U.S. renewables to dominate new capacity in 2026, reshaping industrial decarbonisation strategies

Data from the U.S. Energy Information Administration points to a near-complete shift of planned capacity additions toward variable renewables and batteries in 2026, a development that will have direct implications for industrial decarbonisation strategies, grid planners and project financiers.

EIA’s most recent electricity data, covering generation and capacity through November 2025, show renewables continuing to expand faster than fossil fuels and nuclear in both output and nameplate capacity. According to the SUN DAY Campaign’s analysis of that data, utility-scale solar, wind and battery storage are forecast to supply roughly 69.6 GW of new utility-scale capacity over the next 12 months, with additional distributed solar installations likely to add at least another 6 GW. If realised, those totals would leave natural gas with only modest net growth of around 4 GW, offset in part by coal retirements of about 3.4 GW and no net nuclear additions, meaning renewables and storage would represent roughly 99% of net new U.S. generating capacity in 2026.

The shift is already apparent in 2025 performance. Utility-scale and small-scale solar together produced an estimated 7.2% of U.S. electricity in November 2025, up year-on-year, and solar output for January–November rose by 28.1%, contributing just under 9% of national generation over that period. Wind remained the largest renewable source, supplying 10.1% of U.S. electricity in the first 11 months of 2025. Including hydropower, biomass and geothermal, renewables accounted for about 25.7–26% of electricity production year-to-date, surpassing coal and nuclear generation combined during that window.

Industry reporting corroborates the scale of expected additions. North American Clean Energy cites EIA projections that place utility-scale solar additions in the next 12 months in the mid-30s GW range, while Utility Dive and BIC Magazine note that solar and battery storage together are expected to make up the lion’s share, around 80%, of new utility-scale capacity in the near term. Electrek and other trade outlets have emphasised the possibility that all net new generating capacity in 2026 could be renewables plus storage, underlining a consensus across energy-sector reporting that the resource mix for new capacity is heavily weighted toward low‑carbon technologies.

For industrial energy users and decarbonisation practitioners the implications are manifold. Rapid increases in solar and storage capacity should reduce wholesale price volatility during daylight hours and improve the availability of firming resources, but they will also heighten the operational complexity of balancing systems with high penetrations of variable generation. Developers and asset owners will need to refine bidding, curtailment and co‑optimisation strategies for paired solar‑storage projects. Grid operators will face growing pressure to invest in transmission, interconnection processes and operational tools that preserve reliability as dispatchable thermal capacity declines.

Financiers and policy makers should note the geography of additions reported by sector press: a large share of utility-scale solar growth is concentrated in a few states, notably Texas and California, which can create both investment clustering and transmission bottlenecks. Battery storage growth, a nearly 50% year-on-year increase in deployed capacity during January–November 2025 according to the EIA dataset, strengthens the case for capital structures that accommodate value streams beyond energy arbitrage, including capacity, ancillary services and transmission deferral.

Market participants should also treat headlineled projections with caution. The SUN DAY Campaign frames the outlook as evidence of continued renewable momentum, but such analyses rest on interconnection queues, permitting timelines and supply‑chain assumptions that can change rapidly. EIA’s modelling provides a baseline trajectory, yet project delivery, policy interventions and commodity price dynamics will determine how closely reality follows those projections.

Ken Bossong, executive director of the SUN DAY Campaign, characterised the figures as demonstrating “continued momentum of renewable energy deployment in the U.S., despite political opposition in recent years.” Industry reporting from North American Clean Energy and Utility Dive echoes that reading, while noting that operational differences, particularly capacity factors, mean coal and nuclear assets will continue to supply significant energy even as their relative share of nameplate capacity falls.

For industrial decarbonisation programmes the near‑term priorities are clear: accelerate integration planning that leverages growing volumes of solar and storage, reassess offtake and hedging arrangements to capture time‑varying value, and engage proactively with transmission planning to unlock constrained renewable resources. As the installed base of variable renewables expands toward parity with traditional thermal fleets, the design and procurement of clean energy supply for heavy industrial loads will increasingly pivot from static capacity contracts toward integrated solutions combining generation, storage and demand flexibility.