The Power Markets Case for Geothermal: Firm, Dispatchable, and Priced Like Nothing Else on the Grid

Noreva, an energy market data and analytics provider (formerly Karbone Research), tracks how new generating technologies enter the merit order and reprice the resources around them. Enhanced geothermal is the clearest case in front of US power markets today: a resource with essentially no fuel cost that hyperscalers are now contracting for firm, round-the-clock delivery, and that state regulators are naming by name in clean-firm procurement orders. This piece works through how that combination, near-zero marginal cost paired with real dispatch flexibility, behaves inside organized markets, what it does to power prices at the margin, and how it should be classified and valued.

What Is New in Geothermal: Enhanced Systems, Hyperscaler Offtake, and State Mandates?

Three things changed in 2026. First, enhanced geothermal systems (EGS), which borrow horizontal drilling and fracturing techniques from oil and gas to create a reservoir where a naturally permeable one does not exist, moved from pilot to contracted scale. Fervo Energy and Google signed a 396 MW power purchase agreement for the Cape Station EGS GeoCluster in southwest Utah on September 1, 2026, with an option for Google to expand offtake to nearly 1 GW by June 2030 (Fervo Energy, September 1, 2026). Fervo’s CEO, Tim Latimer, called it proof that “EGS is ready to power the next generation of computing infrastructure” (Fervo Energy, September 1, 2026).

Second, Nevada has become the proving ground for utility-scale geothermal offtake tied to data center load. Ormat Technologies signed a long-term geothermal PPA with NV Energy for up to 150 MW of new capacity to support Google’s Nevada operations, enabled through NV Energy’s Clean Transition Tariff and subject to Public Utilities Commission of Nevada approval expected in the second half of 2026 (Ormat Technologies investor relations press release, February 17, 2026). Google’s Briana Kobor described it as “a repeatable framework that fully covers all costs associated with our electric service” (Ormat Technologies, February 17, 2026). Two and a half months earlier, Zanskar had signed a separate 20-year PPA with NV Energy for 100 MW of what the company calls “reliable, baseload geothermal power,” contingent on approval of NV Energy’s 2026 Integrated Resource Plan (Zanskar, May 8, 2026).

Third, procurement policy caught up. The CPUC voted on February 26, 2026 to order 6,000 MW of new clean energy and storage net qualifying capacity through 2032, requiring that at least 25 percent carry “the attributes associated with clean, firm power and/or long-duration energy storage,” and naming geothermal among the eligible technologies (CPUC, February 26, 2026). Federal research spending predates that order: the Department of Energy’s Enhanced Geothermal Shot, launched September 8, 2022, targets a 90 percent cost reduction to $45 per megawatt-hour by 2035 (DOE, September 8, 2022), backed by a US Geological Survey estimate of 135 GW of potential EGS generation in the Great Basin alone, the resource base the Nevada and Utah deals above are drawing from (EIA, Today in Energy, February 19, 2026, citing USGS).

How Does a Zero-Fuel-Cost, Dispatchable Resource Interact With Wholesale Power Markets?

Geothermal’s marginal cost of energy is close to zero because there is no commodity to buy: the input is heat already in the ground, unlike gas priced off Henry Hub or a regional basis point. That puts it, on a pure cost basis, at the front of the bid stack alongside nuclear, wind, and solar, resources that bid in ahead of anything burning fuel because running costs them almost nothing at the margin. What distinguishes geothermal from the rest of that group is that it is not weather-dependent: the US Energy Information Administration describes it as providing “carbon-free, renewable, continuous power throughout the day and season” that is “not dependent on the weather” the way wind and solar are (EIA, Today in Energy, February 19, 2026).

“Continuous” is not the same as “fixed,” though. Fervo’s own production data from its Project Red site in Nevada shows the opposite: a field trial covering five cycles of 12-hour charge and discharge periods “demonstrat[ed] the ability to curtail, store, and dispatch energy on half-day cycles, enabling load-following generation profiles that deliver more power during peak demand hours” (Fervo Energy, April 13, 2026). The mechanism, FervoFlex, is in-reservoir energy storage: the well field can be throttled back to let pressure and heat build, then produced harder later to capture a higher-value hour. That is a real opportunity cost, not a free option, since reservoir management has physical limits on how far output can be shifted without degrading long-term performance. Geothermal’s dispatch profile is a choice made against a price signal rather than a constraint imposed by wind speed or cloud cover.

That has direct implications for how geothermal behaves during the hours that matter most in CAISO: the evening ramp. Noreva’s own coverage of the California market describes a duck curve that “is not static,” where “the ramp magnitude and timing shift” as solar and storage capacity grow, and where the evening window functions as much as a pricing event as a dispatch event, per Noreva’s CAISO power coverage. CAISO’s battery fleet has already been built to chase that window, charging on negative midday prices to discharge into the evening peak. A flexible geothermal resource competes in that same window on different terms: a four-hour battery is duration-limited and depends on midday solar surplus to recharge, while a geothermal reservoir can sustain a shifted output profile over a much longer horizon, at the cost of some of its own future flexibility. Both show up as “dispatchable” in a capacity table; the physics behind that word are not the same asset.

Is Geothermal Baseload, Intermittent, or Something New?

Neither label fits cleanly, and forcing one onto it obscures the more useful answer: geothermal, particularly EGS with in-reservoir storage, is firm, dispatchable-within-reservoir-limits capacity. It is not intermittent, because its output does not depend on a weather variable outside the operator’s control, and it is not classical baseload either, since baseload implies a constant, undifferentiated output level regardless of price. FervoFlex’s demonstrated 12-hour charge and discharge cycling is, by definition, a departure from flat output; the resource is shaped to price.

Regulators are already accrediting it accordingly, even if the label lags. The CPUC’s clean-firm procurement bucket is defined around an 80 percent-plus annual capacity factor threshold rather than a technology name, with geothermal named as eligible alongside solar, wind, and storage (CPUC, February 26, 2026). Noreva’s CAISO capacity coverage lays out the System, Flexible, Local, and Mid-Term Reliability RA categories any firm resource has to clear, where accreditation reflects expected contribution during critical conditions rather than nameplate capacity. In CAISO, a geothermal plant’s qualifying capacity is set through the Resource Adequacy process governed by the CPUC’s Qualifying Capacity Methodology Manual, rather than by a published technology-class rating of the kind PJM uses.

Resource Comparison: Geothermal vs. Gas Combined-Cycle vs. Solar-Plus-Storage vs. Nuclear

How Would Geothermal Affect Power Prices at Scale?

The logic runs through the hours that matter most, rather than the full year. A geothermal resource with in-reservoir storage can concentrate output in the hours where price is highest, which today in CAISO is overwhelmingly the evening ramp described above. In those hours, a flexible geothermal fleet competing alongside batteries would add zero-marginal-cost supply into a window gas currently sets the price for, the textbook mechanism for compressing a scarcity premium: more supply available when the system is short pushes that hour’s clearing price toward the next-cheapest resource on the stack. Noreva’s coverage of ELCC-driven asset valuation makes the same point from the capacity side: as more of an hour’s reliability need is met by highly accredited resources, the marginal capacity value, and the premium new entrants can command, both compress.

What limits that effect today is scale, not mechanism. The PPAs above total roughly 650 MW of new geothermal offtake announced in 2026, against a national installed geothermal base of 2.7 GW (EIA, Today in Energy, February 19, 2026), a small fraction of a national fleet measured in the hundreds of gigawatts. A resource this size does not move a hub price on its own; it takes capacity revenue and clean-firm premium away from batteries, gas peakers, and merchant renewables competing for the same evening-ramp dollars, well before it is large enough to visibly bend the power price curve itself. The price effect scales with how much of the USGS’s estimated 135 GW of Great Basin EGS potential actually gets built; this piece does not put a near-term number on it.

Fetched Geothermal Projects and Procurement Programs, 2022-2026

Why Are Offtakers Paying a Premium for Firm Clean Power?

Every deal fetched for this piece is structured as a power purchase agreement carrying explicit capacity attributes rather than a plain energy sale. Google’s framing of the Nevada deal, quoted above, makes the point directly: the offtaker pays to remove its own hourly matching problem, buying more than megawatt-hours. A hyperscaler running data centers around the clock must match its load with 24/7 carbon-free generation or fill gaps with market purchases and RECs. A resource that runs continuously and does not depend on weather closes that gap directly, which is why these buyers pay for the firm and clean attributes as a bundle, rather than sourcing energy and environmental attributes separately the way a buyer might combine a merchant PPA with unbundled RECs under looser matching commitments tracked in Noreva’s environmental attributes coverage.

The contract logic mirrors Noreva’s coverage of gas and battery tolling agreements: a fixed capacity payment compensates the owner for standing ready, while the offtaker captures dispatch value. Geothermal PPAs collapse that structure into one instrument, since there is no fuel leg to toll and the reservoir owner already holds the flexibility Fervo’s field data demonstrates. What offtakers underwrite instead is duration and reliability risk over a 15-to-20-year term, which is why the Nevada contracts run that long and remain contingent on regulatory approval before the capacity counts toward anyone’s balance sheet.

How Does Noreva Value a Geothermal Project Against Its Power and Capacity Curves?

A geothermal PPA, like a toll, is only as reliable as the curves behind it. Noreva’s CAISO power coverage models hourly price shapes by month and year to capture how the evening-ramp premium and midday trough evolve as solar and storage capacity change, the same windows a flexible geothermal asset would compete to capture. Its CAISO capacity coverage pairs fundamentals-based modeling with trader-informed pricing inputs across the RA categories above, publishing Low, Base, and High scenarios rather than a single point forecast. For a developer or offtaker underwriting a Nevada or Utah project, that range is the right frame: value the fixed payment against the capacity curve, value merchant upside against the power curve’s evening-ramp premium, and stress-test both the way Noreva’s asset valuation work already does for tolled gas and battery assets, via a forecast platform spanning 1-to-5-year transaction-based forwards through 25-year fundamentals-based merchant curves.

Frequently Asked Questions

How will new geothermal projects interact with the US power market?

They enter at the front of the bid stack on cost, since there is no fuel to price in, and compete for the same hours batteries currently chase: the evening ramp and other scarcity-priced windows. Unlike solar or wind, their output is not weather-bound, so they compete on reservoir management and contract structure rather than resource availability.

How could geothermal projects affect power prices?

At the scale announced through 2026, roughly 650 MW of new PPAs against a 2.7 GW existing US fleet, the effect on hub prices is not yet visible. At larger scale, flexible geothermal dispatched into scarcity hours would compress the scarcity premium in those hours, the same mechanism batteries already exert, while capturing capacity and clean-firm revenue that would otherwise go to other resources. This is a logic-based, scenario-dependent conclusion. It is not a Noreva price forecast for this piece.

Does geothermal fit as baseload, intermittent, or something new?

Something new: firm, dispatchable-within-reservoir-limits capacity. It is not intermittent, because output does not depend on weather. It is not classical baseload either, because enhanced geothermal with in-reservoir storage has demonstrated the ability to shift output on 12-hour cycles to chase price. Regulators are already accrediting it functionally, through capacity-factor thresholds rather than technology labels.

How is geothermal dispatchable if it has no fuel cost?

Dispatch flexibility in enhanced geothermal comes from managing the underground reservoir rather than from fuel supply. Fervo Energy’s field data shows wells throttled back to let heat and pressure build, then produced harder later to shift output toward higher-value hours, a real opportunity cost measured in reservoir performance rather than a fuel bill.

Value Your Next Geothermal Asset Against Transaction-Aligned Curves

A firm, zero-fuel-cost resource still needs market context to be valued correctly: what its capacity is worth against CAISO’s RA framework, what its energy is worth in the hours it chooses to run, and what its clean-firm attributes command against shifting ELCC accreditation. Noreva delivers transaction-aligned power and capacity curves for CAISO and the western markets, built for project finance teams, asset owners, and trading desks underwriting the next wave of firm clean generation.

Book a demo to see how Noreva’s power and capacity forecasts support geothermal project valuation.