The dry-steam geothermal power market is projected to grow at a 2.1% compound annual growth rate from 2026 through 2035, reaching a market index of about 123 by 2035 (2025 = 100), according to IndexBox’s baseline forecast. Growth is expected to come from firm renewable-power demand, repowering of older facilities and incremental development of high-enthalpy fields—not from a sudden expansion of the world’s limited dry-steam resource.
What the 2035 forecast actually measures
IndexBox describes a specialized but resilient market. Because publicly disclosed absolute market volumes are incomplete, its forecast uses an index rather than a global revenue or capacity total. The baseline assumes resource-constrained expansion, with no breakthrough that radically enlarges the dry-steam resource base.
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| Measure | Forecast | Qualification |
|---|---|---|
| Forecast period | 2026–2035 | IndexBox baseline scenario |
| Compound annual growth | 2.1% | IndexBox estimate for the period |
| Market index | About 123 in 2035 | 2025 = 100; an index, not disclosed absolute market volume |
| Dominant end use | Utility-scale generation | About 65% of end use, according to IndexBox’s vendor estimate |
Where growth is expected to come from
New construction is expected in high-enthalpy fields, but the base case gives substantial weight to repowering, life extension and efficiency upgrades at aging plants. Other uses include industrial process heat, cogeneration, district heating, remote electrification, data-center power and desalination cogeneration.
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Renewable electricity that is available continuously
Wind and solar output changes with weather and daylight. A properly managed geothermal field can supply firm, around-the-clock electricity and provide grid-stability and frequency-support value. That makes dry steam complementary to variable renewables rather than a direct substitute for every wind or solar project.
National Renewable Energy Laboratory scenarios hosted by the U.S. Department of Energy deploy 3–5 gigawatts of new geothermal capacity by 2035 alongside about 2 terawatts of combined wind and solar. Those are U.S. scenario outputs for geothermal as a category, not a global forecast for dry-steam plants alone, but they illustrate the role firm geothermal can play in a renewable-heavy system.
Policy and corporate procurement
Renewable portfolio standards, tax incentives, feed-in tariffs and corporate clean-power procurement can improve the economics of projects with high drilling and development costs. Support is especially important where a field needs long lead times before a plant can begin selling electricity.
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Industrial heat and emerging loads
Industrial customers may value a continuous supply of low-carbon steam as well as electricity. IndexBox also identifies data centers and remote operations as emerging sources of demand for clean, firm power. Cogeneration can use the same geothermal resource for electricity and useful heat, while district-heating and desalination projects can add revenue streams where local conditions permit.
How a dry-steam geothermal plant works
Dry steam is one of the three principal geothermal conversion technologies identified by the U.S. Department of Energy, alongside flash steam and binary cycle. It is a direct-use design: the reservoir naturally produces steam-dominated fluid, so the steam can be sent to the turbine without first flashing liquid water or transferring heat through a secondary working fluid.
- Production wells reach a vapor-dominated reservoir. The resource must contain naturally steam-rich, high-temperature hydrothermal fluid.
- Steam flows to the turbine. After appropriate gathering and conditioning, the steam expands through the turbine and spins a generator.
- Electricity is delivered to the grid or an on-site load. The turbine-generator set converts the steam’s energy into electrical output.
- Condensate is handled and frequently reinjected. Condensed geothermal water can be returned to the reservoir, subject to field design, chemistry and permits.
The resource is the limiting factor. DOE says dry-steam plants use hydrothermal fluids that are already mostly steam, “which is a relatively rare natural occurrence.” DOE also notes that steam technology remains in use at The Geysers in northern California, described as the world’s largest single source of geothermal power.
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Dry steam, flash steam and binary: the practical differences
All three technologies convert geothermal heat, but they require different reservoir conditions and plant equipment.
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Random freezes, missing sound and display glitches usually trace back to one bad driver. Find and replace yours safely.Free scan · under a minute| Comparison point | Dry steam | Flash steam | Binary cycle |
|---|---|---|---|
| Reservoir fluid | Naturally steam-dominated hydrothermal fluid | High-temperature hot water that flashes to steam when pressure drops | Lower-temperature geothermal fluid heats a separate working fluid |
| Does geothermal fluid enter the turbine? | Yes; steam is sent directly to the turbine | Separated steam drives the turbine; brine is handled separately | No; geothermal fluid stays outside the turbine loop |
| Resource availability | Relatively rare and geographically concentrated | Requires suitable high-temperature liquid resources | Can use lower-temperature resources and is geographically broader |
| Plant configuration | Direct steam path; comparatively straightforward where the resource is ideal | Flash vessels, separators and brine-management equipment are required | Heat exchangers and a secondary working-fluid loop are required |
| Typical market fit | Utility power and some cogeneration in steam-rich fields | Utility-scale power and combined heat applications in high-temperature fields | Power and heat from lower-temperature resources |
| Water and reinjection considerations | Condensate and reservoir management remain important | Brine, steam separation and reinjection must be managed | Geothermal fluid remains in a closed heat-transfer path relative to the turbine |
Dry steam can offer a direct turbine path, but that advantage does not remove exploration risk: the required vapor-dominated geology is uncommon. Binary plants broaden the usable temperature range, while flash plants occupy the high-temperature liquid-resource segment.
Where dry-steam development is concentrated
Asia-Pacific
IndexBox assigns Asia-Pacific about 40% of the market, the largest regional share in its estimate. Indonesia and the Philippines lead the region’s established geothermal activity. Electricity-demand growth and policy targets support new capacity, while permitting and project finance remain difficult.
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North America
North America accounts for an estimated 25%. California and Nevada contain mature fields, so near-term activity is expected to emphasize repowering, life extension and exploration in other western states rather than a broad wave of greenfield dry-steam construction.
Europe
Europe is estimated at 20%, concentrated in Italy and Iceland. Mature assets make life extension important, while enhanced-geothermal research could expand the wider geothermal opportunity even though it does not automatically create new natural dry-steam fields.
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Latin America
IndexBox estimates a 10% share. Mexico, Central America and the Andes have significant undeveloped potential, but political conditions, financing and exploration uncertainty slow project delivery.
Middle East and Africa
The region is estimated at 5%, with Kenya as the leader. Development-bank finance and rural-electrification programs support expansion, while infrastructure and skills shortages remain practical barriers.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.What can slow expansion through 2035
- Geology: Vapor-dominated, high-temperature reservoirs are uncommon and cannot be developed wherever a grid needs power.
- Drilling outcomes: Wells are expensive, and their temperature, permeability and steam productivity are uncertain until drilling is completed.
- Capital and schedule: Projects require substantial upfront investment, long permitting periods and lengthy construction timelines.
- Environmental and land-use issues: Water management, surface impacts, protected areas and community acceptance can delay or reshape projects.
- Financing and policy: Revenue support and risk-sharing are often needed to attract capital before resource performance is proven.
- Competing technologies: Falling costs for solar photovoltaic systems, wind and batteries can make alternative firming strategies more attractive in some markets.
The International Energy Agency’s The Future of Geothermal Energy, published 13 December 2024, says geothermal scale-up must address “project development risks, permitting and licensing processes, environmental concerns and social acceptance.” Those issues apply across geothermal technologies and are particularly significant for projects with uncertain drilling results.
What developers and utilities should watch
The forecast points to an incremental market, not an explosive one. Developers with producing fields can often reduce risk through reinvestment, improved reservoir management and turbine or plant upgrades. New projects will be most plausible where high-enthalpy resources, transmission access, supportive policy and experienced drilling capability align.
Hybrid configurations may also improve project economics by pairing geothermal’s firm output with variable renewable generation or storage. The exact design depends on the field, grid and industrial load; a hybrid label does not change the underlying requirement for a viable geothermal resource.
For the United States, DOE’s 2019 analysis identified potential for more than 60 gigawatts-electric of firm, flexible clean energy from geothermal by 2050. That figure covers geothermal broadly and is not a dry-steam-only target, but it underscores why utilities continue to value geothermal even as most new renewable capacity comes from wind and solar.
Bottom-line outlook to 2035
Dry-steam power remains a niche technology because nature supplies the necessary steam-dominated reservoirs only in limited places. Within that constraint, the market has a durable role: firm renewable electricity, industrial heat and reliable power for specialized loads. IndexBox’s 2.1% annual growth forecast reflects steady field development, repowering and efficiency work through 2035, with geology, permitting, finance and competition from solar-plus-storage limiting how quickly the sector can expand.
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