The national range that gets cited most often — somewhere between $500 and $2,000 per acre per year — is real, but it tells you almost nothing useful about a specific parcel. A landowner in central Texas and a landowner in rural Indiana can both own flat, sunny, 200-acre parcels and receive lease offers that differ by $800 per acre annually.
The Primary Driver: Grid Access
The rate a developer can offer tracks how much it costs to get power from a parcel to the grid. A solar project needs a point of interconnection — typically a substation with available capacity — and every additional mile of transmission line a developer has to build adds cost that comes out of the lease rate. A parcel two miles from a high-capacity substation supports a higher annual payment than one twelve miles away, even if both parcels have identical solar irradiance and zoning.
NREL's analysis of utility-scale solar siting consistently ranks substation proximity as a top-tier constraint variable, and the criteria developers use to evaluate land viability reflect exactly that — grid access shapes the financial model before irradiance enters the calculation.
ISO/RTO Territory Shapes Developer Competition
The US electricity grid is divided into regional transmission organizations, and which one covers a parcel shapes developer activity — and therefore lease rates.
ERCOT (Texas) operates as an independent island grid with no federal grid oversight from FERC beyond certain rules — which historically meant faster interconnection timelines and more competition among independent developers than anywhere else in the US. Central Texas currently sees ranges of roughly $700–$1,400 per acre per year, driven by strong grid fundamentals and proximity to Houston's electricity demand. West Texas sits at $400–$650; grid congestion in ERCOT's West zone has reduced developer appetite for new sites there, and the rate compression follows.
PJM covers Virginia, Ohio, Pennsylvania, and parts of Indiana. Queue congestion is the defining issue following FERC Order 2023 reforms — cluster study backlogs in some zones have stretched interconnection timelines. When developers can't predict how long a project will sit in queue, they discount the offer accordingly, and parcels without a clear interconnection path feel that most.
MISO territory — Indiana, Illinois, much of the central US — has been through its own queue reform under FERC Order 2023, shifting to a cluster-based study process. Land costs are lower than the coasts, which can support competitive offers on well-positioned parcels, but queue uncertainty in congested zones has added a similar discount to what developers are willing to commit upfront.
In the Southeast — SERC territory, dominated by Georgia Power, Duke, and FPL — utility structure is the binding constraint. Monopoly utilities control most interconnection pathways, which limits the number of independent developers who can get a project permitted and built. Fewer developers competing for land means less upward pressure on rates, even where solar irradiance is strong.
State Policy and Electricity Prices
Two policy variables push rates in either direction: renewable portfolio standards and retail electricity prices.
States with aggressive clean energy mandates — Virginia's Clean Economy Act, North Carolina's HB 951 — create regulatory pressure for utilities to procure solar, which translates into developer demand for land. Where states have set aggressive targets, developers have more regulatory cover to pursue projects, and that competition shows up in higher offers. States without meaningful RPS requirements have less structural demand, and rates reflect it.
Retail electricity prices matter because they affect project revenue per kilowatt-hour. Higher electricity prices mean higher project revenue, which gives developers more room to offer competitive lease rates. New England and the Mid-Atlantic generally have higher retail prices than the Southeast or parts of the Midwest — this partially offsets the higher land costs in those markets.
What the Regional Picture Looks Like
| Region | Primary ISO | Key rate drivers | Directional range ($/acre/year) |
|---|---|---|---|
| Central Texas | ERCOT | Active queue, demand centers, low congestion | $700–$1,400 |
| West Texas | ERCOT | Grid congestion cooling developer competition | $400–$650 |
| Northeast Texas / Gulf Coast | ERCOT | Shifting pipeline activity, flood exposure (Gulf) | $500–$1,100 |
| Southeast (GA, NC, SC) | SERC | Utility-dominated market, limited IPP access | Typically $400–$800 |
| Midwest (OH, IN) | MISO/PJM | Queue reform uncertainty, cheap land | Varies widely; rising with reform |
| Mid-Atlantic (VA, PA) | PJM | Policy tailwind, high land costs, queue congestion | $500–$1,200 |
Ranges for Midwest and Mid-Atlantic states are directional — the variation within each region is large enough that county-level grid context matters more than state averages.
What This Means When Evaluating a Parcel
The top of the rate range reflects parcels where most of the developer's risk and cost has already been filtered out: grid proximity under two miles, no significant wetland or conservation constraints, clear zoning, and an interconnection zone where studies aren't backed up for years. These parcels are a minority.
The bottom of the range reflects land where the developer absorbs real cost or risk — distance from infrastructure, flood zone exposure, a congested interconnection queue that could add years to the project timeline. The lower offer isn't a negotiating position; it's what the project economics can support once those costs are priced in.
A parcel that clears the grid proximity filter reliably commands the top of the range. One that requires a developer to absorb interconnection uncertainty or extra transmission cost is going to land somewhere lower — and that gap is worth understanding before evaluating any offer.
Sunnyplans calculates substation and transmission distance at the parcel level and assigns a SunnyScore to each listing based on the same inputs developers use — grid proximity, constraint overlap, and solar resource. Browse solar land listings across the US to see how specific parcels score on the factors that actually drive lease rates.