentations from several automakers and charging equipment providers. The goal is to share and discuss the current state of V2H deployments in California and to gather broad stakeholder input as CEC considers next steps and policies to facilitate access to bidirectional charging benefits for California EV drivers. Meeting details, including an agenda and presentation slides, will be posted prior to the webinar in Docket 22‑EVI‑06.

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, 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.

Workshop on SB 767 Implementation

The CEC will host a workshop to begin implementation of SB 767 (Richardson, 2025), which establishes new reporting requirements for crude oil pipelines that supply California refineries. SB 767 was enacted in 2025 to help maintain the reliability of California’s crude oil supply by preventing shutdowns of low‑flow crude oil pipelines. It directs the CEC to work with stakeholders to identify reportable pipelines – pipelines that deliver domestic crude oil to in‑state refineries and whose closure could significantly reduce refinery processing capability. Beginning March 30, 2027, operators of reportable pipelines must submit monthly operating data, including minimum and maximum operating volumes, daily crude delivery volumes, operating hours, nameplate capacity, and available capacity.  

During the workshop, CEC staff will present and receive input on draft SB 767 “reportable pipelines” regulations and proposed implementation plan with a focus on the data requirements. The workshop will include a public comment period. A detailed meeting schedule will be posted prior to the workshop in Docket No. 26-OIR-02.

Lithium Valley Informational Proceeding

The CEC will host a hybrid workshop on November 6, 2026 to discuss Lithium Valley development as well as the policies and programs that are in place or that will continue to evolve in order to measure and regulate the lithium industry. The workshop will be available by Zoom or in person at San Diego State University, Imperial Valley, Rodney Auditorium in Calexico, CA. Additional details are available here. Written comments are due to the Docket Unit (Docket No. 24-OIIP-02) by 5:00 p.m. on November 30, 2026.

CALIFORNIA AIR RESOURCES BOARD (CARB)

On September 25, 2026, CARB announced final amendments to the Advanced Clean Fleets (ACF) regulation. The amendments include:

• Extending the 50% zero-emission vehicle purchase provision by 3 years 

• Delaying the 100% zero-emission vehicle purchase provision to 2030 

• Extending the exemption for small fleets and fleets in designated low-population counties until 2030 

• Expanded compliance flexibilities 

The amendments help satisfy the requirements of Assembly Bill 1594, which directed CARB to provide flexibility to most public agency utilities that use highly specialized vehicles in carrying out their work. Public utilities will have expanded access to several exemptions allowing the purchase of combustion engine vehicles when zero emission vehicles are not available or do not meet the fleet’s needs. Additional information regarding ACF and the amendments is available here.

MINNESOTA PUBLIC UTILITIES COMMISSION (MPUC)

At its October 21, 2026, weekly agenda meeting, the MPUC will consider: (1) what action to take on Xcel Large Industrials’ motion to refer the Petition for Approval of an ESA between Google and Xcel Energy to the Court of Administrative Hearings for contested case treatment and compel Xcel Energy to remove references to “Highly Confidential Trade Secret Information” (Docket Nos. E002/M-26-170; E002/M-26-171); (2) granting a site permit for the proposed solar project by Lemon Hill Solar, LLC (Docket No. IP7156/GS-25-126); (3) acceptance of the Minnkota Power Cooperative, Inc. and Northern Municipal Power Agency’s 2026-2040 Integrated Resource Plan (Docket No. ET6/RP-25-417); (4) acceptance of Xcel Energy’s tariff filing regarding the integration and implementation of the Distribution System Reactive Upgrade Process (Docket No. E002,015,017/CI-24-288); (5) what guidance should be given on the scope and/or priority to address the issue of new and expanded substation upgrades being discussed in a subgroup of the Distributed Generation Workgroup (Docket No. E999/CI-16-521); and (6) approval of Dakota Electric Association’s (DEA) proposed requirements in DEA’s Petition for Establish and Define a Very Large Member Contract Rate Service (Docket No. E-111/M-26-243).

Additionally, on October 14, 2026, the MPUC denied Minnesota Power’s request to include a pre-paid pension asset in the rate base (Docket Nos. E015/GR-21-335; E015/GR-23-155). The MPUC directed additional record development on whether to include a true-up mechanism for pension expenses. The decision option adopted by the MPUC is accessible here.

Federal Agencies

FEDERAL ENERGY REGULATORY COMMISSION (FERC)

October Commission Meeting Summaries

At its October 15 Commission meeting, FERC published orders on the following:

• EL25-92-001 | McKenzie Electric Cooperative, Inc. v. Basin Electric Power Cooperative: FERC issued an order sustaining the Commission’s May 21, 2026, order dismissing McKenzie Electric Cooperative, Inc.’s complaint alleging that Basin Electric Power Cooperative engaged in a loan transaction with the Rural Utilities Service in a manner inconsistent with the Federal Power Act. 
• RR26-3-000 | North American Electric Reliability Corporation (NERC): FERC issued an order accepting the 2027 business plans and budgets for NERC, the six Regional Entities, and WIRAB and authorizes the issuance of billing invoices to fund their fiscal year 2027 operations. The order also grants limited waivers of the NERC Rules of Procedure to permit specified deposits into, withdrawals from, assessment stabilization reserves and approves WECC’s use of Peak Reliability Donation Reserves to fund a gas-electric interface study, AI projects, and data management projects. 
• ER24-2045-005 | PJM Interconnection, LLC (PJM): FERC issued an order accepting in part, and rejecting in part, the proposed revisions submitted by PJM to its Open Access Transmission Tariff to comply with the requirements of Order Nos. 2023 and 2023-A and the Commission’s order on compliance issued April 2026. The order also directs PJM to submit further compliance filings. 
• EL26-84-000, QF26-1177-001 | IGS CTS, LLC: FERC issued an order granting IGTS CTS, LLC’s request for partial waiver from the filing requirement in section 292.303(a)(3) of the Commission’s regulations applicable to small power production qualifying facilities during a non-compliance period, starting December 3, 2025, the date the facility began operations, and ending June 17, 2026, the date Petitioner filed a Form No. 556 for QF certification.

Grid Reliability, Nuclear Power, and Cybersecurity Public Meeting

FERC and the Nuclear Regulatory Commission (NRC) noticed a joint open meeting on Thursday, October 22, 2026, from 1:00 p.m. to 3:30 p.m. EST. FERC stated the meeting is not for the purpose of discussing the merits of any specific proceedings before FERC, but the meeting may relate to FERC’s June 18, 2026 show cause orders related to large loads. The meeting will be held in person at the NRC’s headquarters at One White Flint North, 11555 Rockville Pike, Rockville, MD 20852-2738 in the Commissioners Hearing Room. Commissioners from both agencies are expected to participate.

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

CALIFORNIA INDEPENDENT SYSTEM OPERATOR (CAISO)

Stakeholder Initiatives: Upcoming Meetings and Deadlines

REMINDER: Registration for Joint Market Seams Workshop

The fourth market seams workshop jointly held by the CAISO and Southwest Power Pool is scheduled for October 22, 2026, from 9:00 a.m. to 2:30 p.m. MDT. The workshop will focus on the Western leading relief process and Enhanced Curtailment Calculator.

DAME Transitional Measures and Overlapping Capacity Training Session

The CAISO will offer training on the Day-Ahead Market Enhancements (DAME) transitional measures and overlapping capacity on October 22 from 1:30 p.m. to 3:30 p.m. PST. This session will provide an overview of key concepts and walk participants through settlement scenarios and examples. Registration is required for this training.

FERC Order No. 1920 Compliance Filing: Supplemental Proposal Meeting

The CAISO will hold a stakeholder meeting on October 26 to discuss updates to its FERC Order No. 1920 compliance efforts and the CAISO’s plans to submit a supplemental compliance filing in November 2026. Further, the CAISO will discuss a proposed extension of the date to initiate the Long-Term Regional Transmission Planning process from February 1, 2027, to February 1, 2029.

MIDCONTINENT INDEPENDENT SYSTEM OPERATOR (MISO) 

FERC Issues Deficiency Letter on Zero Injection Generation Resources (ZG Resources)

In response to MISO’s tariff revisions for ZG Resources, FERC issued a deficiency letter finding that MISO’s revisions required more information.

MISO’s proposed revisions included establishing a 90-day study process, operational requirements, and market and resource adequacy rules to accommodate the interconnection of ZG Resources, which are generating facilities that intend to serve load interconnecting at the same substation and voltage level as the ZG Resource without injecting energy onto MISO’s transmission system. MISO proposed to add a pro forma Zero Injection Generator Interconnection Agreement to its Generator Interconnection Procedures and that a ZG Resource may participate in MISO’s markets and resource adequacy construct, subject to the limitation that its participation is limited to serving the load associated with the ZG Resource. FERC directed MISO, among other things, to explain how its proposed revisions accomplish the purposes of FERC Order No. 2003 related to interconnection standards, and how capacity market revisions as they relate to ZG Resources are just and reasonable. MISO’s response is due by November 23, 2026.

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.

ISO NEW ENGLAND (ISO-NE) 

FERC Approves Asset Condition Reviewer

FERC approved ISO-NE’s tariff revisions that establish ISO-NE as the region’s Asset Condition Reviewer and the processes for ISO-NE to execute this new role.

Asset Condition Projects are capital projects undertaken by Participating Transmission Owners (PTOs) to replace or reconstruct deteriorating or obsolete transmission facilities to maintain transmission system reliability and integrity. Effective January 1, 2027, ISO-NE will serve as an independent Asset Condition Reviewer. ISO-NE will review certain projects to determine whether the PTO has adequately demonstrated the technical need for the project, sufficiently considered alternatives and cost-effectiveness, and reasonably supported its preferred solution. The reviewer’s role is advisory: ISO-NE will not decide whether a project proceeds or whether its costs are prudent, and PTOs will still plan, own, maintain, and decide whether to proceed with projects.

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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.