Letter from Leadership: EDF 2025 Year-in-Review and Looking Forward to 2026

The DOE's Office of Energy Dominance Financing announced a review and restructuring of roughly $104 billion of prior administration financing, having de‑obligated or revised over $83.6 billion (≈$29.9B de‑obligated and $53.6B revised) and eliminated about $9.5B in wind/solar projects, while retaining roughly $289 billion in available loan authority. EDF closed three loans totaling $4.1 billion in late 2025 (Constellation Crane restart, an AEP transmission reconductoring project, and Wabash Valley's coal‑to‑fertilizer project) and is prioritizing financing for nuclear, fossil fuels, critical minerals, geothermal, grid/transmission, and manufacturing to boost energy security, grid reliability and lower consumer costs.

Analysis

Winners are incumbents in baseload and grid infrastructure: regulated utilities (AEP), nuclear developers (Constellation/CEG), coal-to-products players, and critical‑minerals/mining supply chains because DOE offers ~$289B of lending capacity and has already reallocated ~$83.6B — including removing ~$9.5B of intermittent wind/solar — which materially lowers financing costs and raises pricing power for financed firms over 6–36 months. Losers are late‑stage, financing‑dependent utility‑scale wind and solar developers and project‑finance lenders; expect slower new renewable capacity additions vs. consensus by 12–24 months unless private capital fills the gap.

Tail risks include swift legal/regulatory pushback, a 100–300bp rise in Treasury yields that undermines project economics, or nuclear project cost overruns that exceed DOE commitment—each could reverse sentiment in weeks–quarters. Hidden dependencies: DOE loans still rely on co‑financing, EPC supply chains, and state permitting; bottlenecks in graphite/steel/uranium could delay benefit realization by 12–36 months. Key catalysts: tranche announcements (> $500M) in next 30–90 days, Henry Hub > $6/MMBtu or oil > $90/bbl would accelerate fossil/nuclear demand.

Trade implications: favor 6–18 month longs in regulated utilities and select nuclear exposure, overweight uranium and critical‑minerals miners over 12–36 months, and short select solar ETF/exposed names that lose DOE support. Use options to buy asymmetric upside (LEAP calls on CEG/AEP) and protect shorts with put spreads on TAN or FSLR for 3–9 months. Monitor DOE loan announcements and energy price thresholds weekly to scale positions and set objective stop/profit levels.

Key Decisions for Investors

• Establish a 2–3% portfolio long in AEP (ticker AEP) with a 6–18 month horizon; target +25–40% upside if DOE-backed transmission projects win 2–4 large awards; set stop loss at -12% and take profit at +30%.
• Establish a 1.5–2% long in Constellation Energy (ticker CEG) or equivalent nuclear developer exposure; buy 9–18 month LEAP calls (or 6–12 month call spread) sized to 1–2% notional to capture re‑rating from DOE financing; sell 30% of position at +40% and cut at -15%.
• Create a 1.5% long position in Global X Uranium ETF (URA) for 12–36 months to play supply squeeze and renewed nuclear build; add more if DOE announces ≥$1B in nuclear loans within 90 days.
• Short 1.0–2.0% of portfolio in Invesco Solar ETF (TAN) or high‑beta solar names (e.g., FSLR) over 3–9 months; hedge with a 3–6 month put spread (buy 20% OTM put, sell 10% OTM put) to limit downside and profit from repricing of DOE capital; cover if TAN falls >25% or if DOE re‑commits ≥$2B to utility‑scale solar.
• Monitor DOE weekly announcements for loans/commitments >$500M and energy price triggers (Henry Hub > $6/MMBtu, Brent > $90/bbl) over next 90 days; if DOE awards ≥$5B to fossil/nuclear within 6 months, increase energy/utilities and materials exposure by +3–5%.