Both fleets lean on the Section 45U production tax credit, but Vistra's fully merchant reactors have far less insulation than Constellation's PPA-hedged fleet if the credit gets rolled back.
The mechanism. Section 45U pays existing nuclear plants up to 1.5 cents per kWh (with prevailing wage) for every megawatt-hour they generate, through 2032. It isn't a flat subsidy — it's a price-linked floor. The credit is worth its full value only when a plant's power sells for $25/MWh or less; it shrinks as prices rise and hits zero entirely once power clears $43.75/MWh. The 2025 reconciliation bill left the 2032 sunset untouched, but a future Congress hunting for revenue, or a Treasury tightening the "gross receipts" definition around new co-located data-center deals, could shrink or eliminate it well before then. That's the live risk: not repeal tomorrow, but a phase-down that lands hardest on whichever fleet is most dependent on the credit to clear break-even in a merchant market — versus a fleet that's already hedged into long-term contracts where the credit is a rounding error.
Who cashes in either way. Constellation (CEG) runs roughly 22.8 GW of nuclear, the largest fleet in the country, and has spent two years converting merchant exposure into contracted revenue — the Crane restart is underwritten by a 20-year Microsoft PPA, and additional hyperscaler deals lock in prices well above the 45U floor. When power sells north of $43.75/MWh under a fixed contract, the credit is already zero in the math investors care about; a rollback barely moves the model. GE Vernova (GEV) and BWXT cash in on the buildout regardless of 45U's fate — GEV on turbines/grid equipment for new gas and nuclear capacity, BWXT on reactor components and Navy/DOE work insulated from merchant power prices entirely. Cameco (CCJ) benefits from fleet uptime and new-build demand for fuel, a volume story more than a 45U story.
Constellation hedged its nuclear fleet into 20-year contracts; Vistra left more of its reactors exposed to the same tax credit Congress could shrink.
Who is exposed. Vistra (VST) carries roughly 6.4 GW of nuclear (the former Energy Harbor fleet) sold largely into ERCOT and PJM merchant markets. Less of that output is locked behind long-duration PPAs than Constellation's, meaning more of Vistra's nuclear cash flow still depends on the 45U floor showing up in quarterly numbers when power prices dip. A credit phase-down hits Vistra's uncontracted megawatt-hours directly. Talen (TLN), similarly merchant-heavy in PJM even after the Susquehanna PPA activity, sits in the same bucket. NuScale (SMR) and Oklo (OKLO) are a different risk entirely — pre-revenue SMR developers whose economics assume 45Y (the successor credit for new builds) survives; they're exposed to a broader nuclear-incentive rollback, not 45U specifically.
The play. This is a hedge-quality spread, not a growth call: Constellation's contracted book makes it the defensive nuclear name into any tax-credit headline risk, while Vistra's merchant tilt makes it the more volatile way to trade the same underlying fleet. Watch for Treasury guidance narrowing what counts as "gross receipts" under co-located data-center deals — that technical rulemaking, not a repeal vote, is the nearer-term catalyst.
Source: original report ↗
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