Largest California Solar Farms: A Comprehensive Directory for 2026

This directory of solar farms California surveys the state’s largest operating utility-scale photovoltaic (PV) and concentrating solar power plants, plus the most significant projects advancing through permitting and construction. California’s installed solar fleet recently surpassed 46 GW of nameplate capacity, and the pipeline of new solar farms California developers are bringing forward remains the deepest in the nation. The interplay between record‑scale sites, co‑located battery energy storage, and evolving off‑take structures is where investors and market researchers are focusing now.

Operating Solar Farms: The Largest Projects

The table below summarises the largest solar farms currently injecting power into the California grid, from multi‑phase PV behemoths to a one‑of‑a‑kind concentrating solar plant.

Project	Location	Capacity (MW)	Storage (MWh)	Technology	Primary Off‑taker	Year(s) Online
Edwards & Sanborn Solar + Storage	Kern County	875	3,287	Crystalline‑silicon & thin‑film PV, single‑axis trackers	SCE, PG&E	2022‑2024
Solar Star	Kern / Los Angeles Counties	579	—	Single‑axis tracking PV	SCE	2015
Topaz Solar Farm	San Luis Obispo County	550	—	Cadmium telluride thin‑film, single‑axis trackers	PG&E	2014
Desert Sunlight Solar Farm	Riverside County	550	—	Thin‑film PV	SCE, PG&E	2015
Blythe Solar Power Project	Riverside County	485	—	Single‑axis tracking PV	SCE	2016‑2022
Ivanpah Solar Electric Generating System	San Bernardino County	392	—	Power‑tower concentrating solar with heliostats	PG&E, SCE	2014
California Valley Solar Ranch	San Luis Obispo County	250	—	Single‑axis tracking PV	PG&E	2013

Why the Edwards & Sanborn numbers matter for offtake valuations. The 3,287 MWh battery system at Edwards & Sanborn provides exactly the four‑hour duration that California resource adequacy contracts now prize. Southern California Edison and Pacific Gas and Electric purchase the output under long‑term PPAs, and the storage means the project can deliver firm, dispatchable energy into the early evening net‑peak period. That combination—large‑scale PV plus storage that shifts generation by several hours—is rapidly becoming the template for new solar farms California off‑takers want to sign.

Expert nuance on nameplate versus delivered capacity. The capacities listed above are nameplate AC ratings. During peak summer months, actual grid deliveries from these plants can sit 10–15% below nameplate because of soiling, high‑temperature derating, and inverter clipping. When you are modelling a PPA’s shape, it pays to derate nameplate megawatts to expected annual net output, not to rely on headline numbers.

Ivanpah’s operational reality. Ivanpah uses water for steam generation and mirror washing; the plant has undergone efficiency adjustments and partial repowering in recent years. Although no new concentrating solar plants are being built in California at this scale, Ivanpah remains a reminder that concentrating solar brings different operational costs and a different output profile than single‑axis‑tracking PV.

Planned and Under‑Construction Solar Farms

The development pipeline shows that utility‑scale solar in California is still scaling aggressively. The table below captures the largest known projects, though CAISO’s interconnection queue holds over 50 GW of submitted solar projects, so the total roster is much longer.

Project	Location	Planned Capacity (MW)	Storage	Developer	Target COD
Westlands Solar Park	Kings County	Up to 2,700 across multiple phases	Not specified	—	Phased rollout
Crimson Solar Project	Blythe / Riverside County	350	Included (battery storage)	Recurrent Energy	2026
Sanborn Solar expansion	Kern County	Hundreds of megawatts additional	Existing complex added to	Terra‑Gen	Tied to Phase II of Edwards & Sanborn

Common mistake investors make with pipeline numbers. CAISO’s interconnection queue tallies over 50 GW of solar entries, but a large share of those projects will later withdraw or be combined. Interpreting that raw figure as committed new construction overstates the realistic mid‑term build‑out. Developers typically use the queue to secure grid positions early and then decide which sites to advance; the queue data alone does not equate to shovel‑ready capacity.

A practical scenario for siting decisions. A developer who secures land near an existing 500 kV backbone in Kern County can often reduce network upgrade costs dramatically compared with a site that requires a new radial line. When evaluating solar farms California project economics, the first variable to stress‑test is often the interconnection study deposit and the scope of required transmission upgrades, not the module price.

What Drives California’s Solar Farm Growth?

Renewable Portfolio Standard and Carbon Goals

California’s Renewable Portfolio Standard requires 60% renewable electricity by 2030 and a fully carbon‑free grid by 2045. That policy floor creates durable, long‑term demand that IPPs can underwrite into project finance models. Even when spot power prices tumble during solar‑heavy hours, the RPS mandate keeps utility procurement teams buying.

The Investment Tax Credit and Capital Stacks

The federal Investment Tax Credit (ITC) sits at 30% through 2032 and continues to anchor project capital stacks. Pairing the ITC with bonus adders (energy community, domestic content) is now a standard modelling exercise. Decision rule: if your project qualifies for the energy‑community adder, run two financial scenarios—one with the adder and one without—because IRS guidance on what constitutes an “energy community” can shift between the start of construction and the placed‑in‑service date.

PPA Structures and Off‑taker Evolution

Most large‑scale solar projects in California monetise output through power purchase agreements signed with investor‑owned utilities and community choice aggregators (CCAs). The rise of CCAs has broadened the off‑take market, but CCA contracts often carry shorter tenors and different credit‑support requirements than traditional utility PPAs. Expert nuance: a CCA PPA may price energy at a hub such as NP15 or SP15, but the basis risk between the hub and the project’s delivery node can erode margins if the developer doesn’t hedge transmission congestion.

Battery Co‑Location and Resource Adequacy

Adding a behind‑the‑meter battery energy storage system to a PV site lets the project sell into higher‑priced evening windows and bid into CAISO’s resource adequacy construct. Development rule of thumb: if your PPA values only as‑generated PV and you plan to add storage later, re‑negotiate the offtake language early so that battery charging does not count as parasitic load that reduces your contracted delivery volume.

Repowering Older Plants

Photovoltaic plants commissioned in the early 2010s are increasingly swapping out modules and inverters on the same racking and grid connection. Repowering can lift capacity factors by several percentage points and extend asset lives beyond the original 30‑year design horizon without starting a new permitting cycle from scratch.

What Environmental and Land‑Use Factors Shape Solar Farms?

Land Requirements and Dual‑Use Options

Utility‑scale solar typically needs 5 to 10 acres per megawatt, a footprint that varies with site slope, panel efficiency, and tracker spacing. Central Valley developers increasingly turn to drainage‑impaired agricultural land for dual‑use solar arrangements, reducing competition with prime farmland while keeping the land in agricultural tax status.

Water, Dust, and Module Maintenance

All large new plants in California are photovoltaic and use dry‑cooling systems, so water for steam generation is no longer a factor outside of the legacy Ivanpah plant. Dust, however, remains a persistent drag on performance. Common practice: waterless robotic cleaning and controlled grading are the go‑to methods for maintaining module efficiency and satisfying county‑level dust‑control permits in the Mojave and San Joaquin Valley.

Habitat Conservation and Permitting

Permitting for solar farms California agencies review frequently involves mitigation for protected species—especially the desert tortoise and San Joaquin kit fox. Scenario: a developer working in western Kern County may satisfy habitat requirements by purchasing credits from an approved mitigation bank early in the CEQA process, rather than trying to redesign the array layout later. That small upfront step often saves six to nine months in the permitting schedule.

A Quick‑Check Agenda for Early‑Stage Siting

• Confirm the parcel is not encumbered by a Williamson Act contract that restricts non‑agricultural use.
• Overlay the project boundary with California Department of Fish and Wildlife critical habitat maps.
• Verify that the point of interconnection can accommodate the proposed capacity without a new substation.
• Evaluate whether adding agrivoltaics (sheep grazing or pollinator habitat) strengthens support from county planning staff.

Frequently Asked Questions

Is California closing a solar farm?
No. No utility‑scale solar farm in California is being permanently shut down. Older concentrating solar units at Ivanpah have been temporarily curtailed for repowering work, but full decommissioning of large PV or CSP assets remains extremely rare.

Are solar farms profitable in California?
Yes. Utility‑scale solar farms in California are generally profitable thanks to long‑term PPAs with creditworthy off‑takers, declining equipment costs, and the federal ITC. In high‑irradiance zones, capacity factors above 25% are common, and adding battery storage makes project‑level returns even more compelling by capturing evening price peaks.

What’s the downside to solar farms?
Land‑use conflicts, grid congestion during periods of high renewable output, and curtailment risk are the main challenges. Dust accumulation and water availability for cleaning add daily operational burdens in desert regions, though developers mitigate these with dual‑use designs, storage co‑location, and waterless cleaning.

Where’s the largest solar farm in California?
Edwards & Sanborn Solar + Storage in Kern County holds the title, with 875 MW of PV and 3,287 MWh of battery storage fully operational by 2024.

What’s the typical life span of a California solar farm?
Utility‑scale photovoltaic plants are engineered for 30–35 years. At the 15‑ to 20‑year mark, repowering—swapping out modules and inverters while preserving the grid connection and offtake arrangements—is standard.

Download the Complete Directory

The quick‑reference tables above cover the largest projects, but the full searchable directory includes sub‑250 MW plants, ownership structures, detailed PPA parameters, interconnection maps, and developer contacts. It’s available as a free download.