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In the United States, a utility-scale battery project does not have one nationwide permit checklist. Developers generally need to pursue local land-use and construction approvals, screen for environmental permits triggered by the site and its impacts, and separately complete the grid interconnection process with the relevant transmission provider or utility. The exact requirements depend on the project’s location, design, land status, and point of interconnection.
What permits do I need for a utility-scale battery project?
Start by identifying the state, county and municipality; the parcel and who owns it; the project’s size and configuration; and the proposed point of interconnection. Those details determine which authorities have jurisdiction and which approvals are actually triggered. A standalone battery and a battery co-located with another facility may face different land-use, environmental and interconnection questions.
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Most projects should screen four workstreams in parallel. These are a framework, not a guarantee that every item applies:
- Land use and siting: Check zoning, permitted-use rules, conditional-use approval, site-plan review, setbacks, access, noise, lighting, visual screening and decommissioning requirements. A state energy-facility siting or environmental review process may supplement or, in some circumstances, alter the local process.
- Construction and safety: Ask the local authority having jurisdiction (AHJ) which building, electrical and fire codes it has adopted, what permits and inspections apply, and what documentation it requires for the proposed system. The applicable requirements depend on local code adoption and project design.
- Environmental and resource review: Screen the site and construction footprint for wetlands and waters, stormwater, floodplains, protected species and habitat, cultural and historic resources, contaminated-site obligations, and state or federal environmental review. A permit from the U.S. Army Corps of Engineers (USACE) may be required for certain work affecting waters within its jurisdiction; it is not automatic for every battery project.
- Grid interconnection: File a separate interconnection request with the applicable transmission provider, regional transmission organization or independent system operator (RTO/ISO), or utility. The process can include readiness demonstrations, studies, agreements, assigned network upgrades and testing before operation.
These tracks involve different decision-makers and can proceed on different schedules. A land-use approval does not grant permission to connect to the grid, and an interconnection request does not establish that a site is allowed under local zoning.
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Who approves each part of the project?
| Authority | What it may decide | What determines whether it is involved |
|---|---|---|
| Local government | Zoning, conditional-use approval, site plans, setbacks, access and other local land-use conditions. | The parcel’s jurisdiction, local ordinances and project characteristics. |
| Local AHJ, including building and fire officials | Applicable construction permits, code review, inspections and fire-safety requirements. | Locally adopted codes, the system design and the AHJ’s jurisdiction. |
| State agencies | Depending on the state, energy-facility siting, environmental review, wetlands or water, wildlife, cultural-resource or other approvals. | State law, agency authority, project thresholds and site impacts. |
| Federal agencies | Approvals tied to a specific federal permit, land, funding, action or other federal jurisdiction. USACE, for example, administers permits for certain activities in regulated waters and wetlands. | The specific federal connection and the proposed activity or impacts. |
| FERC and the transmission provider | The applicable transmission interconnection framework for public utilities, administered through the relevant tariff and provider procedures. | The point of interconnection, transmission provider and governing tariff. |
FERC’s federal transmission-siting authority is a separate, narrow process. It applies to qualifying electric transmission facilities in Department of Energy-designated National Interest Electric Transmission Corridors under specified circumstances; it is not a general siting permit for a battery plant. FERC says state siting continues to cover most transmission projects.
How do I connect a battery storage project to the grid?
For a project seeking to inject electricity into the transmission system, a grid-scale battery enters the generator-interconnection framework. Its ability to draw electricity while charging also matters to system studies. The applicable tariff and project-specific studies control the detailed sequence, costs, schedule and operating rights.
- Identify the proposed point of interconnection and provider. Determine which transmission provider, RTO/ISO or utility serves that point and which tariff and queue procedures apply.
- Establish project readiness and submit the request. Meet the provider’s filing, financial and site-control requirements. Requirements should be checked in the current tariff and request documents rather than assumed from a general summary.
- Complete the required studies. Participate in the provider’s system-impact and facilities studies. Study scope and results inform whether network upgrades are needed and how the project may connect and operate.
- Negotiate the agreement and address assigned upgrades. Execute the required interconnection agreement and fund or otherwise meet obligations for network upgrades assigned to the project under the governing process.
- Complete testing and obtain authorization to operate. Follow the provider’s requirements before the battery begins grid operation.
What FERC Order No. 2023 changes
FERC issued Order No. 2023 in July 2023. It requires public utilities to adopt revised pro forma generator interconnection procedures and agreements, including first-ready, first-served cluster studies, financial and site-control readiness requirements, and study assumptions that account for storage charging behavior. Order No. 2023-A, issued March 21, 2024, clarified and modified parts of the rule. A live project should use the provider’s current tariff and controlling rule text because the applicable procedures and project circumstances matter.
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FERC’s Order No. 2023-A explainer summarizes site-control thresholds as 90% when submitting an interconnection request and 100% at execution of the facilities study agreement. It describes a deposit alternative only where regulatory limitations may prevent timely demonstration of site control; in that case, the customer must obtain site control within 180 days after completing the study process and executing an interconnection agreement. These are rule-summary details to verify against the current tariff and the circumstances of the request.
How to interpret interconnection-queue wait figures
Queue figures are snapshots, not project-specific schedule estimates. FERC reported more than 2,000 GW of energy resources waiting in interconnection queues at the end of 2022. In a September 25, 2024 article, FERC described wait times longer than five years and said the average project then needed would not begin construction until 2029. That statement describes conditions FERC was discussing in 2024; it is not a 2026 forecast for an individual project.
Does FERC approve battery storage projects?
Not through a single general battery-project siting permit. FERC’s role relevant to many transmission-connected projects is the interconnection framework for public utilities, implemented through the applicable provider’s tariff and procedures. Local and state authorities handle the land-use, construction, safety and other approvals within their jurisdiction; federal agencies become involved when a particular federal jurisdiction, action, land, funding or permit is implicated.
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FERC’s special transmission-siting process concerns qualifying transmission facilities in designated corridors under specified conditions, not the ordinary siting of a battery facility. If a federal agency action is involved, environmental review under the National Environmental Policy Act (NEPA) may apply to that federal action. A privately developed battery project does not trigger blanket NEPA review solely because it is a battery project.
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That depends on the parcel’s zoning designation, local ordinance and project details. A locality may allow the use by right, require a conditional-use approval or site-plan review, restrict battery facilities to certain zones, or apply size-based requirements. The absence of a battery-specific provision does not by itself settle which general zoning rules apply.
Review the local code for provisions concerning:
- Allowed zones, use classifications, conditional-use or special-use approvals, and project-size tiers.
- Setbacks, site access, landscaping or visual screening, lighting and noise.
- Emergency planning, fire response, decommissioning and any required financial assurance.
- Building, electrical, fire-code and inspection requirements administered by the AHJ.
Local rules vary substantially. PNNL’s 2023 report describes safety, visual, auditory and environmental impacts among local land-use concerns. Its 2026 report notes variation in ordinance detail and that some jurisdictions lack BESS-specific code language. Engage the planning office and local fire authority early to establish how the ordinance and adopted codes apply to the proposed design.
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Which environmental permits or reviews might apply?
Environmental approvals depend on site conditions, construction methods and impacts; a project should not assume that every review below is required, or that none is. Screen the full footprint, access roads, grading and related construction for:
- Wetlands, streams and other waters, including whether proposed work falls within USACE jurisdiction.
- Grading, erosion control, construction stormwater and floodplain constraints.
- Protected species, habitat, cultural and historic resources, and state environmental-review thresholds.
- Contaminated-site status, as well as applicable air and noise requirements.
EPA guidance emphasizes state and local siting, zoning, marking and permitting requirements, as well as fire-response planning and cleanup. Its BESS incident-response guidance identifies fire suppression, emissions, environmental impacts from damaged-battery cleanup and coordination for incident response as concerns. The local code and AHJ determine which particular plans, designs or evidence are required; no single fire standard should be assumed to apply everywhere.
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How should a developer compare possible sites or grid connections?
Where more than one location or point of interconnection is plausible, compare them using the same project assumptions. A site with fewer apparent land constraints may still have a difficult queue position or costly upgrades, while a promising grid location may create local siting or environmental challenges.
- Approval path: Identify the governing authorities and likely local, state and federal reviews for each alternative.
- Grid path: Compare queue status, study scope and estimated network upgrades, while treating cost and schedule as uncertain until provider studies and agreements establish them.
- Site control: Check whether the project can meet the applicable readiness and site-control milestones.
- Site impacts: Compare environmental constraints, required mitigation, emergency response considerations and local zoning conditions.
- Execution risk: Assess schedule and cost uncertainty alongside community conditions and the work needed to obtain approvals.
What information is needed to build a project-specific approval map?
Before treating any checklist as complete, assemble the details that determine jurisdiction and study scope:
- State, county, municipality, parcel and land ownership or control.
- Project power and energy capacity, battery chemistry, and whether the system is standalone or co-located.
- Proposed point of interconnection, transmission provider or utility, and intended market or operating model.
- Current land-use designation, site constraints and known environmental resources.
- Construction footprint, access needs and the proposed system design.
Then verify requirements with the local planning authority and AHJ, relevant state siting and environmental agencies, USACE district if regulated waters may be affected, and the transmission provider’s current tariff and queue documents. FERC Chairman Willie Phillips said in a September 25, 2024 FERC article: “Connecting new resources to the grid quicker and more efficiently is key to more reliable, resilient, and affordable electricity for everyone.” The procedural details for any individual project still come from the authorities and provider governing its location and interconnection.
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