Wind and Solar Set to Surpass Natural Gas as Texas Grid’s Top Power Source
EIA forecasts ERCOT renewables will generate more electricity than gas-fired plants in 2026, marking a structural shift in the nation’s largest competitive power market.
Wind and solar generation on the Electric Reliability Council of Texas grid are on track to surpass natural gas as the system’s single largest source of electricity in 2026, according to the U.S. Energy Information Administration. The EIA’s February forecast projects that combined wind and solar generation in ERCOT will reach 189 million megawatt-hours this year, overtaking natural gas at 177 million MWh. The milestone underscores a rapid transformation in a state long defined by its fossil fuel dominance—and one that carries significant implications for energy infrastructure, grid operations, and workforce planning across the sector.
Texas has quietly become the nation’s renewable energy powerhouse. The state passed California in installed utility-scale solar capacity in 2024, and 2025 was the first full year in which Texas’ solar projects generated more electricity than California’s, producing 58,634 gigawatt-hours from utility-scale solar alone. Over the first nine months of 2025, Texas installed 7.4 gigawatts of new solar capacity—nearly double California’s additions over the same period.
The shift is also visible in ERCOT’s evolving fuel mix. Natural gas-fired generation averaged 43 percent of ERCOT demand in the first nine months of 2025, down from 47 percent over the same period in 2023 and 2024. Wind and solar, by contrast, met 36 percent of ERCOT electricity demand, with utility-scale solar alone generating 45 terawatt-hours—50 percent more than the same period in 2024 and nearly four times the output from the same period in 2021.
Battery storage has been central to enabling this transition. The ERCOT grid entered 2026 with approximately 13.9 gigawatts of commercially operational battery energy storage, surpassing California for the first time to lead the nation. According to the Solar Energy Industries Association and Benchmark Mineral Intelligence, U.S. battery storage installations hit a record 57.6 GWh in 2025, with Texas commanding the largest share.
The scale of planned additions is striking. Nationally, developers plan to install 84 GW of utility-scale solar, 45 GW of batteries, and 20 GW of wind in 2026 and 2027, compared to just 15 GW of natural gas. Texas alone represents 40 percent of planned solar additions and more than half of planned battery storage capacity. The EIA estimates that renewable energy and battery storage will account for 99 percent of all new electricity capacity added to the U.S. grid in 2026.
Several factors are driving this concentration in Texas. Data center demand, cryptocurrency mining operations, and industrial electrification are pushing ERCOT load growth higher than any other U.S. grid operator. The Tehuacana Creek 1 Solar and BESS project, the largest solar photovoltaic facility expected to come online in 2026, will add 837 megawatts of solar and 418 MW of battery storage to the Texas grid. Zelestra has also begun construction on the 253 MWdc Echols Grove and 188 MWdc Cedar Range solar projects in Northeast Texas.
Developers face headwinds, however. Federal tariffs on imported solar cells and modules continue to raise project costs, and the expiration of certain tax credit safe harbor provisions has compressed development timelines. Despite these pressures, Texas managed to add the same volume of solar capacity in 2025 as it did in 2024, suggesting that the state’s market fundamentals—abundant land, strong irradiance, favorable permitting, and growing demand—continue to outweigh policy uncertainty.
A transition of this magnitude creates substantial demand shifts across the energy workforce. The buildout of utility-scale solar and battery storage projects across Texas requires experienced project managers, electrical engineers, and construction supervisors capable of managing large-scale installations in a compressed timeline. Battery energy storage systems, in particular, demand specialized knowledge in power electronics, thermal management, and grid integration that remains relatively scarce in the labor market.
Grid operations are also evolving. As ERCOT manages an increasingly variable generation mix, demand is growing for power systems engineers, grid reliability analysts, and forecasting specialists who can model and respond to the intermittency profiles of wind and solar resources. The integration of nearly 14 GW of battery storage adds another layer of operational complexity, requiring dispatch optimization expertise and familiarity with emerging storage-as-transmission models.
On the regulatory and commercial side, the interplay between federal trade policy, tax credit structures, and state-level permitting is creating demand for energy finance professionals, regulatory affairs specialists, and development attorneys who can navigate an increasingly complex policy landscape. Organizations expanding their renewable portfolios in Texas may find competition for this talent intensifying as the state’s share of national capacity additions continues to grow.
Industry observers will be watching several developments in the coming months. The pace at which ERCOT’s renewable share grows relative to natural gas will test the grid’s ability to maintain reliability during peak summer demand, when solar output is highest but evening ramp rates create operational challenges. The performance of Texas’s expanded battery storage fleet during the summer of 2026 will be a critical proof point for storage’s role in grid stability.
Federal trade policy remains a wildcard. Any escalation or extension of solar tariffs could slow the pace of new project construction, while clarity on long-term tax credit availability would influence the pipeline of projects currently in development. At the state level, ERCOT’s ongoing market redesign efforts—including potential capacity market mechanisms—could reshape the economics of both renewable and conventional generation in ways that reverberate across the broader U.S. power sector.
