October 28, 2026

Regulatory Update for October 28, 2026

(Covering October 21, 2026 - October 27, 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.

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State Regulatory Agencies

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

Proposed Decisions and Resolutions

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

This decision directs the three large electric Investor-Owned Utilities (IOUs), Pacific Gas and Electric Company (PG&E), Southern California Edison Company (SCE), and San Diego Gas & Electric Company (SDG&E) to expand the availability and use of flexible service connections (FSCs) for customers. Building on existing offerings, as well as directing new offerings, this decision expands the use of FSCs to enable customers to connect to the electrical grid using available distribution grid capacity while deferring or avoiding upgrades where feasible. This decision directs the IOUs to implement and expand a range of offerings that reflect customer successes and advances in the evolution of power control systems and technical standards. Implementation is sequenced according to the complexity of the FSC measures and the capabilities of each IOU’s system, while also considering the technical infrastructure needed to support broader deployment. According to the Commission, this decision advances affordability by requiring the IOUs to evaluate lower-cost mitigations when these options meet the needs of a proposed connection and defer or avoid the need for a more costly upgrade. The IOUs must provide customers with sufficient information about available options and their associated operating limits to enable them to determine whether an FSC meets their needs. The decision further addresses the rules and procedures necessary to enable these options, including support for customer-managed power limits and updates to the IOUs’ Electric Rule 2 provisions that govern the specifications of electric service such as the voltage range. Lastly, this decision establishes data reporting and affordability tracking requirements to document the use and outcomes of FSCs. Accordingly, this information will assist in assessing affordability impacts and informing future implementation. Taken together, these actions establish a framework for expanding FSCs. Expansion of FSCs allows for greater use of existing distribution capacity, additional customer connection options, reduction in infrastructure costs, and development of technical and operational capabilities needed to support these options over time.

Rulemaking (R.) 19-09-009 (Order Instituting Rulemaking Regarding Microgrids Pursuant to Senate Bill 1339 and Resiliency Strategies)

This decision grants the petition for modification of Decision (D.) 20-06-017 filed by California Solar & Storage Association, in part. Specifically, the decision modifies D.20-06-017 to temporarily remove the energy storage sizing limit for large net energy metering-paired storage until January 1, 2030.

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. Held to November 19.

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. Held to November 19.

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

Rev. 1: On October 27, the Commission issued Revision (Rev.) 1 to the PD which materially revises the cost recovery. The revised decision denies $20,152,686 in capital costs and $42,603,474 in Operations & Maintenance (O&M) costs. The reductions reflect a disallowance in both capital and O&M for incremental straight-time labor costs and associated vacation and sick leave costs (approximately $37 million), incremental Vendor #11900 costs (approximately $0.693 million), and a $24,464,160 disallowance for the eight percent of projects SoCalGas did not support with workpapers. Within 30 days of the adoption of this decision, SoCalGas is directed to file a Tier 2 advice letter to calculate the final revenue requirement in light of the reductions to capital and O&M described above and may include a proposed alternative breakdown of the $24,464,160 disallowance between capital and O&M by providing an allocation that is based on the information in this proceeding. This decision directs SoCalGas to utilize the cost allocation mechanism adopted by the Commission in Decision 24-07-009, until such time as a new cost allocation mechanism is adopted. Furthermore, SoCalGas is directed to amortize the amounts authorized for recovery in this decision over a 12-month amortization period.

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 distributed energy resource (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. Held to November 19.

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

This decision finds that all investor-owned gas utility customers should pay a share of the above-market costs of the Renewable Gas Standard (RGS) program. However, the allocation of costs is not extended to non-core customers at this time, pending further assessment of whether an exemption (either in whole or in part) should apply to non-core customers. An additional process on this matter is needed to identify whether and how to implement cost allocation in a way that avoids emissions leakage and encourages industry to stay in California. This decision orders the joint gas utilities to lead a workshop process and subsequently file an application that considers recommendations coming out of the workshop as to whether and how these issues should be addressed. Held to November 19.

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

This Alternate Proposed Decision (APD) finds that all investor-owned gas utility customers should pay a share of the above-market costs of the RGS program and allocates costs to both core and non-core customers. The APD similarly directs the utilities to lead a workshop process and subsequently file an application. Held to November 19.

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. Held to November 19.

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. Held to November 19.

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

Interconnection Forum for Project Developers

Southern California Edison Company (SCE) will host the transmission interconnection forum for developers seeking interconnection. The forum will focus on policy, process, and implantation topics affecting transmission interconnection. The forum will take place on November 17, 2026 virtually. Meeting details can be found here, and those wishing to attend must register by October 30, 2026.

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.

Distributed Electricity Backup Assets (DEBA) Grant Funding Opportunity

On October 23, 2026, the CEC announced the availability of up to $46 million in grant funding available for a competitive grant solicitation through the DEBA Program. The intent of this solicitation is to support the deployment of new DERs that can increase supply or reduce (or shift) load to improve the reliability of the state’s electrical grid and help avoid blackouts during extreme events. CEC staff will host one Pre-Application Workshop, on November 5, 2026 from 1:00 p.m. – 4:00 p.m., to discuss this solicitation with potential applicants. Event access details are available here.

Webinar on Enabling Bidirectional EV Charging at Home (V2H)

The CEC will host a webinar on November 10, 2026, from 10:00 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 the 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.

Gas Reliability Workshop

The CEC will host a staff workshop on November 24, 2026, from 1:00 p.m. – 3:00 p.m. to present California’s natural gas reliability outlook for the winter months of 2026–2027. A workshop agenda, access details, and related documentation are available here.

Workshop on Senate Bill (SB) 767 Implementation

The CEC will host a workshop on October 28, 2026 from 2:00 p.m. – 3:00 p.m. PT 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.

Workshop on Refinery Resupply

The CEC will host a workshop on November 9, 2026, from 1:00 p.m. – 3:30 p.m. to discuss resupply rulemaking pursuant to Assembly Bill (AB) X2-1 (Stats. 2024, 2d Ex. Sess. 2023–2024, Ch. 1) and SB X1-2 (Stats. 2023, 1st Ex. Sess. 2023–2024, Ch. 1).

SB X1-2 and AB X2-1 require the CEC to assess transportation fuel prices, supply conditions, and reliability in California. AB X2-1 further requires the CEC to consider the effects of refiners’ inventories of fuel, feedstock, and blending components on transportation fuel prices, and authorizes the CEC to consider ways to minimize the impacts of maintenance-related production losses on fuel prices while protecting the health and safety of workers, local communities, and the public.

A link to the workshop agenda and access details is available here.

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, California. 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)

Preliminary Carbon Capture Removal, Utilization, and Storage Regulations

CARB staff proposed regulations that would regulate entities voluntarily pursuing carbon capture projects, direct air capture (DAC) projects, and geological carbon storage (GCS) and injection sites. The proposed regulations include:

  • Public disclosure requirements that apply to operators of carbon capture projects, DAC projects, and GCS sites, including maintaining a public-facing webpage with monitoring plans and periodic reports, permitting and regulatory information, existing air monitoring, and remedial response plans, as applicable;
  • Geologic storage requirements to monitor surface and subsurface carbon dioxide leakage, monitor ambient concentrations of criteria air pollutants and toxic air contaminants, implement strategies that minimize air quality impacts, perform risk-based seismic monitoring to reduce seismic impacts and the probability of an undetected leak, demonstrate long-term financial responsibility, and engage with nearby communities; and
  • Align with existing programs by proposing amendments to the Cap-and-Invest Program to clarify how carbon capture and sequestration can reduce greenhouse gas emissions, amendments to the Regulation for the Mandatory Reporting of Greenhouse Gas Emissions to require monitoring, reporting, and verification provisions for GCS sites operating in the state and claims of sequestered carbon, and amendments to the Low Carbon Fuel Standard to reflect updates to the GCS protocol to separate accounting and permanence provisions.

CARB stated that the proposed regulations are expected to have a 45-day public comment period beginning on October 30, 2026, and an anticipated end date of December 14, 2026. 

MINNESOTA PUBLIC UTILITIES COMMISSION (MPUC)

At its October 29, 2026, weekly agenda meeting, the MPUC will consider: (1) granting the Petition for Reconsideration submitted by Larry Rauenhorst regarding the Formal Complaint by Larry Rauenhorst against Renville Sibley Cooperative Power Association (Docket No. E136/C-26-113); (2) approving Xcel Energy’s proposed Invenergy - Lake Wilson BESS agreement and authorizing Xcel Energy to recover from Minnesota retail customers the Minnesota jurisdictional portion of the energy costs through the Fuel Clause Rider and capacity payments through base rates and the capacity tracker (Docket Nos. E002/CN-23-212; E002/RP-24-67); and (3) accepting the Offer of Settlement regarding Xcel Energy’s Application for Authority to Increase Rates for Natural Gas Service in Minnesota, and adoption of the recommendations in the Administrative Law Judge’s Findings of Fact, Conclusions of Law, and Recommendation regarding the level of revenue appropriate for the Company’s 2026 test year (Docket Nos. G002/GR-25-356; G002/MR-25-357).

Additionally, at its October 22, 2026, weekly agenda meeting, the MPUC denied Xcel Large Industrials’ (XLI) motion to compel Xcel Energy to remove references to “Highly Confidential Trade Secret” information (Docket Nos. E002/M-26-170; E002/M-26-171), thus precluding XLI and all other non-government participants access to certain information regarding the proposed electric service agreement (ESA) between Xcel Energy and a new data center customer. XLI’s motion also included a request for contested case review of the ESA, which the MPUC tabled until a future hearing after the close of the comment period.  

PACIFIC NORTHWEST (OPUC, WUTC, BPA)

Public Utility Commission of Oregon (OPUC)

On October 22, 2026, the OPUC held a rulemaking hearing on proposed rules implementing House Bill 3863 and a 10-megawatt cap on standard PURPA avoided-cost rate eligibility for Qualifying Facilities, with written comments due October 29, 2026 (Docket No. AR-684). The Notice of Proposed Rulemaking can be found here.

Washington Utilities and Transportation Commission (WUTC)

On October 18, 2026, former State Senator Reuven Carlyle and Washington Policy Center’s Todd Myers debated on TVW’s “Inside Olympia” whether to ease permitting and infrastructure barriers or relax Washington’s 2030 clean electricity deadline, with both noting opportunities for data centers to help finance new generation.

Bonneville Power Administration (BPA)

On October 19, 2026, BPA hosted an all-day Grid Access Transformation workshop to introduce its RAPID and SPRINT initiatives for accelerating large-load and data center interconnections to its transmission grid, with a final record of decision targeted for spring 2027. Workshop materials, including slide presentation, are available here. On October 23, 2026, BPA held a Post-2028 Residential Exchange Program workshop to continue developing the Residential Purchase and Sale Agreement, the Average System Cost Methodology, and related 7(b)(2) legal interpretation issues. More information on the Post-2028 Residential Exchange Program can be found here. 

The deadline for objecting to BPA’s proposed settlement of the TC-27 proceeding closed on October 16, 2026. BPA received 16 objections in response to its settlement proposal from companies that include Grant PUD, Inland Power and Light Company, and NewSun Energy, among others. The objections are available here. 

Federal Agencies

FEDERAL ENERGY REGULATORY COMMISSION (FERC)

FERC Approves MISO Demand Response Changes

FERC approved MISO’s proposed tariff revisions, effective June 1, 2027, reforming MISO’s penalty provisions for Load Modifying Resources (LMRs), including Demand Response Resources, that fail to meet their performance obligations beginning with the 2027/2028 Planning Year.

Under the revised framework, MISO may use a real-time penalty and an Auction Clearing Price (ACP) penalty tied to the resource’s degree of underperformance and capacity-market compensation. FERC concluded that the penalty framework is not overly punitive as it is intended to incentivize performance during emergencies and replace capacity that MISO otherwise expects to be available. FERC nevertheless required MISO to clarify through a compliance filing how the ACP penalty applies when an LMR reports itself unavailable and therefore does not receive a Scheduling Instruction.

The order also tightens the consequences of nonperformance for continued participation in MISO’s capacity market. An LMR experiencing a complete performance failure will generally be disqualified for the remainder of the Planning Year unless it has fully performed in response to at least one Scheduling Instruction during the same Season. Two complete failures in a Season will result in exclusion from the following Planning Year’s auction, and an LMR disqualified twice within three years will be barred from the auction for three additional Planning Years. MISO will also retain discretion to prohibit an LMR with a single complete performance failure from participating in the following Planning Year.

FERC Extends Expedited Resource Addition Study (ERAS) Sunset Date

FERC accepted a request from MISO to extend the sunset date of its ERAS process from August 31, 2027, to December 31, 2027. MISO’s ERAS process is its targeted temporary process designed to issue a Generator Interconnection Agreement within three months.

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

CALIFORNIA INDEPENDENT SYSTEM OPERATOR (CAISO)

Stakeholder Initiatives: Upcoming Meetings and Deadlines

2027 Default Resource Adequacy Values

The CAISO has posted the final 2027 Default Qualifying Capacity list and FAQ documents. The CAISO will use the posted default qualifying capacity values and planning reserve margins included in this list for compliance year 2027 only in situations where a Local Regulatory Authority has not submitted a qualifying capacity value for a resource or a planning reserve margin for a load serving entity.

2028 Local Capacity Requirements: Technical Study Criteria, Methodology, and Assumptions Meeting

The CAISO will hold a public stakeholder meeting on November 2, 2026, to discuss the criteria, methodology, and assumptions to be used in the 2028 Local Capacity Technical Study. The draft study manual, meeting materials, and meeting details are available here.

Extended Day-Ahead Market (EDAM) Congestion Revenue Allocation Phase 2

The CAISO will hold an upcoming hybrid, full-day, EDAM congestion revenue allocation working group meeting on November 9, 2026. The meeting details can be found here. This meeting will be a continuation of prior working group meetings discussing design concept #3, which introduces a common simultaneous feasibility test that informs the congestion revenue entitlements incorporating congestion revenue rights in the CAISO balancing area and reserved transmission rights in the EDAM balancing area.

SOUTHWEST POWER POOL (SPP)  

Ninth Circuit Rejects Nonprofit Suit on SPP+ Participation

The Ninth Circuit Court of Appeals rejected a petition from nonprofit organizations that sought review of BPA’s decision to join Markets+. The Ninth Circuit reasoned that the nonprofit organizations’ claims were not ripe for review given that Markets+ does not yet exist and BPA has not formally joined it, and therefore the court could not speculate on what injuries may occur.

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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.

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