Xcel Energy Takes Colorado Wind Interconnection Dispute to State Supreme Court
An eminent domain standoff is blocking more than 1 GW of nearly complete wind capacity from reaching the grid, threatening a state-approved expansion plan.
Xcel Energy's Public Service Co. of Colorado filed a petition with the Colorado Supreme Court on Wednesday (2026-08-12), asking justices to resolve an eminent domain dispute that has left two nearly finished wind farms unable to connect to the grid. The projects — the 603-MW Singing Grass and 450-MW Cheyenne Ridge II facilities — represent more than 1 GW of generation capacity sitting idle while the legal standoff plays out.5
Both projects are part of a 6.1-GW system expansion approved by Colorado state utility regulators in January 2024. With construction essentially done, the bottleneck is no longer engineering or finance — it is land access, and the utility has concluded the dispute cannot wait for lower courts to work through it.5
The cost exposure is real. Wind farms installed in 2024, before Trump administration tariffs broadly pushed up infrastructure costs, averaged $1.85 million per MW according to the most recent land-based wind report from Lawrence Berkeley National Laboratory. At that rate, Singing Grass and Cheyenne Ridge II together represent roughly $1.95 billion in sunk capital that is generating no revenue and no electrons for Colorado ratepayers.5
PSCo's filing describes the case as presenting "an important statewide question at the intersection" of utility regulation and property rights, framing it as the kind of issue that warrants Supreme Court intervention rather than years of appellate litigation. Whether Colorado's justices agree to take it up — and how quickly — is now the central variable for the project timeline.5
The dispute arrives in a broader national environment where wind development has become increasingly contested in the courts and in federal policy. The Trump administration has moved to limit onshore wind construction, with President Trump stating his administration would "try and have no windmills built in the United States." A coalition of 18 states and Washington, D.C., had already moved by July (2026-07-20) to join an industry lawsuit challenging the Department of Defense's freeze on onshore wind projects.4
Colorado's situation is different from a federal permitting fight — this is a state-level eminent domain question, not a federal licensing dispute. But the broader pattern holds: across multiple jurisdictions, wind developers and utilities are finding that court systems have become a primary venue for resolving project blockages that were once handled through administrative processes. In Italy, Montel reported, authorities reject close to 50% of wind farm applications, and most onshore permits are now secured through legal action against the assessment system rather than through regulatory approval.3
In Scotland, CWP Energy submitted a judicial review petition in June (2026-06-02) after the Scottish government blocked its 432-MW Scoop Hill project, and launched a second judicial review against the Ministry of Defence in late June (2026-06-29) over a ban on wind farms near the Eskdalemuir Seismic Array. The company argued the decision was unlawful.1,2
None of those cases are directly analogous to Xcel's eminent domain problem in Colorado. But together they illustrate a shift: for large-scale wind, the grid connection or permitting dispute has become as significant a risk factor as turbine costs or financing. Lenders and equity investors pricing wind assets now need to model legal timelines alongside construction schedules.
For PSCo specifically, the stakes extend beyond two projects. The 6.1-GW expansion plan approved in January 2024 is the backbone of the utility's generation strategy, and delays to Singing Grass and Cheyenne Ridge II have implications for the sequencing of everything behind them. A prolonged Supreme Court process — Colorado's docket is not fast — could push commissioning deep into a period when tariff-inflated replacement costs make any re-procurement significantly more expensive than the 2024 average of $1.85 million per MW.5
The court's decision on whether to accept the case will be the first signal. If justices decline, Xcel is back in the lower court queue with no clear timeline. If they accept, the question becomes how they read the intersection of eminent domain law and utility interconnection rights — a ruling that would carry weight well beyond these two projects.