The Trump administration is touting approvals for oil-exporting hubs in the Gulf of Mexico—but no one seems to want to build them

The Biden-era permitting backlog briefly gave way to a Trump administration announcement that Texas GulfLink received licensing on Feb. 3, yet developer Sentinel Midstream declined to comment and other planned deepwater Gulf export projects remain stalled. U.S. crude production and exports exceed 4 million barrels per day, but VLCC loading constraints, shifting trade flows toward Europe, loss of anchor customers (e.g., Chevron at Enterprise’s SPOT) and EPA permitting/emissions issues for projects like Phillips 66’s Bluewater have eroded commercial support; analysts say new offshore terminals are unlikely to advance before a potential industry rebound around 2027.

Analysis

Market structure: Deepwater export terminal delays are a win for refiners and integrated majors that pivot to exporting higher-margin petroleum products (PSX, CVX) and a loss for midstream pure-play exporters (EPD, ENB, ET) facing potential stranded capex. Expect midstream bargaining power and returns on greenfield offshore projects to compress for at least 18–36 months until crude demand or tanker economics recover.

Risk assessment: Tail risks include a regulatory reversal or fast-track permitting that forces accelerated capex (low-probability, high-impact) and a Venezuela supply surge or global demand shock that cuts US export volumes by >10% into 2025. Immediate (days–weeks) impacts will be sentiment and share-price moves on permitting headlines; short-term (3–12 months) will determine anchor-customer commitments; long-term (2027+) decides whether projects are built or written down.

Trade implications: Favor relative-long refiners versus midstream: structural product-export demand should support PSX vs EPD/ENB underperformance over 3–12 months. Use defined-risk put spreads on ENB/EPD to hedge credit/capex write-down risk and consider modest bearish exposure to Brent/WTI (5–10% downside scenario into 2025) via 3–6 month put calendars.

Contrarian angle: The market may be underpricing the option-value of existing licenses (SPOT, Texas GulfLink); if macro improves by 2027, licensed owners could re-rate sharply. Consider small, time-staggered call-spread exposure to EPD/ENB (12–36 month) while keeping protective hedges — but beware immediate dilution/write-down headlines that can erase near-term gains.

Key Decisions for Investors

• Establish a pair trade: go long PSX 2–3% of portfolio and short EPD 2–3% (equal dollar) with a 3–12 month horizon; target 15–25% relative outperformance, stop-loss at 10% absolute on either leg. Rationale: refiners capture product-export margins while midstream faces commercial shortfall.
• Buy a 6–9 month put spread on ENB sized at 1–2% of portfolio to hedge capex/write-down risk: buy 25% OTM puts and sell 12.5% OTM puts (defined-risk). If permit delays >90 days or ENB/EPD announce >$200m writedowns, widen size to 3% and trim midstream equity exposure by 50%.
• Trim midstream IG/senior unsecured bond exposure (EPD/ENB/ET) by 20–30% over next 30 days; redeploy into PSX or CVX senior paper or AAA/IG energy utilities to reduce duration to permit-permit risk and preserve carry.
• If EPA/Coast Guard issues favorable permit developments within 60–120 days for any project, buy time-staggered 12–36 month call spreads on the licensor (EPD/ENB) sized at 1–2% to capture option re-rating; if permits are denied or anchor customers publicly exit, increase shorts by additional 2–3%.