FERC Updates Data Rules for Reliable Power Grid Operations
Published Date: 12/23/2025
Notice
Summary
FERC is updating the rules for how certain energy companies report important data to keep the power grid safe and reliable. These changes affect generator owners, operators, and transmission folks who must follow new reporting steps. Comments on these updates are due by February 23, 2026, so get ready to share your thoughts and stay in the loop!
Analyzed Economic Effects
7 provisions identified: 0 benefits, 7 costs, 0 mixed.
New frequency‑response paperwork (BAL-001-TRE-2)
Category 2 generator owners and operators must now follow BAL-001-TRE-2 Requirements R6 through R10 (governor parameter responsiveness and notifications) and R8 (service status notifications to the balancing authority). FERC estimates this standard will add a total of 332 annual hours and $21,088.64 in costs across 53 respondents under FERC-725T.
Reliability coordinator data reporting (IRO-010-5)
Category 2 generator owners and operators must meet IRO-010-5 Requirement R3 to provide the reliability coordinator with the documented specifications of data and information needed for operational planning, real‑time monitoring, and real‑time assessments. The filing estimates this standard will require 6,408 annual hours and $407,036.10 in total costs across 801 respondents under FERC-725Z.
Power‑system modeling data reporting (MOD-032-1)
Category 2 generator owners must provide modeling data and address planning coordinator or transmission planner concerns under MOD-032-1 Requirements R2 and R3 to support planning horizon cases. FERC estimates this standard will require 9,820 annual hours and $623,766.40 in total costs across 491 respondents under FERC-725L.
Remedial Action Scheme testing and maintenance (PRC-012-2 & PRC-017-1)
Category 2 generator owners that are part of a Remedial Action Scheme (RAS) must follow PRC-012-2 Requirements R1, R3, and R5–R8 (information review, testing, performance analysis, corrective actions) and PRC-017-1 Requirements R1 and R2 (maintain and document maintenance and testing programs). FERC estimates these PRC standards will add 39,280 annual hours and $2,495,065.60 in total costs across 982 respondent actions under FERC-725G.
Transmission operator/balancing authority data obligations (TOP-003-6.1)
Category 2 generator owners and operators must satisfy TOP-003-6.1 Requirement R5 by providing data and information specified by the transmission operator or balancing authority for operational planning, real‑time monitoring, and real‑time assessments. FERC estimates this standard will require 6,408 annual hours and $407,036.16 in total costs across 801 respondents under FERC-725A.
Voltage and reactive control reporting & operation (VAR-001-5 & VAR-002-4.1)
Category 2 generator owners and operators (including WECC entities) must meet VAR-001-5 Requirements E.A.15 and E.A.17 (voltage set point conversion methodologies and control loop specs) and VAR-002-4.1 Requirements R1–R4 (automatic voltage control, maintaining voltage schedules, notifications) plus R5–R6 (tap settings and data). FERC estimates these VAR standards will require 12,816 annual hours and $814,072.32 in total costs across respondents under FERC-725X.
Definitions expanded to include Category 2 IBRs
If you own or operate non‑BES inverter‑based resources that have or contribute to an aggregate nameplate capacity of greater than or equal to 20 MVA and are connected through a system designed primarily to deliver that capacity to a common point at a voltage greater than or equal to 60 kV, you are now defined as a Generator Owner or Generator Operator (Category 2). That change in the NERC Glossary makes those Category 2 entities subject to applicable mandatory Reliability Standards.
Your PRIA Score
Personalized for You
How does this regulation affect your finances?
Sign up for a PRIA Policy Scan to see your personalized alignment score for this federal register document and every other regulation we track. We analyze your financial profile against policy provisions to show you exactly what matters to your wallet.
Key Dates
Department and Agencies
Related Federal Register Documents
2026-11881 — Venture Global CP2 LNG, LLC, Venture Global CP Express, LLC; Notice of Application and Establishing Intervention Deadline
Venture Global CP2 LNG and CP Express want to expand their LNG export terminal in Louisiana and the pipeline from Texas to Louisiana. This big project will boost LNG export capacity by 11.7 million tonnes per year and add pipeline capacity for 1,900 million cubic feet daily, costing about $826 million. If you’re interested, you’ve got until the intervention deadline to speak up or get involved!
2026-11880 — Rio Grande LNG Train 6, LLC; Notice of Application and Establishing Intervention Deadline
Rio Grande LNG Train 6, LLC wants to expand its Texas LNG terminal by adding a new liquefaction train and marine jetty, boosting production by over 6 million tonnes per year and allowing more LNG ships to dock. This means more energy and business for the area, but folks have a deadline to speak up or get involved. The project is moving fast, so keep an eye on the clock and your calendars!
2026-11846 — Combined Notice of Filings
The Federal Energy Regulatory Commission is reviewing new and updated natural gas pipeline rate filings that could change how much customers pay starting as soon as July 1, 2026. Pipeline companies like DCP Guadalupe and Transcontinental Gas are asking for rate changes or corrections, and the public has until late June or early August to share their thoughts. These updates affect energy companies and customers who rely on natural gas, with some changes already effective or coming soon.
2026-11879 — Northern Natural Gas Company; Notice of Application and Establishing Intervention Deadline
Northern Natural Gas Company wants to build new pipelines and a compressor station in New Mexico and Texas to boost gas delivery to a power plant and improve their system’s reliability. The project will cost about $105 million, and they’re asking to include these costs in their regular rates. If you’re interested, you need to act before the deadline to get involved in the decision.
2026-11878 — California Department of Water Resources; Notice of Availability and Adoption of Final Environmental Assessment
The California Department of Water Resources has shared its final environmental assessment, which looks at how a new water project might affect the environment. This update mainly impacts local communities and water users by ensuring the project is safe and eco-friendly. The assessment is now official, so the project can move forward without delays or extra costs.
2026-11782 — Combined Notice of Filings
The Federal Energy Regulatory Commission got several new filings about natural gas pipeline rates and refunds from companies like NextEra Energy and ETC Tiger Pipeline. These filings could change how much customers pay starting as soon as June or July 2026. If you want to speak up or get involved, you need to act before the deadlines in mid to late June.
Previous / Next Documents
Previous: 2025-23709 — Avista Corporation; Notice of Intent To Prepare an Environmental Assessment
Avista Corporation plans to fix the spillway gates at the North Channel Dam on the Spokane River, affecting parts of Washington and Idaho. They’ll replace the gates without changing how the dam works or its environment, with only short-term construction impacts expected. The government will review the project and share an environmental report by April 10, 2026, inviting public feedback before making a final decision.
Next: 2025-23711 — Columbia Gulf Transmission, LLC; Notice of Scoping Period Requesting Comments on Environmental Issues for the Proposed Pulaski Project
Columbia Gulf Transmission wants to build new gas facilities in Lincoln and Pulaski Counties, Kentucky, and the government is asking the public for their thoughts on how this might affect the environment. People have until January 20, 2025, to share their ideas and concerns, which will help decide if the project moves forward. This is a big deal for local communities and could impact the area’s environment and energy future.