Most landowners who receive a solar lease offer assume the developer found them through a broker or a mailing list. In reality, the developer ran your parcel through a filtering process before they ever called — and the same filters that got you on their list will determine the terms they offer.
Grid Proximity Is the Dominant Variable
Every kilowatt-hour a solar farm produces has to travel through transmission infrastructure to reach customers. The cost of getting it there — the interconnection cost — falls on the developer, not the grid operator. That cost scales with distance.
A parcel two miles from a high-capacity substation might support a viable project. The same parcel ten miles away may not, even if everything else is identical. Developers run interconnection cost estimates early in their screening process because a bad number there ends the evaluation regardless of how good the land looks otherwise.
What matters isn't just distance — it's the capacity available at the nearest substation. A substation that's already near its hosting capacity creates a long, expensive queue for new interconnection applications, even if it's physically close. Developers check the substation's available capacity, the voltage level of the connected transmission lines, and whether the local utility has a history of approving interconnection requests at a reasonable pace.
Parcel Size and Shape
Utility-scale solar projects — those feeding power directly into the grid — typically require a minimum of 40 to 100 acres of usable land. Community solar projects, which are smaller and serve local subscribers, can work with 5 to 30 acres in the right markets.
But acreage alone isn't the number developers care about. It's contiguous usable acreage — the portion of the parcel that can actually hold panels after removing setbacks, slopes, wetlands, and other constraints. A 200-acre parcel with a creek running through the middle, a tree buffer along the road, and a 15-acre wetland in the northeast corner might yield 120 acres of buildable land. That's the number that drives the project economics.
Irregular or fragmented shape creates installation inefficiencies and fencing costs. Developers prefer parcels that allow clean rectangular or trapezoidal panel arrays. A nearly square parcel is worth more per acre than a long, narrow strip of equivalent total acreage.
Terrain and Slope
Solar panels need to face the sun. Significant slope — generally anything above 5 percent gradient — increases racking and grading costs, and beyond about 15 percent, many terrains become unworkable without expensive cut-and-fill that rarely pencils out.
Flat to gently rolling land is strongly preferred. South-facing slopes in the northern hemisphere are actually beneficial — they naturally angle toward peak solar irradiance — but any steep terrain requires careful evaluation. East-west facing slopes reduce output and affect array design.
Developers use digital elevation models to calculate slope across every part of a candidate parcel before considering it seriously. Land that looks flat in person can have enough micro-variation to create problems at scale.
Land Use and Zoning
Agricultural land zoned A-1 or equivalent is the most common target for solar development for several reasons: it's typically flat, it's outside urban setback restrictions, and the opportunity cost of converting it from row crops to solar is something regulators have become more comfortable approving over time.
The critical question isn't current use — it's whether the local jurisdiction allows solar as a permitted use or conditional use on land of that classification. Some counties require a special use permit, which adds time and uncertainty. A few have outright moratoriums or strict acreage caps.
Developers check the county zoning ordinance before anything else. A parcel that requires a variance — not just a conditional use permit, but an actual variance — carries substantial permitting risk and will either receive a lower offer or get passed over entirely.
Constraint Layers That Kill Deals
Beyond the positive criteria, developers run parcels through a set of constraint filters. Any one of these can disqualify a site:
Flood zone classification: Land in FEMA Zone AE (100-year floodplain) is typically disqualifying. Zone X or Zone X-shaded (500-year) is acceptable in most cases, but insurers and lenders vary. Developers check FEMA flood maps as one of their first automated screens.
Wetlands: Jurisdictional wetlands trigger federal Army Corps of Engineers review under Section 404 of the Clean Water Act, even if they appear dry most of the year. Any wetland presence on a parcel adds months to permitting and limits buildable footprint.
Protected land designations: National Register historic sites, prime farmland designation under the Farmland Protection Policy Act, and proximity to critical wildlife habitat (especially listed species habitat under the Endangered Species Act) all add permitting burden. Some are disqualifying.
Easements and encumbrances: Utility easements, pipeline rights-of-way, and conservation easements show up in title searches and affect what can be built where. A gas pipeline crossing the middle of a parcel isn't disqualifying, but it creates a no-build corridor and adds surveying requirements.
FAA obstruction evaluation zones: Land within a certain radius of airports, heliports, or military installations may require FAA glare analysis — solar panels reflect light, and glare impact on approach paths is a regulated concern. This is a niche issue but one that has killed projects at the permitting stage.
Solar Resource Quality
After all the constraint filters, solar irradiance is almost secondary — but it still matters, especially for project financing. Lenders and tax equity investors who fund solar construction rely on energy production models that require a minimum level of confidence in the long-term solar resource.
The relevant metric is GHI (Global Horizontal Irradiance), measured in kWh/m²/day — the amount of solar energy hitting a square meter of ground per day, averaged annually.
| Region | GHI range (kWh/m²/day) | Representative states |
|---|---|---|
| Southwest | 5.5–6.5 | Arizona, Nevada, New Mexico |
| Southeast / South-Central | 4.5–5.5 | Georgia, Carolinas, Texas |
| Midwest / Northeast | 3.5–4.5 | Ohio, Pennsylvania, New York |
Projects in lower-irradiance regions can still be viable, but they need stronger economics elsewhere — usually better grid access or a higher contracted power price — to compensate.
What "Viable" Actually Means in Practice
A parcel passes the viability test when it clears all the hard constraints and produces project economics that justify the developer's permitting and construction investment. That math depends on factors outside the landowner's control — the current state of the interconnection queue, the contracted power price available in that market, tax credit availability — but the parcel itself contributes most of the inputs.
The parcels that consistently attract the best solar land lease offers share a profile: 50-plus contiguous flat acres, clean title, agricultural or light commercial zoning, no wetlands or flood risk, and within three to five miles of a substation with available capacity.
Most landowners find out their parcel's constraint profile only after a developer tells them — or doesn't call back. Sunnyplans screens parcels against protected areas and wetlands, then ranks them by grid proximity and solar suitability — so you can see what survives the filters before the conversation starts.