The Reliable Power Act amends Section 215 of the Federal Power Act to require the Electric Reliability Organization (ERO) to produce an annual long‑term assessment of the bulk‑power system’s ability to supply sufficient electric energy, including analyses of generation mix, transmission development, demand trends, and risks under normal and extreme weather. If the ERO concludes the system faces inadequate generation, it must publicly notify the Federal Energy Regulatory Commission (FERC), which in turn must notify DOE, EPA, and other relevant agencies.
Once notified, those federal agencies must submit any “covered agency action” — rulemakings under development that directly affect generation resources — to FERC for review and comment at the point the rule is sent to OMB or at least 90 days before publication. FERC must consult the ERO and transmission organizations, provide written comments and recommended modifications aimed at preventing significant negative impacts on energy supply, and may assess effects on rates under FPA sections 201 and 206.
Agencies may not finalize the rule until they respond in writing to FERC’s comments and FERC finds the action will not likely cause a significant negative impact on generation adequacy. This creates a formal interagency review tied to a reliability determination and procedural gates for agency rulemakings that touch generation.
At a Glance
What It Does
Requires the ERO to perform an annual long‑term assessment of generation adequacy and to notify FERC if it finds a risk of inadequate generation; creates a mandatory FERC review process for certain agency rulemakings that affect generation resources. FERC will provide comments and recommended modifications, and agencies cannot finalize covered rules until they respond and FERC finds no likely significant negative impact.
Who It Affects
Directly affects federal agencies developing regulations that relate to generation resources (notably DOE and EPA), the ERO, FERC, transmission organizations, and entities that own or operate generation and bulk‑power grid infrastructure. It also impacts market participants whose operations or permitting are influenced by interagency rulemaking timing.
Why It Matters
This bill inserts reliability review into the federal rulemaking pipeline for regulations that touch generation supply, effectively giving FERC a formal cross‑cutting review role during development of covered rules and a de facto check before finalization when a generation inadequacy has been declared.
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What This Bill Actually Does
The bill makes two linked changes to Section 215 of the Federal Power Act. First, it expands the ERO’s assessment obligations by adding an annual long‑term assessment focused on whether the bulk‑power system can supply enough electric energy over an assessment period.
That assessment must analyze generation resource mix, transmission development, demand trends, and the risk of supply shortfalls under normal and extreme weather; it must also state whether additional generation is needed. The ERO can collect data from grid users, owners, and operators to support that analysis.
Second, the bill creates a triggered interagency review when the ERO notifies FERC that the system is at risk of generation inadequacy. Upon such notice, FERC must alert DOE, EPA, and other agencies.
Any agency developing a regulation that directly affects generation resources and is under consideration at the time of notice — a “covered agency action” — must be submitted to FERC for review either when it goes to OMB or at least 90 days before public publication. The timing hooks tie FERC’s input to existing points in the rulemaking calendar, not after-the-fact challenges.FERC must consult the ERO and transmission organizations before issuing an order with comments and, if appropriate, recommendations to modify the agency rule to prevent significant negative impacts on the bulk‑power system’s ability to supply energy.
Those comments may include assessments of effects on rates and terms under FPA sections 201 and 206. An agency may not finalize a covered action until it files a written response explaining any changes or why it declined to change, and until FERC finds the action will not be likely to cause a significant negative impact.
The agency must include the back‑and‑forth in the administrative record and when publishing the rule, making the exchange public.
The Five Things You Need to Know
The ERO must publish an annual long‑term assessment that analyzes generation mix, transmission development, demand trends, weather‑driven shortfall risk, and whether new generation is needed.
If the ERO concludes there is a generation inadequacy, it must publicly notify FERC, which then alerts DOE, EPA, and other relevant federal agencies.
An agency developing a regulation that directly affects generation resources and is under consideration at the time of FERC notice must submit that draft rule to FERC when sent to OMB or at least 90 days before publication for FERC review and comment.
FERC must consult the ERO and transmission organizations and may recommend modifications to the draft regulation to avoid a significant negative impact on the bulk‑power system; FERC’s comments may address impacts on rates under FPA sections 201 and 206.
Agencies cannot finalize covered rules until they provide a written response to FERC explaining any modifications or why they declined to modify the rule, and until FERC finds the final action will not likely have a significant negative impact on energy supply.
Section-by-Section Breakdown
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Annual long‑term assessment and data authority
This part directs the ERO to add an annual long‑term assessment to its existing reliability assessments, specifying the analytical elements required (generation mix, transmission development, demand trends, and shortfall risk under normal and extreme weather). Practically, it elevates forward‑looking, energy‑centric analysis (not just instantaneous resource adequacy) and authorizes the ERO to collect information from users, owners, and operators to support that analysis — a potentially significant new data‑collection duty for entities that submit operational and planning data to the ERO.
Public notification to FERC when adequacy is at risk
If the long‑term assessment shows a risk of inadequate generation, the ERO must publicly notify FERC that the bulk‑power system is in a state of generation inadequacy. That public notice both triggers the interagency process in the next subsection and creates a formal, publishable factual predicate that agencies and stakeholders can point to when justifying or challenging regulatory choices.
FERC alerts agencies; agencies must submit draft rules
Once FERC receives the ERO notice, it must promptly notify DOE, EPA, and other agencies it deems appropriate. Agency heads who receive notice must submit any covered agency action — defined as regulations under development that directly affect generation resources and already under consideration — to FERC either on the first date they send the draft to OMB or no later than 90 days before publication. That creates two concrete timing hooks tied to common stages in federal rulemaking (OMB review and pre‑publication), which agencies will need to track when a generation inadequacy has been declared.
FERC comment authority and procedural gate for finalization
FERC must, by order and in consultation with the ERO and transmission organizations, provide comments and if applicable recommend changes to prevent significant negative impacts on the bulk‑power system’s ability to supply energy. Agencies may not finalize the rule until they respond in writing to FERC explaining any changes or why none were made and until FERC finds the action will not likely have a significant negative impact. The bill requires agencies to include FERC’s comments and the agency’s response in the Federal Register publication or other public rulemaking materials, making the exchange part of the public administrative record.
Narrow definition of covered actions and federal agency scope
The bill limits its reach to ‘‘covered agency actions’’ — regulations that relate to or directly affect generation resources and are already under development at the time of notice — and confines ‘‘federal agency’’ to Executive departments and cabinet agencies. This narrows the universe of regulations subject to the process, but leaves open judgment calls about what counts as ‘‘relates to, or otherwise directly affects, any generation resource,’’ which will be central in practice.
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Explore Energy in Codify Search →Who Benefits and Who Bears the Cost
Every bill creates winners and losers. Here's who stands to gain and who bears the cost.
Who Benefits
- ERO and reliability planners — gain a statutory mandate and data authority to perform forward‑looking energy adequacy analysis, improving their ability to identify regional shortfall risks and to press for corrective actions.
- FERC — acquires a formal role in reviewing agency rulemakings that could affect generation adequacy, giving it a clearer institutional pathway to influence rules that intersect with grid reliability and to raise rate‑impact concerns under FPA sections 201 and 206.
- Transmission organizations and regional planners — receive structured input and an authoritative assessment to support transmission and resource planning decisions, and a mechanism to surface reliability risks to federal agencies.
- Consumers in at‑risk regions — may indirectly benefit if the process speeds identification of generation shortfalls and prompts corrective regulatory or investment actions to avoid outages.
Who Bears the Cost
- EPA, DOE, and other cabinet agencies — must add FERC review into rulemaking timelines, prepare additional materials for FERC, and potentially revise rules in response to reliability recommendations, creating extra workload and possible delays.
- Federal rulewriters and OMB — will need to track ERO/FERC notices and may face compressed or shifted timelines to meet the submission hooks (first OMB submission or 90‑day prepublication), complicating coordination between OMB review and interagency input.
- FERC and the ERO — bear resource and staffing burdens to conduct the annual long‑term assessment, to review multiple agency rulemakings, consult transmission organizations, and issue orders and findings on likely impacts.
- Regulated industries (generation owners, developers, and project proponents) — may see longer approval timelines for rules that affect permitting, emissions, or market rules, and face increased uncertainty as FERC recommendations could require rule changes that affect project economics.
Key Issues
The Core Tension
The bill forces a trade‑off between safeguarding near‑term energy supply (by giving FERC and the ERO a formal checkpoint over rules that could reduce generation) and preserving agencies’ ability to pursue public‑interest regulations (such as environmental or health rules) on their own timelines; it delegates more preventive authority to reliability actors but does so without clear standards or timelines, risking either regulatory paralysis or inadequate safeguards depending on how the balance is drawn.
Several implementation questions and trade‑offs are unresolved. The statute does not define ‘‘generation resource’’ beyond the plain text, nor the temporal scope of the ‘‘assessment period,’’ leaving room for dispute about whether demand response, storage, and certain distributed resources count as generation for the statute’s purposes.
Those definitional gaps will determine how broadly agencies must submit rules and how the ERO models adequacy.
The bill creates a procedural gate: an agency cannot finalize a covered rule until it explains its response and FERC finds there is no likely significant negative impact. The statute lacks a defined standard for ‘‘likely’’ or ‘‘significant negative impact,’’ and it does not prescribe a deadline for FERC to make that finding.
That combination could allow FERC to delay finalization effectively or provoke litigation over what constitutes adequate factual findings. The requirement to include FERC comments and agency responses in the Federal Register increases transparency but may also politicize the administrative record and invite procedural challenges under the Administrative Procedure Act.
Finally, the ERO’s expanded data collection authority raises confidentiality and commercial sensitivity issues. Entities may resist new data requests or claim privilege for market‑sensitive information, and there is no funding mechanism in the text to scale ERO or FERC analytical capacity.
Those practical limits — data access, staffing, and definitional disputes — will shape whether the statutory process speeds corrective action or simply adds another layer of interagency friction.
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