The rock was always there. The buyers weren't.

The evidence points to a demand-side explanation for the 2026 geothermal moment — data-center power purchase agreements, state decarbonization mandates, and federal geothermal tax credits — rather than drilling technology breakthroughs alone.

For half a century, enhanced geothermal, electricity from hot, dry rock that was never hot enough to make steam on its own, sat in the same bucket as fusion: technically possible, economically marginal, perpetually five years away. The rocks did not suddenly get hotter. The buyers did.

Three demand shifts converged at once. Hyperscale data centers needed around-the-clock clean power that does not depend on the sun shining or the wind blowing. State decarbonization mandates made firm clean energy legally required, not optional. Bipartisan federal geothermal tax credits brought new policy momentum that shifted project economics for developments previously considered unviable. Together those forces built a clock that drilling improvements alone had not yet built.

Ormat's 1+ gigawatt of operating capacity in the western U.S. is the incumbent case. The 61-year-old Reno firm is revisiting a dry-rock EGS pilot program — the earliest verifiable milestone is a 2013 Desert Peak 1.7-MW demonstration — in a new partnership with SLB at Desert Peak, because the demand side now justifies the risk. Conventional hydrothermal remains the workhorse. Enhanced geothermal is the new option on the menu. Both are 2026 bets on the same rule: clean firm power is finally worth paying for, so the rock that was always there is finally worth unlocking.