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Explore databasesThe United States passed 200 GW of total installed solar capacity as 2026 opened, and utility‑scale solar farms drove nearly all of those new grid connections. Interconnection queues are swelling, corporate offtake demand stays strong, and a record number of projects are moving from paper to steel. Three developers dominate that pipeline: NextEra Energy Resources, Invenergy, and EDF Renewables North America. Here is how they compare on operating fleets, landmark projects, and what comes next.
Who Are the Largest Developers of Solar Farms?
Three firms control the lion’s share of the development pipeline and already run some of the country’s biggest solar parks. The table below gives a quick size comparison, and the sections that follow dig into each operator’s approach and most notable assets.
| Developer | HQ | Operating solar | Pipeline | Signature project |
|---|---|---|---|---|
| NextEra Energy Resources | Juno Beach, FL | >9 GW | >18 GW | 550 MW Desert Sunlight Solar Farm (CA) |
| Invenergy | Chicago, IL | ~3.5 GW | >20 GW (solar + storage) | 1.31 GW Samson Solar Energy Center (TX) |
| EDF Renewables North America | San Diego, CA | ~5.5 GW | >10 GW | 300 MW Space City Solar (TX) |
NextEra Energy Resources
NextEra Energy’s competitive generation arm has been developing solar since 1998 and now runs the largest operating solar fleet in the country. Its 9+ GW of photovoltaic assets sit inside a broader 30 GW portfolio that mixes wind, solar, and battery storage. Standout projects include the 550 MW Desert Sunlight Solar Farm in California (commissioned in 2015, co‑owned), the 485 MW Blythe Solar Power Project (completed in phases through 2024), and the 300 MW Centinela Solar Energy Project.
A practical nuance many land‑use planners miss: NextEra systematically deploys single‑axis trackers with bifacial modules across its newer sites, which lifts yield by several percentage points without requiring more land. That equipment choice helps the company reach competitive levelised costs in both high‑irradiance Southwestern deserts and less‑sunny Southeastern locations. The revenue side relies on long‑term power purchase agreements with utilities and large corporate buyers, which support project financing even before construction starts. The 18 GW development queue leans heavily into Texas, the Southwest, and the Southeast—a deliberate geographic bet on strong solar resource and proximity to growing load centers.
Invenergy
Invenergy entered solar development in 2001 and today operates about 3.5 GW of solar capacity, with more than 7 GW developed across its history. Its flagship asset is the 1.31 GW Samson Solar Energy Center in Texas, built in phases beginning in 2022 and ranking among the largest single‑site PV power stations in the nation. The 250 MW Buckthorn Solar project adds another large block of capacity.
Where Invenergy often wins on project returns is its engineering philosophy: high DC‑to‑AC ratios and advanced inverter configurations push capacity factors beyond 25% at top‑tier desert sites. Rather than abandoning aging sites, the company actively repowers older solar plants and reuses brownfield land, which sidesteps greenfield permitting headaches and stretches the useful life of existing interconnection rights. Its combined solar‑plus‑storage pipeline tops 20 GW, underpinned by an in‑house finance team and established tax‑equity structures that can close deals faster than many competitors.
EDF Renewables North America
A subsidiary of the French utility EDF Group, EDF Renewables North America manages roughly 5.5 GW of installed solar from its San Diego headquarters. The portfolio spans utility‑scale farms, behind‑the‑meter setups, and community solar platforms—a breadth that gives the firm multiple routes to market. Key assets include the 300 MW Space City Solar project in Texas, the 250 MW Cougar Solar installation, and California’s 200 MW Desert Harvest facility.
A common developer mistake is relying too heavily on a single offtake type; EDF Renewables hedges that risk by layering virtual power purchase agreements alongside physical PPAs. Its tax‑equity model paired with the investment tax credit works to lower the levelised cost of energy and structure competitive wholesale sales, which matters most when power prices in deregulated markets dip. The North American pipeline exceeding 10 GW is spread across several interconnection queues, reducing queue position concentration and giving the company optionality to advance projects as grid capacity opens up.
Notable Solar Farms by State
The table below highlights some of the largest solar farms commissioned across key states during the 2010s and early 2020s. Each project reflects the scale and regional diversity of US utility‑scale solar development.
| State | Project name | Capacity (MW) | Commissioned |
|---|---|---|---|
| California | Desert Sunlight Solar Farm | 550 | 2015 |
| California | Topaz Solar Farm | 550 | 2014 |
| California | Solar Star | 579 | 2015 |
| California | California Valley Solar Ranch | 250 | 2013 |
| Nevada | Copper Mountain Solar Facility | 802 | 2010–2021 |
| Arizona | Agua Caliente | 290 | 2014 |
| Arizona | Mesquite Solar | 400 | 2011–2016 |
| Texas | Roserock Solar Facility | 212 | 2016 |
| Texas | Buckthorn Solar | 250 | 2020s |
| Florida | Babcock Ranch Solar Energy Center | 75 | 2016 |
| Florida | Manatee Solar Energy Center | 74.5 | 2016 |
California tops the list with giant desert parks, but Nevada’s Copper Mountain facility reached 802 MW in stages and Texas has added several large farms that now anchor the ERCOT market.
Frequently Asked Questions
What is the downside of solar farms?
The main downsides are land-use conflicts, intermittent generation, and high interconnection costs. Utility‑scale solar farms typically need 5 to 10 acres per megawatt, which can disrupt habitat and compete with agricultural uses. Capacity factors usually range from 20% to 30% across US sites, so backup power or storage is required to deliver firm capacity. Grid‑interconnection studies and battery retrofits add both upfront expense and operational complexity.
How profitable is a solar farm?
Typical returns run 8% to 12% unlevered internal rate of return, with payback periods of 5 to 10 years in favorable markets. Annual revenue per megawatt can reach $30,000 to $60,000, based on long‑term PPA rates of $20 to $40 per MWh and a capacity factor around 25%. Actual returns swing widely depending on solar resource, tax equity terms, and regional wholesale power prices, so site‑level due diligence is essential.
How much does a 1‑acre solar farm cost?
A 1‑acre ground‑mounted system with roughly 0.2–0.25 MW of nameplate capacity costs $150,000 to $300,000 installed. That figure covers modules, single‑axis tracking or fixed‑tilt racking, inverters, labor, and soft costs like permitting and interconnection studies. At an installed cost of $0.80 to $1.20 per watt, larger contiguous projects benefit from economies of scale; a 100 MW farm occupying 400 to 1,000 acres would require $80 million to $120 million in upfront investment.
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