New York, North Carolina slam Trump administration's deal to kill offshore wind projects | CBC News

The U.S. Interior Department will pay $1.0B to TotalEnergies to relinquish two offshore wind leases (Carolina Long Bay ~$133M; NY/NJ ~$795M), with TotalEnergies committing to invest the refunded amounts in a Texas LNG plant and oil & gas activities. The deal signals a politically driven shift that increases regulatory and execution risk for U.S. offshore wind while redirecting capital to fossil fuels. Ongoing litigation and recent court actions that allowed other East Coast projects to resume highlight continued legal and market friction in the sector.

Analysis

This deal crystallizes a policy-driven reallocation of capital from offshore wind to LNG that will raise the political risk premium on US renewables development for the next election cycle. Expect a measurable step-up in WACC for merchant offshore projects (we estimate +150–300bps on project-level discount rates within 6–18 months) as developers price potential future pay-to-not-build or permit-reversal risk into bids and offtake discussions.

On the supply-chain side, OEMs, cable suppliers and installation vessel owners face a demand cliff concentrated in the next 12–36 months: lost East Coast megawatts free up turbine capacity and jack-up/AHTS vessel slots, pressuring utilization and margins and forcing either inventory drawdown or lower new-build orders. That creates a two-speed market — public integrators with diversified orderbooks will be insulated, while pure-play offshore suppliers will see outsized downside and accelerated consolidation.

Macro and commodity linkages are asymmetric: redirecting capital to US LNG creates a multi-year tail of higher US export capacity and sustained domestic gas demand that can lift Henry Hub into a structurally higher band if global demand surprises (6–24 months to manifest in flows). The main reversal paths are legal defeats to the payout, a change in federal administration, or a large, near-term gas price shock that changes the economics of onshore vs offshore investment decisions.

Key Decisions for Investors

• Long Cheniere Energy (LNG) — 12–24 month horizon. Buy stock (or 12–18 month call spread) to capture higher contracted volumes and potential third-party regas/jettison economics; target 20–40% upside vs 25–30% downside from construction/regulatory delays. Size as a directional LNG exposure, hedge with short Henry Hub futures if wanting cap on domestic gas-price risk.
• Long TotalEnergies (TTE) with hedge — 6–12 months. Buy shares on weakness and sell 9–12 month covered calls to monetize near-term sentiment; expected IRR from redeployed capital into higher-return US gas assets > integrated renewables margin but offset by ESG multiple compression. Use 25–40% position trim on 15–20% adverse move.
• Pair trade: short offshore-equipment exposure / long regulated coastal utility (short ORSTED or SGRE.MC; long D) — 6–12 months. Short pure-play OEMs or large European offshore integrators vulnerable to US policy headwinds and lower utilization, paired with long Dominion Energy (D) to capture rate-base resilience and state-level pushback upside; target asymmetric 2:1 reward:risk.
• Buy downside protection on renewable developers — 9–18 months. Purchase puts or long-dated put collars on a basket of offshore-wind-exposed equities to hedge portfolio exposure to a policy-induced write-down wave; keep hedges small-cost relative to potential project-level impairments.