Geothermal Energy Market Size & Share Analysis - Growth Trends and Forecast (2026 - 2031)

Global Geothermal Energy Market Trends and Insights

Rising Government Incentives & FiTs for Baseload Renewables

Feed-in tariffs and capacity payments are reshaping project economics by locking in revenue streams that neutralize exploration risk. Indonesia lifted its geothermal tariff to IDR 1,450 per kWh in 2025, a 12% premium that accelerated well-field work in Sumatra and Sulawesi. Turkey extended its tariff guarantee to 2030, triggering eight new binary-cycle plants totaling 320 MW. Kenya introduced sovereign drilling insurance that now covers up to 70% of well losses, directly addressing the single largest barrier to private finance. The European Union shortened geothermal permitting to below 18 months, improving project lead times and bankability. These moves convert speculative acreage into investable assets in markets where solar and wind curtailment already exceeds 15%.

Growing Deployment of Geothermal Heat Pumps

Ground-source heat-pump installations are creating a parallel demand channel that is independent of electricity generation. A 30% U.S. federal tax credit drove a 41% year-on-year jump in residential systems during 2025 in cold-climate states. Germany issued 87,000 new permits as gas boilers are phased out under the Building Energy Act. Sweden retrofitted district-heating plants with large-scale pumps that cut operating costs by 35% and improved seasonal performance ratios. Japan earmarked JPY 18 billion in subsidies for commercial retrofits, pursuing a 20% fossil-fuel reduction in buildings by 2028. Contractors see this segment as high margin and low risk because shallow drilling avoids deep subsurface uncertainty.

Heightened Energy-Security Needs for 24/7 Green Power

Geopolitical disruptions have pushed regulators to mandate firm renewable capacity. The European Union now requires at least 15% of electricity from dispatchable renewables by 2030, explicitly including geothermal. Japan allocated JPY 50 billion for exploration subsidies in regions hit by blackouts during the 2024 winter peak. South Korea’s utility signed a 20-year PPA paying a 22% premium for a 50 MW project that will supply semiconductor plants. The Philippines now requires at least 30% firm capacity in new renewable contracts, effectively mandating geothermal or storage pairing. These policies elevate geothermal from a niche option to a grid-stability necessity.

Repurposing Idle Oil & Gas Wells for Closed-Loop Geothermal

Closed-loop systems lower exploration risk by using known well paths. Chevron and Baker Hughes began retrofitting 12 depleted wells at California’s Salton Sea in 2025, targeting 5 MW online by Q4 2026 at capital costs 40% below greenfield geothermal. Eavor Technologies achieved an LCOE of EUR 72 per MWh in a German demonstration without induced seismicity concerns. The U.S. Wells of Opportunity program is cataloging 2.3 million orphaned wells, with 18,000 already flagged for temperatures above 150 °C. Saudi Aramco is assessing closed-loop systems to displace oil used for steam injection, highlighting oil-field expertise migration into geothermal. Development cycles in proven basins are dropping from seven years to under three.

High Upfront Drilling Risk & Capex

Exploration wells succeed only 55%-65% of the time in frontier basins, with dry-hole costs up to USD 8 million, making financing difficult. Drilling consumes 40%-50% of total capex, and one failed well can sink a 20 MW project if permeability is poor. Kenya’s Menengai field saw only a 38% success rate, causing USD 47 million in write-offs and 18-month delays. Indonesia’s Sarulla project ended 23% over budget due to unexpected reservoir compartmentalization. Risk-mitigation funds cover part of the loss, but developers remain exposed to reservoir performance uncertainty, steering capital toward retrofits with known subsurface data.

Cost-Competitive Pressure from Solar & Wind

Weighted-average LCOE for utility-scale solar fell to USD 36 per MWh and onshore wind to USD 38 per MWh in 2025, while geothermal averaged USD 68 per MWh. Record-low solar bids under USD 17 per MWh in the Middle East widen the gap further. Auctions in Spain and Australia favored solar paired with batteries over geothermal despite rising curtailment rates. Developers respond by bundling ancillary grid services and targeting industrial offtakers that need an uninterruptible supply.

*Our updated forecasts treat driver/restraint impacts as directional, not additive. The revised impact forecasts reflect baseline growth, mix effects, and variable interactions.

Segment Analysis

By Plant Type: Flash Dominates but EGS Gains Pace

Flash-steam plants represented 47.50% of capacity in 2025, reflecting their long track record in high-enthalpy zones across Indonesia and the Philippines. The segment benefits from established supply chains and proven reservoir management practices, keeping drilling risk moderate. However, the global geothermal energy market size for Enhanced Geothermal Systems is projected to expand at an 18.80% CAGR to 2031 as shale-style stimulation creates reservoirs in previously uneconomic hot-dry-rock formations. Pilot successes in Nevada and Utah validated cost benchmarks near USD 4.2 million per MW, on par with binary plants in lower-temperature fields. Dry-steam configurations persist at legacy sites like The Geysers but face a gradual decline as vapor-dominated fields deplete. Binary-cycle technology continues to serve low-enthalpy markets in Europe, where organic Rankine turbines cut water use by 85%, strengthening the global geothermal energy industry mix.

EGS momentum is altering supply-chain dynamics. Service companies with horizontal-drilling expertise are entering the market, increasing competition for casing, proppant, and stimulation crews. Equipment vendors respond with modular surface plants that shorten construction timelines. Combined-cycle hybrids that co-locate solar collectors with geothermal wells are emerging in regions with strong isolation, adding daytime output without new turbines and nudging the global geothermal energy market toward integrated renewable hubs.

By Application: District Heating Moves into the Spotlight

Electricity generation held 59.4% of 2025 capacity, supported by baseload PPAs in emerging economies. Yet, the global geothermal energy market share for district heating and cooling is set to grow rapidly, with the segment advancing at a 14.5% CAGR through 2031. Paris drilled six new doublets in the Dogger aquifer, and Reykjavik Energy already supplies 95% of buildings with geothermal heat at costs 40% below natural gas. Industrial process heat in food and chemical plants is also expanding, although from a smaller base, thanks to corporate decarbonization targets.

Revenue diversification is improving project economics. Heat-only projects avoid turbine costs and reach breakeven sooner, enticing municipal utilities with limited capital budgets. The global geothermal energy market size for heat applications benefits from year-round load factors and local demand elasticity. Developers increasingly co-locate heat and power facilities to maximize reservoir utilization and lengthen field life. Direct-use clusters in China’s North China Plain illustrate this integrated model, where shallow aquifers supply both residential heating and greenhouse agriculture at one-third the cost of coal boilers.

Geography Analysis

Asia-Pacific held a 44.27% global geothermal energy market share in 2025 and is projected to grow at an 11.9% CAGR through 2031, supported by Indonesia’s plan to commission 3.3 GW of new capacity and the Philippines’ streamlined permitting framework.^{[1]Ministry of Energy and Mineral Resources, “Geothermal Policy Update 2025,” Government of Indonesia, esdm.go.id} Indonesia’s Pertamina Geothermal Energy added 165 MW across three Sumatra fields in 2025, and Star Energy completed a 110 MW expansion at Salak to prolong reservoir life by 18 years. Japan removed drilling limits near onsen resorts, opening 420 km² for exploration and prompting Mitsubishi Power to propose a 30 MW plant in Beppu slated for 2027. China continues to focus on direct-use heating; shallow aquifers in the North China Plain now supply residential heat at one-third the cost of coal boilers.

North America is experiencing a resurgence as the U.S. Bureau of Land Management issued 47 leases covering 78 000 acres in 2025, attracting USD 142 million in bonus bids, the highest since 2008.^{[2]U.S. Bureau of Land Management, “Geothermal Leasing Statistics 2025,” U.S. Department of the Interior, blm.gov} Ormat Technologies expanded the Steamboat complex by 18 MW using binary cycles that tap 155 °C fluids formerly deemed sub-economic.^{[3]Ormat Technologies, “Platanares Acquisition,” Ormat Investor Update, ormat.com} Canada’s CAD 50 million exploration fund targets retrofits in depleted gas wells, while Mexico’s Comisión Federal de Electricidad maintains 963 MW but lacks fresh projects after 2015 budget cuts.

Europe, the Middle East, and Africa reveal contrasting trajectories. Turkey reached 1.7 GW after adding 95 MW of binary-cycle capacity in 2025 under a 10-year tariff guarantee. Iceland’s installed base is steady at 755 MW, with developers now exporting renewable hydrogen from geothermal electrolysis.^{[4]National Energy Authority, “Iceland Geothermal Capacity 2026,” Government of Iceland, nea.is} Kenya lifted its capacity to 985 MW after completing two 35 MW units at Olkaria V, and a further 140 MW is planned at Olkaria I by 2027. Ethiopia’s Tulu Moye project secured a USD 800 million package to target 520 MW by 2029, while Chile’s only operating plant remains Cerro Pabellón at 48 MW amid high Andean transmission costs.