Denmark Geothermal Energy - Market Share Analysis, Industry Trends & Statistics, Growth Forecasts (2026-2031)

Denmark geothermal energy market size in 2026 is estimated at 31.06 megawatt, growing from 2025 value of 21 megawatt with 2031 projections showing 219.68 megawatt, growing at 47.90% CAGR over 2026-2031. This report is Segmented by Plant Type (Dry Steam Plants, Flash Steam Plants, Binary Cycle Plants, Combined Cycle/Hybrid Plants, and Enhanced Geothermal Systems) and Application (Electricity Generation, District Heating and Cooling, and Industrial Process Heat). The Market Size and Forecasts are Provided in Terms of Installed Capacity (GW).

Denmark Geothermal Energy Market Trends and Insights

Rapid Decarbonization Targets for District-Heating Utilities

More than 400 municipal utilities must eliminate fossil-fuel backup systems by 2030, transforming geothermal from an optional resource to an operational necessity. Mandatory heat-planning filings reveal multi-year demand schedules, enabling developers to underwrite projects with 20-year heat-purchase contracts that cut offtake risk. Early movers such as HOFOR deploy advanced supervisory control systems to blend low-temperature geothermal heat with biomass and waste-to-energy feedstocks, lowering delivered heat costs under tightening CO₂ caps. The regulatory timetable, therefore, creates a flywheel: confirmed demand de-risks finance, financed projects prove technical success, and proven success accelerates further demand. Utilities adopting geothermal sooner lock in a secure heat supply and avoid later peak-demand surcharges on limited drilling rigs and service crews.

Phase-Out of New Natural-Gas Boilers from 2028

Denmark’s BR18 building code closed the door on fossil-fuel boilers in new construction inside district-heating zones, and the 2028 national ban eliminates gas as a fall-back option even in legacy buildings. State grants from Fjernvarmepuljen reimburse up to DKK 20,000 per converted boiler, channeling households toward network hookups and pushing utilities to secure renewable baseload capacity. Because binary-cycle plants require 3-5 years from seismic study to commissioning, the 2028 milestone perfectly matches developer timelines and is already visible in municipal tender schedules. Cutting gas out of the supply stack also raises the capacity factor requirements for heat pumps that depend on low-cost power, thus improving the load-factor economics of steady geothermal output. The boiler ban, therefore, removes lower-capex fossil competition and hardwires geothermal into future network expansion blueprints.

Uncertain Subsurface Temperature Gradients Outside Zealand

Exploration wells in Jutland show variable gradients that swing from 20 °C/km to under 15 °C/km within short lateral distances, forcing developers to budget up to 50% more for seismic, coring, and step-out drilling before locking down full field development. Lenders price this geological uncertainty into higher interest-rate spreads, particularly for municipalities whose heat tariffs are capped by consumer-protection rules. Smaller utilities lacking diversified revenue bases are wary of dry-hole risk that could strand millions in sunk exploration cost, shrinking the pool of feasible offtakers. While EGS pilots promise to widen the resource base, their learning curve and distinct permitting paths mean commercial deployment remains several years away. Until exploration data density improves, the Denmark geothermal energy market will continue to cluster around Zealand’s proven aquifers.

Other drivers and restraints analyzed in the detailed report include:

• Abundant Low-Temperature Sedimentary Basins Under Zealand
• Industrial-Scale Heat-Pump Cost Declines
• Competition from Surplus Wind Power-to-Heat

Segment Analysis

Binary-cycle facilities represented 66.12% of installed capacity in 2025, and their share of the Denmark geothermal energy market size is forecast to stay above 70% through 2031 as 110 MW of additional binary projects reach completion. The segment’s 47.35% CAGR reflects both subsurface temperature suitability and the ability to add ORC turbines without incurring seismic risks that accompany flash-steam designs. Innargi’s Skejby phase, commissioned in October 2025, showcases 55 °C brine lifted to 85 °C via ammonia heat pumps, achieving 75-80% system efficiency.

Enhanced geothermal systems remain in the pilot stage, led by Aalborg’s 2 MW Heat4Ever coaxial wellbores. Flash-steam and dry-steam technologies are absent, since Denmark lacks ≥150 °C reservoirs. Continued heat-pump cost reductions toward EUR 300-400 per kW by 2027 should further widen the cost gap in favor of binary construction, positioning the segment to approach 198.6 MW by 2031 if Copenhagen’s 26 MW Bunter Sandstone project hits performance milestones.

Complete Report Scope:

• By Plant Type
  • Dry Steam Plants
  • Flash Steam Plants
  • Binary Cycle Plants
  • Combined Cycle/Hybrid Plants
  • Enhanced Geothermal Systems (EGS)
• By Application
  • Electricity Generation
  • District Heating and Cooling
  • Industrial Process Heat

List of Companies Covered in this Report:

• Innargi A/S
• A.P. Moller Holding A/S
• Danfoss A/S
• Ramboll Group A/S
• Welltec A/S
• NIRAS A/S
• Hovedstadens Geotermi P/S
• Gate 21
• Ross DK A/S
• De Rigo Thermal A/S
• Enopsol A/S
• GEOOP A/S
• GEOLOG International
• Baker Hughes Denmark
• Halliburton Denmark
• Ørsted A/S (geothermal JV interests)
• TotalEnergies Denmark (CCS-geo synergies)
• E.ON Denmark
• Siemens Energy Denmark
• AFRY Denmark
• COWI A/S

Additional Benefits:

• The market estimate (ME) sheet in Excel format
• 3 months of analyst support