January 22, 2026

Regulatory Update for January 22, 2026

(Covering January 14, 2026 - January 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)
• Pacific Northwest (OPUC, BPA, WUTC)

Federal Regulatory Agencies

• Federal Energy Regulatory Commission (FERC)

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

• California Independent System Operator (CAISO)
• PJM Interconnection (PJM)
• New York Independent System Operator (NYISO)
• ISO New England (ISO-NE)
• Southwest Power Pool (SPP)

Click here to download this update as a PDF

Expanding Our Energy Infrastructure Capabilities

We’re pleased to welcome Ankur Tohan, an environmental attorney with a deep focus on energy infrastructure, renewables, and carbon management. Ankur advises energy clients on permitting, enforcement defense, and regulatory strategy across complex federal and state regimes, drawing on significant prior experience at EPA and the Washington Attorney General’s Office. Read the full announcement to learn how Ankur’s background supports today’s energy projects.

State Regulatory Agencies

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

Proposed Decisions and Resolutions

Rulemaking (R.) 25-06-019 (Order Instituting Rulemaking to Continue Oversight of Electric Integrated Resource Planning and Procurement Processes)

This decision requires load-serving entities under the Commission’s integrated resource planning purview to undertake additional reliability procurement between 2029 and 2032, to pursue any viable projects that can still qualify for Federal tax credits or other incentives, as well as to continue the momentum of annual procurement activity that began under the mid-term reliability (MTR) and supplemental MTR requirements in Decision (D.) 21-06-035 and D.23-02-040, respectively. The new procurement required is 2,000 megawatts (MW) of net qualifying capacity (NQC) by 2030 and an additional 4,000 MW NQC by 2032, with no more than half of the total NQC per tranche eligible to come from storage resources. This procurement will be generally subject to the same compliance and enforcement requirements as the prior MTR orders, with some exceptions.

This decision also transmits a reliability and policy-driven base case electricity portfolio and a sensitivity portfolio to the California Independent System Operator (CAISO) for analysis in its 2026-2027 Transmission Planning Process (TPP). The recommended base case portfolio is consistent with the 2025-2026 TPP base case portfolio, though it differs from the 2025-2026 TPP base case by extending the online dates for some offshore wind resources by up to six years, and recommending up to a two-year extension to the in-service dates for the transmission to support North Coast offshore wind. The recommended sensitivity portfolio tests a low-wind development scenario. 

Resolution E-5436

This Resolution explains the relationship between the IOUs’ distributed generation interconnection applications and the California Distributed Generation Statistics (DGStats) Platform. The Resolution also addresses funding and data quality issues that currently limit the potential improvement and value of DGStats and the associated interconnection application data. This Resolution authorizes an increase to the DGStats vendor budget to $2.6 million over each three-year contract and authorizes Energy Division to adjust the budget by an amount indexed to the prior calendar year’s rate of inflation through a Letter from the Deputy Executive Director or their designee or an email communication to select service lists once per year. The IOUs are directed to implement a series of changes to each of their respective online interconnection application interfaces to resolve ongoing data quality issues and improve data comprehensiveness.

Resolution E-5445

This Resolution approves 10 contracts across four projects, two of which are co-located battery energy storage system (BESS) and solar photovoltaic (PV) projects, while the remaining two projects are solar PV. All 10 of these contracts were entered into because of Southern California Edison Company’s (SCE) 2024 Clean Energy Request for Offers. SCE contracted these 10 different resources to help meet its Integrated Resource Plan (IRP), capacity, and RPS requirements (full summary of contract terms found in Confidential Appendix A).

Voting Meeting

The CPUC held a voting meeting in San Francisco, California on January 15, 2026, at 11:00 a.m. PT.  The energy-related results are below:  

Item 2. Rulemaking (R.) 18-07-003 (Order Instituting Rulemaking to Continue Implementation and Administration and Consider Further Development of California Renewables Portfolio Standard Program)

This decision denies the March 6, 2025 petition to modify D.20-08-043, filed by the Bioenergy Association of California (BAC).  BAC is seeking to extend or remove the end date of the Bioenergy Market Adjusting Tariff (BioMAT) and proposes other programmatic changes, primarily due to underutilization of this high-cost program and availability of other procurement options for bioenergy resources.  The decision contends that maintaining the BioMAT end date, December 31, 2025, as directed by the Commission in D.20-08-043, is in alignment with the October 30, 2024 Governor’s Executive Order N-5-24 on affordability, and will allow Commission resources to be directed toward more effective clean energy programs. Withdrawn.

Item 3. Application (A.) 23-07-008 (In the Matter of the Application of California Resources Production Corporation (CRPC) for a Certificate of Public Convenience and Necessity to Operate as a Gas Corporation in the State of California)

This decision denies A.23-07-008 and the request to hold this proceeding in abeyance made by the cities of Antioch and Brentwood, California.  The decision further denies CRPC’s motion to amend A.23-07-008 and grants for a period of three years CRPC’s motions to file certain materials as confidential under seal. Held to February 5.

Item 5. Res E-5437.  This Resolution approves one mid-term reliability (MTR) long-term resource adequacy agreement with energy settlement storage contract between Pacific Gas and Electric Company (PG&E) and the Balsam Project, LLC (Balsam Project), for the Dirac Battery Energy Storage System (Dirac Project)

The Dirac Project will be developed by Aypa Power Development through their subsidiary, Balsam Project.  The Balsam Project contract is for a total of 225 megawatts (MW) of nameplate capacity and is expected to be commercially online by May 20, 2028, and deliver for a term of 15 years beginning August 1, 2028.  PG&E procured this lithium-ion battery resource to satisfy a portion of its MTR requirements. Approved.

Item 6. A.23-04-003 (Application of Southern California Edison Company (SCE) for a Commission Finding that its Procurement-Related and Other Operations for the Record Period January 1 Through December 31, 2022 Complied with its Adopted Procurement Plan; for Verification of its Entries in the Energy Resource Recovery Account and Other Regulatory Accounts; and for Recovery of $51.442 Million Recorded in Five Accounts)

This proposed decision (PD) addresses whether SCE met the standard for compliance for its Energy Resources Recovery Account (ERRA) activities in 2022.  Except in two instances, the PD finds that SCE met the applicable standards and requirements for this ERRA compliance application and that the entries in its balancing and memorandum accounts were reasonable and correct.  According to the PD, SCE prudently managed its generation resources and complied with its Bundled Procurement Plan in procuring fuel, greenhouse gas (GHG) compliance instruments, resource adequacy, and other resources. Signed, D.26-01-003.

Item 7. Res E-5432

This Resolution approves an amendment to the contract between PG&E and Nighthawk Energy Storage, LLC (Nighthawk), a subsidiary of PG&E’s project developer, Arevon Energy Inc., for 300 MW of lithium-ion battery storage.  Whereas the delivery date for the previously approved contract was June 1, 2025, the delivery date in the amended contract is June 1, 2026.  In addition, this Resolution approves the amended contract price. Approved.

Item 10. Res G-3617

This Resolution addresses the Southwest Gas Corporation 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. Held to February 26.

Item 12. Res O-0100

This Resolution authorizes San Pablo Bay Pipeline Company LLC to bill and collect $894,683 in retroactive recovery from shippers.  This amount is in accordance with D.25-06-044, with an adjustment made to the calculation of interest owed. Approved.

Item 16. Res G-3618

This Resolution denies PG&E AL 5077-G-A and AL 5069-G with proposed Gas Research, Development, and Demonstration Investment Plans (Gas RD&D Plan) for Calendar Years (CYs) 2024 and 2025.  PG&E’s Gas RD&D Plan was established pursuant to D.23-11-069, requiring PG&E to submit and obtain Commission approval of an annual Tier 3 AL describing PG&E’s proposed Gas RD&D Plan prior to utilizing authorized funds.  Based on Commission review of requirements, the Commission denies PG&E’s Gas RD&D Plans with proposed budgets of $8,092,000 for CY 2024 and $8,267,000 for CY 2025, totaling $16,359,000.  These budgets include administrative budgets of 10% for total administrative costs of $809,200 for 2024 and $826,700 for 2025.  This Resolution denies PG&E’s request to recover $7,207,712 in expenses for CYs 2023 and 2024.  The Commission directs PG&E to submit revised 2024 and 2025 Gas RD&D Plans via respective Tier 3 ALs with modifications specified in the Resolution. Approved.

Item 17. Res E-5439

This Resolution approves, with modifications, PG&E AL 7635-E, which requests Commission approval of four agreements to support the energization of a new 90 MW data center load in San Jose, California as requested by Microsoft Corporation.  These agreements facilitate the construction of new transmission facilities to serve Microsoft’s load.  The Commission approves the AL with modifications, finding the agreements necessary and largely appropriate to energize this new load. Approved.

Item 38. A.22-05-015/22-05-016 (Application of Southern California Gas Company (SoCalGas) for Authority, Among Other Things, to Update its Gas Revenue Requirement and Base Rates Effective on January 1, 2024/Application of San Diego Gas & Electric Company (U 902 M) for Authority, Among Other Things, to Update Its Electric and Gas Revenue Requirement and Base Rates Effective on January 1, 2024)

In this application, SDG&E seeks recovery of costs recorded in its Electric and Gas Wildfire Mitigation Plan Memorandum Accounts from May 2019 through the end of 2022, above amounts not authorized by the Commission in SDG&E’s 2019 Test Year General Rate Case decision (D.19-05-051).  The amount requested includes recovery of operations and maintenance (O&M) costs totaling $284 million and capital expenditures placed in service during the 2019 to 2022 period of $1,188 million.  This decision finds unreasonable and disallows $192.561 million in O&M costs and $242.391 million in capital expenditures.  The Commission approves the balance requested of $77.86 million in O&M expenses and $945.533 million in capital expenditures. Signed, D.26-01-021.

Item 39. R.21-03-011 (Order Instituting Rulemaking to Implement Senate Bill (SB) 520 and Address Other Matters Related to Provider of Last Resort (POLR))

This PD sets guidelines for entities other than Investor-Owned Utilities (IOUs) to file an application for POLR status and for the Commission to develop situation-specific criteria for eligibility to serve as a POLR.  This decision adopts a streamlined version of the approach presented in the Administrative Law Judge’s (ALJ) Ruling Seeking Comment on Procedural Pathway to Address Applications for POLR Status dated May 28, 2025.  According to the PD, any application seeking non-IOU POLR status that is submitted to the Commission should demonstrate that the applicant meets the requirements set forth in SB 520 and shall include supporting evidence demonstrating the applicant meets those criteria.  Currently, there are no non-IOU entities expressing intent to serve as a POLR for all the customers within a given geographic region.  There are some entities that have expressed interest in the responsibilities a non-IOU POLR would have, under certain conditions.  The PD provides that the guidelines set out in the PD conserve Commission and stakeholder resources until the necessary evidence and data are available for the Commission to consider the fact-specific circumstances that an individual applicant seeking non-POLR status may present. Signed, D.26-01-022.

Upcoming Workshops and Events.

Building Decarbonization Best Practices and Future Pathways

On January 21-22, 2026 from 9 a.m. to 4:30 p.m. PT, the CPUC is hosting a workshop, with opening remarks from Commissioner Houck, to discuss lessons learned, best practices, and forward-looking strategies from prior and ongoing building decarbonization programs and activities.  Participants will also discuss pathways for scaling decarbonization, including zonal decarbonization, technology applications, funding, and policy strategies.  Presenters will include state agencies, local governments, tribal governments, Community Choice Aggregators, Regional Energy Networks, utilities, energy program implementers and evaluators, ratepayer advocates, and building industry representatives.  Registration information is available here, and the workshop will be held both in person at the CPUC Headquarters (505 Van Ness Avenue, San Francisco, California) and remote via WebEx.  The meetings will be recorded and made available on the CPUC’s Building Decarbonization page.

Workshop on High Distributed Energy Resource (DER) Planning (R.21-06-017)

The CPUC will host an in-person workshop on February 20, 2026 as part of ongoing workshops in Track 3 of the High DER proceeding. This proceeding considers DER planning, siting, and interconnection, among other elements, needed to determine the timing and scope of system investments that facilitate the integration of DERs into the grid.  The workshop will be held at the CPUC’s headquarters located at 505 Van Ness Avenue, San Francisco, from 10 a.m. to 3 p.m.  A link for remote viewing will be made available but in person attendance is encouraged.

CALIFORNIA ENERGY COMMISSION (CEC)

2025 Integrated Energy Policy Report (IEPR)

On January 7, 2026, the CEC published a Notice of Availability for the California Energy Demand Forecast, 2025 – 2045 (IEPR Forecast).  The IEPR Forecast will be considered for adoption at the January 21, 2026 CEC Business Meeting.

Staff Workshop on the Draft 2025 Building Energy Action Plan

The CEC announced an upcoming workshop to review the contents of the draft 2025 California Building Energy Action Plan (Action Plan) to solicit feedback and stakeholder recommendations.  The workshop will be held on Thursday, January 29, 2026 from 1 p.m. to 4 p.m.  Additional information and access details are available here.

CEC Business Meetings

The CEC held its Business Meeting on January 21, 2026.  The agenda is available here.

CALIFORNIA AIR RESOURCES BOARD (CARB)

Amendments to Cap-and-Invest and Mandatory Reporting Regulations

On January 13, 2026, CARB posted preliminary regulatory proposal documents for the Regulation for the California Cap on GHG Emissions and Market-Based Compliance Mechanisms (Cap-and-Invest Regulation, formerly Cap-and-Trade Regulation) and Mandatory Reporting Regulation for public review ahead of a formal comment period.  CARB staff posted these materials to the Cap-and-Invest Regulation webpage and Mandatory GHG Reporting Regulation webpage. CARB will be submitting these rulemaking materials to the California Office of Administrative Law (OAL). CARB anticipates that OAL will publish the Notice of Public Hearing (Notice) for each regulation on January 23, 2026, commencing a 45-day public comment period that will end on March 9, 2026.

Climate Risk Disclosure Laws Update

On February 26, 2026, CARB will conduct a public hearing to consider approving for adoption the proposed California Corporate GHG Reporting and Climate-Related Financial Risk Disclosure Initial Regulation.  The related Notice of Public Hearing (Notice), Staff Report, and proposed regulatory text were sent to the OAL on December 9, 2025.  These materials are currently available on CARB’s webpage.  OAL published the Notice on December 26, 2025, commencing a 45-day public comment period that will end on February 9, 2026.  Given the holiday season and the strong interest in this program, staff is providing extra time for public review of materials prior to the start of the 45-day formal comment period.

MINNESOTA PUBLIC UTILITIES COMMISSION (MPUC)

At its January 21, 2026 weekly agenda meeting, the MPUC considered: (1) approval of Minnesota Power’s 2025 Remaining Life Depreciation proposal (Docket No. E015/D-25-342); (2) the appropriate data sources and values for the regulatory cost of greenhouse gas emissions for the upcoming gas integrated resource plans for the state’s electric utilities (Docket Nos. E999/CI-07-1199; E999/DI-22-236; E999/CI-14-643; G008, G002, G11/CI-23-117 G999/CI-21-565); (3) adoption of the ALJ report and whether to grant the associated certificate of need and route permit for the Appleton to Benson 115-Kilovolt Transmission Line Project (Docket Nos. ET2, E017, ET6135, E100/CN-24-263; ET2, E017, ET6135, E100/TL-24-264); and (4) approval of the Invenergy Cannon Falls, Onward Mankato Energy Center 1, Mankato Energy Center BESS, and DESRI North Star Energy PPAs, authorization for Xcel to recover through the Fuel Clause Rider the Minnesota jurisdictional portion of the costs incurred under the agreements from Minnesota retail customers, and whether to condition approval of the North Star and MEC BESS agreements on a requirement that Xcel demonstrate New Trade Measure Event costs are just and reasonable for ratepayers, among other considerations (Docket Nos. E002/RP-24-67; E002/CN-23-212). 

Additionally, on January 15, 2026, the MPUC considered adoption of a fuel life-cycle analysis framework as part of its responsibility to set criteria and standards for evaluating utility compliance with Minnesota’s Carbon-Free Standard (“CFS”). Therein, the MPUC determined that:

1. A fuel life-cycle analysis is the most appropriate methodology for assessing whether an electric resource is considered carbon free for compliance with the CFS statute. 
2. A fuel life-cycle analysis shall be used to determine whether the net emissions resulting from a technology or fuel used to produce electricity, over the fuel’s production and combustion cycle, is lower than the emissions that would result from the process most likely to occur (“the counterfactual”) in the absence of its use for electricity generation.
3. The integrated resource planning (IRP) process will continue to be the MPUC’s primary tool and process for selecting electric generating resources with consideration of reliability, resource adequacy, greenhouse gas emissions and associated externalities, and pollutants and other environmental impacts.
4. Primary biomass (intentionally cultivated for the generation of electricity) is not eligible for CFS compliance, but waste biomass is eligible for CFS compliance under certain circumstances.
5. Carbon capture and sequestration and storage systems are eligible for partial CFS compliance.
6. The Executive Secretary shall begin proceedings to establish a process to develop an accounting methodology for energy storage, including transmission interconnected large-scale energy storage resources.

The MPUC’s press release containing more detailed information about its decision is available here.  

PACIFIC NORTHWEST (OPUC, BPA, WUTC)

Oregon Public Utility Commission (OPUC)

On January 21, 2025, the OPUC held a special meeting regarding its investigation into marginal cost study treatment of costs for large customers and further modifications to Portland General Electric Company’s Rule C and Rule I (Docket No. UM 2377). The agenda for that meeting is here.  On January 22, 2026, the OPUC will hold a special public meeting regarding its process to identify priorities in implementation of Executive Orders 25-25 (Accelerating Wind and Solar Energy Development in Advance of Elimination of Federal Clean Energy Tax Credits, including directives to the OPUC) and 25-29 (Executive Order on Reducing Greenhouse Gas Emissions and Advancing Oregon’s Clean Energy Future, which identified goals and directives for the OPUC) (Docket No. UM 2417). The agenda for that meeting is here.

Bonneville Power Administration (BPA)

On January 21, 2026, BPA held its monthly Commercial Business Process Improvement (CBPI) customer call, including a systems status update. The agenda is here, and the CBPI webpage with more information is here.

Washington Utilities and Transportation Commission (WUTC)

On January 15, 2026, the WUTC held its open meeting to consider: (1) Cascade Natural Gas Corporation’s petition to deploy a Thermal Energy Network Pilot Project, pursuant to RCW 80.28.460(2)(a) (Docket No. UG-250456).

Federal Agencies

FEDERAL ENERGY REGULATORY COMMISSION (FERC)

January 2026 Commission Meeting

FERC noticed its January 2026 Commission meeting, which will take place on January 22, 2026 at 10:00 a.m. ET. FERC’s agenda may be found here.

Federal and State Current Issues Collaborative Meeting

FERC noticed its fourth Federal and State Current Issues Collaborative Meeting. The meeting will be held on February 11, 2026, from 1:00 p.m. to 3:30 p.m. ET, at the Westin Downtown Washington hotel in Washington, D.C. The meeting will be open to the public for listening and observing and will be on the record. The public may also attend via Webcast.

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

CALIFORNIA INDEPENDENT SYSTEM OPERATOR (CAISO)

Stakeholder Initiatives: Upcoming Meetings and Deadlines

2027 and 2031 Local Capacity Technical Study

The CAISO posted the 2027 and 2031 Local Capacity Technical Study base cases. Comments are due January 30, 2026. Access to the secure website may be requested after completing a non-disclosure agreement. More information can be found here.

Notification of revised ISO Operating Procedure 2720

The CAISO has revised and issued the operating procedures 2720A and 2720B. Specifically, operating procedure 2720 underwent a complete rewrite to simplify the steps for isolation, separation, and suspension during market disruptions. The CAISO’s operating procedures can be found here.

Congestion Revenue Rights Enhancements

The CAISO published the Issue Paper on revenue adequacy and auction efficiency for the Congestion Revenue Rights Enhancements initiative. Further, the CAISO hosted a hybrid stakeholder meeting on January 21, 2026, to discuss this paper and give stakeholders an opportunity to ask questions.

2024-2025 Transmission Planning Process Phase 3 Competitive Solicitation

The CAISO has posted a list of project sponsors whose applications are deemed qualified for the Northern Receiving Station – San Jose B 230 kV Line Project.  The CAISO will now initiate the selection process to determine which qualified project sponsor should finance, construct, own, operate, and maintain the transmission solution.

Draft CISO Balancing Authority Area Supplement to the Extended Day-Ahead Market (EDAM) Business Practice Manual

The CAISO has published a draft version of the CISO Balancing Authority Area Supplement to the EDAM Business Practice Manual - Attachment A.  Stakeholders are encouraged to submit comments by January 23, 2025.

Resource Adequacy Modeling and Program Design

The CAISO will hold a virtual public stakeholder meeting on January 26, 2026, to discuss Track 1 and 3A tariff amendments. The amendments aim to modernize RA data submission by strengthening the validation and mismatch-correction processes, updating Qualifying Capacity methodologies, and provide a more structured framework for RA procurement under Tracks 1 and 3A. The information to join the meeting is available here.

2027 Flexible Capacity Needs Assessment Process

The CAISO is conducting its 2027 flexible capacity needs assessment.  The data template is available for scheduling coordinators of load-serving entities to provide CAISO with the variable energy resources contract data needed for the study.  Scheduling coordinators were to submit this data by January 15, 2026.

Process Enhancements 5.0: Final Proposal Posted

The CAISO posted the final proposal for the Interconnection Process Enhancements 5.0 initiative and hosted a virtual stakeholder meeting on January 7, 2026.  The CAISO’s proposal would apply commercial viability criteria (CVC) to projects that request extensions to their commercial operation date and cause projects that cannot satisfy the CVC to be withdrawn from the queue.  Written comments were due by January 21, 2026. 

Congestion Revenue Rights Enhancements

CAISO has published a discussion paper on Congestion Revenue Rights Enhancements, available here. CAISO also published the related issue paper and straw proposal for this initiative.  CAISO hosted a virtual stakeholder meeting for this initiative on January 21, 2026, to discuss this paper and give stakeholders an opportunity to ask questions.  Written comments in response to questions identified throughout the issue paper are due February 4, 2026.  Further information is available here.

PJM INTERCONNECTION (PJM)

The White House and Governors in PJM States Urge PJM Tariff Revisions

The National Energy Dominance Council, which includes the Secretaries of the U.S. Department of the Interior and the U.S. Department of Energy, and the governors from Indiana, Maryland, Ohio, Pennsylvania, Virginia, West Virginia, Delaware, Illinois, Michigan, New Jersey, Tennessee, North Carolina, and Kentucky, issued a plan urging PJM to revise its tariff. The plan included suggested revisions that would provide 15-year price certainty for new capacity resources, extending the existing price collar to the next two base residual auctions at the current rate level; allocate costs to data centers; improve load forecasting; accelerate ongoing interconnection studies; and reform the capacity market. The governors further noted that they would use their authority to allocate costs to data centers and protect residential customers.

PJM Outlines Framework to Address Large Load Growth

The PJM Board of Managers outlined its plan to address large load growth through its Critical Issue Fast Path process. The board notes that the following are the primary components of its plan:

• Improvements to load forecasting
• Frameworks in which large loads and states bring their own incremental generation to offset their load additions
• Connecting and managing large load additions that do not bring their own generation and curtailment prior to emergency demand response when necessary to load shed
• Immediate initiation of reliability backstop procurement
• Holistic reviews of investment incentives in PJM’s markets in 2026
• Feedback requests on price collar for 2028/2029 and 2029/2030 capacity auction

PJM 2026 Load Forecast Report

PJM published its 2026 Load Forecast Report, which includes a 20-year long-term forecast of peak loads, net energy, load management, distributed solar generation, plug-in electric vehicles and battery storage. PJM notes that its 2026 Long-Term Load Forecast is lower than its 2025 Long-Term Load Forecast in the near term through 2032 because of updates to electric vehicle forecasts, economics, and large load adjustments.

Markets and Reliability Committee and Members Committee Meetings

PJM’s Markets and Reliability Committee and Members Committee will meet on January 22, 2026. Included in the agenda are proposed revisions to PJM’s Regional Transmission and Energy Scheduling Practices, Transmission Service Requests, Rules and Procedures for Determination of Generation Capability, and increasing the minimum capitalization requirements to participate in its markets.

NEW YORK INDEPENDENT SYSTEM OPERATOR (NYISO)

Quarterly Assessment of Reliability

NYISO published its quarterly short-term assessment of reliability for Quarter 4 of 2025. The report identified reliability violations in New York City and Long Island beginning in the summer of 2026, noting that violations are driven by generator deactivations, increasing demand, and transmission limitations. The report also notes that the delayed completion of offshore wind projects could cause additional issues related to the reliability violations.

ISO NEW ENGLAND (ISO-NE)

Capacity Auction Reform Framework

ISO-NE presented a framework to evaluate the effects of its proposed Capacity Auction Reforms (CAR)—Seasonal and Accreditation to show potential impacts of its CAR proposal. ISO-NE will assess through studies the effects of seasonal capacity products and revised resource accreditation rules on resource obligations, system reliability, capacity prices, and market costs to provide stakeholders a better understanding of how CAR may impact how much capacity may be sold.

SOUTHWEST POWER POOL (SPP)

FERC Approves SPP Large Load Tariff Revisions

FERC approved SPP’s proposed revisions to its tariff, which address the rapid growth of large load, by adding a High Impact Large Loads (HILL) study process and High Impact Large Load Generation Assessment (HILLGA) process.

HILL establishes a new study process that imposes enhanced technical studies and ongoing operational requirements on large loads, which include system impact analyses and heightened study deposits to discourage speculative requests. HILLGA will serve as an optional, expedited interconnection pathway for generation built specifically to serve HILLs. HILLGA introduces a new, limited form of interconnection service—Load Limited Resource Interconnection Service—that restricts a generator’s output to match the associated load and expires after five years.

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

[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.