The projects going up fastest in the US right now aren't solar farms — they're battery storage facilities, often sitting next to solar installations or on land that never would have supported one. The EIA projects 24 GW of new utility-scale battery storage will come online in 2026, nearly double the 15 GW added in 2025. Texas alone accounts for 12.9 GW of that.
Battery energy storage systems look deceptively similar to solar from the road: fenced industrial parcels, rows of containers, a substation connection. But the land that qualifies for solar and the land that qualifies for battery storage are often not the same land, and the criteria that separate them are worth understanding before a developer comes calling.
Two Very Different Projects
Most large battery projects currently going up in the US are co-located with solar — the battery sits on the same site as the panels, charges from the array during daylight hours, and dispatches power to the grid during peaks or overnight. This model needs the same large footprint as a solar farm, 400 acres or more, and the land has to qualify for both technologies simultaneously.
Standalone projects are a different situation entirely. They aren't connected to any generation source — they charge directly from the grid during low-price periods and discharge during peaks, capturing the price spread. ERCOT in Texas and CAISO in California have the electricity price volatility that makes this model work. A standalone battery developer isn't looking for acres of open land with good sun exposure. They want a small site — often 5 to 20 acres — within a short distance of a high-capacity substation, and the solar resource is irrelevant.
A co-located project and a standalone project share almost nothing beyond the battery containers themselves. If a developer contacts you about a battery storage project, the first useful question is which one they're building.
What Carries Over from Solar
Both technologies need flat terrain, grid access, and land outside wetlands and active floodplains. FEMA Zone AE designation — active floodplain — eliminates a parcel regardless of whether the project is panels or battery containers, since elevated flood risk affects both insurability and project financing.
The slope threshold both share is roughly 5% grade. Above that, site prep costs escalate for different reasons: solar arrays need consistent drainage and panel orientation; battery containers need stable, compacted ground to prevent equipment stress and meet drainage requirements tied to fire suppression systems.
The filters that determine what makes land viable for a solar farm — wetlands overlays from the NWI, conservation easements, proximity to protected areas in PAD-US — apply to BESS as well. A parcel that fails these screens for solar fails them for storage too.
No Sun Required
Beyond those shared filters, the criteria diverge. Battery storage has no irradiance requirement. A parcel facing the wrong direction, shaded by terrain, or sitting in a region with mediocre solar resource can still host a viable battery project, as long as the grid access is there.
This opens up land that wouldn't make a solar developer's list. North-facing hillsides, shaded valleys, parcels in the Pacific Northwest with strong transmission infrastructure — all potentially viable for storage. The constraint set shifts rather than shrinks: irradiance drops out, and substation proximity becomes the filter that does most of the work.
Substation Proximity: Tighter Than Solar
Solar developers get uncomfortable with substation distances beyond two to three miles because the cost of building a new grid connection scales with distance. Battery developers tend to draw the line closer.
Most standalone BESS projects are sited within one kilometer — about 0.6 miles — of a viable substation. The reason comes down to how battery storage earns money: rather than generating power steadily over daylight hours the way a solar farm does, a battery charges and discharges in concentrated windows, often responding to grid conditions within minutes. That speed and reliability degrade with line distance in ways that affect project revenue directly.
The substation also has to be able to handle the project's output pattern. A battery that can release 100 MW within minutes needs a substation capable of absorbing that rapid burst without destabilizing local grid voltage. Developers commission engineering studies to confirm this before signing a lease — if the substation can't handle it, the project doesn't work regardless of how close the land is.
For standalone projects, substation proximity is the filter that eliminates the most candidate sites, ahead of acreage, terrain, or zoning. A parcel that clears everything else but sits two miles from the nearest usable node is very difficult to make work.
How Much Land
Battery storage requires substantially less land than solar, which is part of why it can work on parcels too small for a utility-scale solar project.
A rough industry benchmark is about 1,000 square feet of footprint per MWh of storage capacity. A 100 MWh project — a mid-size standalone installation — needs roughly 2.3 acres for the battery containers themselves. Total site area, including the transformer yard, access roads, setback buffers, and perimeter fencing, typically runs between 5 and 20 acres depending on project design and local codes.
| Project type | Typical land need | Primary siting constraint |
|---|---|---|
| 100 MW utility-scale solar | 400–600 acres | Irradiance, substation proximity, grid capacity |
| 100 MWh standalone BESS | 5–20 acres | Substation proximity and grid capacity |
| Co-located solar + BESS | 400–600 acres (shared) | Both irradiance and two-way grid capacity |
The smaller footprint means it's easier to find a qualifying parcel by size alone. It also means the total annual lease payment is smaller — which matters when a developer's per-acre offer looks competitive but the actual check doesn't reflect that.
Zoning: Check County Code Before Assuming
Agricultural zoning that accommodates a solar farm does not automatically accommodate a battery storage project, and the gap between the two catches a lot of landowners off guard.
Solar farms have worked their way into agricultural zoning districts across the US through Special Use Permits and conditional use approvals. Battery storage tends to get classified differently — as industrial infrastructure. Some counties that permit solar without friction require an industrial zone designation for BESS, which eliminates most agricultural parcels before anything else is evaluated.
This isn't uniform. Some jurisdictions have updated their codes to treat battery storage similarly to solar; others haven't touched their ordinances since utility-scale BESS wasn't yet a realistic technology. In 2024, the American Planning Association published zoning guidance specifically for battery energy storage systems, and a growing number of counties have since adopted dedicated BESS permit pathways. Adoption is uneven enough that the zoning classification needs to be confirmed at the county level for any specific parcel — not inferred from how nearby solar projects were handled.
Fire Codes and the Permitting Timeline
Battery containers carry a fire risk that solar panels don't. Lithium-ion cells can enter a condition called thermal runaway under certain failure scenarios, generating intense heat and toxic gases. Local fire codes — most commonly drawing from NFPA 855, the national standard for stationary energy storage systems — govern how battery projects must be laid out: spacing between containers, fire suppression systems, access road dimensions for emergency vehicles, and minimum clearance from property lines and other structures.
Most jurisdictions applying the NFPA 855 framework require buffer zones of 10 to 20 meters between battery containers and property lines, access roads, and other structures on the site. Some also impose noise limits, since the cooling systems that keep battery containers within operating temperature run continuously, not just during business hours.
Permitting a BESS project tends to take longer than solar. Counties reviewing their first battery application sometimes add steps that stretch the timeline by months. It rarely stops a project outright, but it's a real variable in the development schedule and affects how developers think about site risk when they're choosing between candidate parcels.
Lease Rates
BESS lease rates don't have the same established benchmarks as solar. The technology has scaled fast enough that the leasing market hasn't produced enough publicly reported transactions to establish a reliable range.
BESS developers pay well for substation-adjacent land because it's scarce. A small parcel within a kilometer of a high-capacity substation in a volatile electricity market commands a different conversation than comparable agricultural land nearby. Land brokers active in this space report per-acre rates that tend to run close to local solar rates — but the total payment is smaller because the footprint is smaller, and that's the number that matters when evaluating whether a BESS lease makes financial sense.
A developer offering $1,800/acre on 8 acres is a structurally different deal from a solar offer at the same rate on 300 acres, even though the per-acre number is identical. The total payment, the lease term, and what happens to the land's agricultural use during that term are the variables worth negotiating around.
Sunnyplans maps parcel-level grid proximity and constraint data across US states — if you're trying to understand whether a specific site clears the filters developers run before making contact, the substation distance and SunnyScore on each listing is a reasonable starting point.