U.S. wind and solar output climbed 10% in the first half of 2026, outpacing coal and nuclear despite federal headwinds

U.S. wind and solar generation climbed 10 percent in the first half of 2026, producing nearly 420 terawatt-hours and overtaking both coal and nuclear in the country's electricity mix, according to a POLITICO review of federal energy data reported by E&E News. It is the first time wind and solar have surpassed nuclear over a comparable six-month period, and it comes despite an active federal effort to slow the sector's expansion.

Coal output fell 10 percent year over year to 323 TWh during the same window. Nuclear climbed 2 percent to 390 TWh. Natural gas, still the country's dominant power source, held essentially flat at 767 TWh. Wind and solar's combined 20 percent share of generation, up from 18.6 percent in the first half of 2025, now represents a meaningful planning variable for any enterprise buying power at scale.

A pipeline built before the policy reversal

The gains reflect, in large part, a construction wave that began before federal incentives were rolled back. The U.S. installed a record 31 gigawatts of solar in 2024 and 29 GW in 2025, according to EIA data cited by E&E News. Another 9 GW had been installed through May 2026. That backlog of capacity is now producing power regardless of the current policy environment.

The single biggest contributor to wind growth this year is Pattern Energy's SunZia facility in eastern New Mexico, which at 3,650 megawatts is the largest renewable energy project ever built in the United States. SunZia officially came online in mid-2026 after testing that began as early as April, per E&E News. Writing in The Land Desk, journalist Jonathan P. Thompson noted that SunZia added a "whopping 3.65 gigawatts to the grid" and represents exactly the kind of project that was deep in permitting and construction before federal land-leasing restrictions tightened.

Utility-scale solar alone produced nearly 156 TWh through June, a 19 percent increase over the same period in 2025, according to EIA figures. Wind generation rose 5 percent to 264 TWh, with SunZia and the 800 MW Vineyard Wind project off Massachusetts, which has been gradually ramping up despite turbine commissioning challenges, among the largest contributors.

Private land and displaced farmland filling the permitting gap

Federal land permitting for utility-scale wind and solar has slowed under the current administration, but developers have responded by routing projects onto private land, including former agricultural fields. Thompson, writing in The Land Desk, highlighted California's Westlands Water District, which is advancing a 20-gigawatt solar and battery storage project across more than 100,000 acres of water-constrained Central Valley farmland under its Valley Clean Infrastructure Plan. Projects of that scale on already-disturbed land reduce pressure on ecologically sensitive public acreage while also freeing irrigation water previously consumed by crops.

The economics driving private-land solar are straightforward. As Nora Brownell, a former Pennsylvania utility regulator and ex-Federal Energy Regulatory Commission member, told E&E News: utilities building new generation are choosing solar because it is fast and cheap. That cost structure has provided a degree of insulation from federal policy changes that more capital-intensive generation types simply do not have.

Two variables now dominating the forward outlook

Federal tax credits for new wind and solar projects expired July 4, 2026, under a budget law signed last year. Projects that had met the legal definition for starting construction before that date can still qualify for subsidies through the end of the decade, per E&E News, but the economics for projects not yet in that window have shifted materially. BloombergNEF analyst Helen Kou told E&E News that the tax-credit phaseout changes project economics, even as AI and data center load growth continues to pull investment into both renewables and storage independently.

That data center demand is also fueling a parallel gas buildout. Power companies are increasingly planning gas plants to serve anticipated AI-driven load, according to E&E News. While solar accounts for more planned capacity through 2030 (130 GW) than gas (66 GW), the expected electricity output of the two technologies is comparable because gas plants run at much higher capacity factors. Timothy Fox, an analyst at ClearView Energy Partners, told E&E News that the central question is no longer whether renewables will grow, but whether they can grow fast enough to maintain their share of an overall mix in which total demand is also rising. National power demand was up 1 percent through the first six months of 2026, reaching 2,079 TWh, per EIA.

For energy procurement and operations teams, that combination of expiring incentives, accelerating demand, and a bifurcated capacity market between solar and gas means the planning horizon through 2030 looks materially different from the one that shaped contracts signed even 18 months ago. Projects grandfathered under prior incentive rules remain the most competitively priced near-term option; anything requiring new federal credits will need revised pro formas.

What this means for your team

• Audit your power purchase agreements against the July 4, 2026 tax-credit expiration: projects that had not legally started construction by that date face different economics, and counterparty pricing may shift during renegotiation windows.
• Evaluate large-scale solar opportunities on private or formerly agricultural land, where permitting timelines are shorter than federal land projects and the Westlands-style model is gaining traction.
• Factor AI and data center load growth into demand forecasts: national power consumption is already up 1 percent in H1 2026, and gas plant buildout to serve that load will compete for the same grid interconnection queues as new renewables.
• Track grandfathered renewable projects in your region closely: capacity coming online through the end of the decade under prior incentive rules represents the most price-stable procurement option in the current policy environment.