Duke Surrenders Carolina Wind Lease as Trump Buyout Program Redirects Billions to Gas
The administration's $2.6 billion offshore wind exit is funneling capital toward natural gas infrastructure, creating a structural demand tailwind for a market where Henry Hub now trades above $3.
Duke Energy surrendered its undeveloped offshore wind lease in the Carolina Long Bay area on Monday (2026-06-29), accepting partial reimbursement from the U.S. Department of the Interior in exchange for rights the company originally acquired for $155 million in 2022.4
Interior valued the lease at $129 million, describing it as a "very early stage" project, and stipulated that Duke reinvest the same amount in additional generating capacity for Carolinas customers.4 The utility had projected the site could support up to 1.6 gigawatts of potential offshore wind — enough to power approximately 375,000 homes — contingent on regulatory approval. That optionality is now closed out.
Duke's deal is the latest in a systematic federal program. Across nine lease areas, the Trump administration has agreed to pay more than $2.6 billion to terminate offshore wind development rights, with recovered funds steered toward specific alternative projects including oil, gas and geothermal.4 On June 17 (2026-06-17), the Interior Department reached a separate $765 million agreement with Invenergy to close its offshore leases, directing those proceeds toward natural gas-fired power plants in Indiana, Wisconsin, Iowa, Kansas and Missouri, as well as geothermal development in the western United States.3
The implication for gas supply investment is direct. NYMEX Henry Hub front-month traded at $3.21 on Wednesday (2026-07-01), and the program is effectively underwriting a new cohort of gas generation capacity in Midwest markets where coal retirement timelines and load growth from data centers have created visible resource adequacy pressure.3
Golden State Wind, a joint venture between Ocean Winds and Reventus Power, earlier settled for approximately $120 million in refunded lease fees.5 A coalition challenging the broader policy argues that the termination of $2.7 billion in clean energy awards — including $1.2 billion for California's ARCHES clean hydrogen hub — represents an unconstitutional violation of congressional appropriations.5 That legal challenge has not yet slowed the pace of settlements.
The gas market context complicates the picture. EIA data show marketed natural gas production in the Lower 48 averaged 117.2 billion cubic feet per day in the first quarter of 2026, a 4% increase year-on-year, with the agency forecasting a further 3% increase for the full year driven largely by Permian growth to 29.2 Bcf/d.2 Storage inventories were running 141 billion cubic feet above year-ago levels as of late May, roughly 8% above the prior year.1 That surplus has capped the front-month price for most of 2026.
But the wind buyout program is building a structural commitment to gas-fired generation on a multi-year horizon, with new combined-cycle capacity in Midwest grid territories where gas holds a competitive edge over residual coal. The EIA projects Haynesville production to grow 6% in 2026 and 8% in 2027, partly anticipating incremental gas loads from this pipeline of new capacity.2
The mechanism matters for demand more than near-term spot prices. New combined-cycle plant in load-growth markets consumes base-load volumes rather than peaking supplies, creating long-dated contracted demand that may not register in weekly EIA storage reports for two or three years.
What the program has not resolved is execution timing. Duke described the Carolina lease as "very early stage," and Interior's $129 million valuation reflected the absence of any permitted infrastructure.4 Whether the redirected capital flows into operational gas turbines before the next federal election cycle remains the central risk — a developer choosing between a greenfield gas plant in Indiana and an early-stage offshore wind permit faces permitting timelines that may not differ as sharply as the policy shift implies.