Wind Farms Have Had 50 Years of Subsidies: Should We Rethink How Energy Is Priced?

A recent clip from Net Zero Watch highlights a pointed question from Reform Scotland leader Malcolm Offord: Why are wind farms still being subsidized after decades of support? “Wind farms arrived 30 years ago, and they were given a 15-year subsidy,” Offord noted. “After 15 years, they’re given another 15-year subsidy, and then last month they’re given 20 years more subsidy. So that’s 50 years of subsidy.”

Offord’s remarks, made during a podcast discussion, underscore a broader frustration: despite promises that wind power would become the “cheapest form of energy,” massive ongoing subsidies, grid upgrades, and constraint payments continue to flow into the sector—costs ultimately passed on to consumers. In Scotland, where onshore and offshore wind have boomed, the real-world impacts are stark. This pattern repeats in the United States, where federal tax credits prop up wind generation while grid integration and resiliency costs are socialized across ratepayers. It’s time to ask: Should we rethink how we price energy by updating metrics like the Levelized Cost of Energy (LCOE) to reflect full system costs?

“Why are wind farms still being subsidised? Wind farms arrived 30 years ago, and they were given a 15 year subsidy… After 15 years, they’re given another 15 year subsidy, and then last month they’re given 20 years more subsidy. So that’s 50 years of subsidy.” @Malcolm_Offord pic.twitter.com/JlNWBA3ahe

— Net Zero Watch (@NetZeroWatch) April 8, 2026

Scotland’s Wind Boom: Subsidies, Curtailment, and Soaring Consumer Costs

Scotland has aggressively pursued wind energy, positioning itself as a renewable leader. Yet the results have not matched the hype. Massive constraint (curtailment) payments—where operators are paid to shut down turbines because the grid cannot handle excess generation—have become routine. In recent years, Scottish wind farms have received hundreds of millions in such payments annually. UK-wide curtailment costs hit roughly £1.5 billion in 2025 alone, with the vast majority tied to Scottish wind output (often 98% of curtailed volume). Projections suggest these could reach £8 billion by 2030 without reforms.

These payments aren’t abstract—they directly inflate household bills. Ofgem estimates constraint costs alone added around £15 to typical UK household bills in late 2025, with network upgrades to accommodate more wind projected to add another £60 per year by 2030. For a typical three-bedroom household facing £1,000 annual bills, only about one-third covers actual energy; the rest includes subsidies, grid upgrades, carbon taxes, and add-ons.

Grid bottlenecks exacerbate the issue. Scotland generates far more wind power than its local demand can absorb, but transmission capacity to England (and internal Scottish reinforcements) lags. Turbines frequently run below capacity or are paid to idle entirely. Meanwhile, promised “just transition” jobs in renewables have underdelivered: many turbine blades and components are manufactured elsewhere, and transferability/salary levels in the sector have fallen short of expectations. Rural communities often bear visual and environmental costs with limited local economic upside.

Offord summed it up: The “big green economy” touted by politicians isn’t materializing as promised for ordinary Scots—it primarily benefits big developers who sometimes get paid both to produce and not to produce.

Wind Power in the United States: Subsidies Without Full Accountability

The U.S. wind industry tells a parallel story. Installed wind capacity has grown dramatically, driven by federal incentives. The Production Tax Credit (PTC) remains the cornerstone: for qualifying projects, it provides up to ~2.75–3 cents per kWh (inflation-adjusted, higher with prevailing wage/apprenticeship requirements under the Inflation Reduction Act). This credit applies for 10 years after a facility comes online.

Because the PTC is production-based, operators can bid electricity into wholesale markets at zero or even negative prices and still profit, distorting price signals and making it harder for dispatchable (reliable, on-demand) generation to compete. Power Purchase Agreements (PPAs) often lock in payments, but the subsidy layer allows wind to underbid true marginal costs.

Crucially, wind developers are rarely charged directly for the full costs they impose on the grid. Two major gaps stand out:Transmission and Interconnection Costs: In Texas—the nation’s wind leader—the Competitive Renewable Energy Zones (CREZ) initiative built ~$6.9–7 billion in new high-voltage lines specifically to deliver remote West Texas wind to population centers. These costs were socialized across ERCOT ratepayers via transmission charges, not borne by wind developers. Ratepayers have shouldered nearly $15 billion in such renewable-related transmission investments since 2010 (adjusted figures show a 57% real increase in per-customer transmission charges). Ongoing and planned upgrades could push annual transmission costs beyond $12 billion by the early 2030s, adding at least $100 annually to average residential bills.

Grid Resiliency and Balancing Costs: Wind’s intermittency requires backup generation, storage, or demand response to maintain reliability. These “system integration” costs—ancillary services, congestion management, and reliability adders—are largely socialized. ERCOT has seen billions in annual congestion costs, partly driven by variable renewable output. Wind farms contribute to—but are not directly charged for—the need for additional dispatchable capacity or storage to keep the lights on during low-wind periods.

In short, wind receives guaranteed production subsidies while the downstream costs of integration, resiliency, and infrastructure are spread across all ratepayers and taxpayers.

Redefining the Levelized Cost of Energy: Time for a Full-System View

The standard LCOE metric—widely cited to claim wind is now “cheaper” than fossil fuels—calculates only the plant-level costs of building and operating a generator over its lifetime, divided by expected output. It ignores critical system-wide realities: transmission upgrades, grid balancing, backup capacity for intermittency, and resiliency needs during low-output periods.

Analysts increasingly call for a “Levelized Full System Cost of Energy” (or System LCOE / LFSCOE) that internalizes these externalities. Studies using this approach show wind and solar costs rise dramatically when forced to supply 100% (or even 95%) of demand in isolation. In Texas (ERCOT), for example, wind’s full-system costs can exceed those of natural gas or even nuclear when balancing and storage requirements are included. Even with steep storage cost reductions, renewables struggle to compete on a true apples-to-apples basis.

Energy News Beat has previously advocated updating LCOE to a “Levelized System Cost of Energy” that explicitly includes integration, balancing, storage, and resiliency charges. Policymakers should require this fuller accounting in procurement decisions, rate cases, and subsidy evaluations. Only then can markets send accurate price signals and ensure consumers pay the real cost of the energy mix they receive.