Could Former Fracking Sites Be Used for Geothermal Heat Production?

By Abdul Ahad NazakatReviewed by Laura ThomsonSep 12 2025

As the UK accelerates its transition from fossil fuels, repurposing existing energy infrastructure presents economic and environmental opportunities. Former hydraulic fracturing sites, once sources of controversy, are now being evaluated as potential geothermal heat sources. The deep wells already drilled for oil and gas extraction could provide access to underground heat reserves, offering a path to renewable heating systems. Early conversion projects provide crucial data on this approach's technical and commercial viability.

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This article explores the potential of converting former fracking sites into geothermal heat sources in the UK, highlighting technical feasibility, economic considerations, and policy implications based on current demonstrator projects and research findings.

Case Study: Kirby Misperton KM8 Well Conversion

The Kirby Misperton site in North Yorkshire represents the UK’s first operational conversion of a former hydraulic fracturing well to geothermal heat production. The site, previously operated by Third Energy for fracking operations, has been converted by CeraPhi Energy to extract geothermal heat from deep underground formations.¹

Initial project assessments suggest that the converted 3-kilometer-deep well could supply heat for local applications by circulating water down the wellbore, where it absorbs heat from surrounding rock formations before being pumped back to the surface.²

National Resource Assessment

Research published in the journal Energies identified substantial conversion potential across the UK. Of 2,242 onshore hydrocarbon wells analyzed, 560 demonstrate potential for geothermal repurposing, with 292 currently operational.³

CeraPhi Energy’s assessment suggests approximately 680 oil and gas wells could potentially be converted, with concentrations of over 200 wells between Lincolnshire and the North-East.²

The economic advantage of well conversion lies in utilizing existing infrastructure. Government data indicates that typical geothermal heat projects cost between £2 to £4 million per MWth of capacity, with drilling representing the most expensive component.⁴ Converting existing wells eliminates this primary cost barrier, improving project economics.

Requirements and Limitations of Converting Oil and Gas Wells into Geothermal Heat Projects

Successful conversion requires wells to reach sufficient depths to access viable temperatures, typically 2-3 kilometers, for effective heat extraction. Many former oil and gas wells meet these depth requirements, though individual site assessment remains essential.

Technical difficulties include the need for equipment modifications tailored to geothermal operations, which differ substantially from conventional oil and gas systems.

Regulatory frameworks add another layer of complexity, as current rules allow only a short window between halting hydrocarbon production and mandating well abandonment. Policy adjustments will be necessary to create more flexibility and enable these wells to be converted for geothermal use.

Government Support Mechanisms

The UK government has implemented several funding mechanisms that support geothermal heat development.

Key initiatives include £22 million awarded to the Langarth Deep Geothermal Heat Network project in 2023 and the Green Heat Network Fund, providing £288 million for heat network projects through 2025.^5,6

Research by the British Geological Survey and Arup indicates geothermal heating projects could achieve carbon dioxide (CO₂) savings of approximately 2,400 tons annually compared to gas heating systems.⁷ Establishing the UK’s first National Centre for Geothermal Energy in 2024 demonstrates institutional commitment to sector development.⁸

Economic and Market Considerations of Geothermal Heat Sources

District heating networks represent the primary market application for geothermal heat sources. These systems enable efficient distribution of heat to multiple buildings, improving project economics through scale. Rural communities and industrial facilities with consistent heat demand present additional opportunities.

Operational costs remain a consideration despite reduced capital requirements. Heat distribution infrastructure, ongoing maintenance, and specialized technical expertise contribute to project expenses beyond initial conversion.

Integration with UK Energy Infrastructure

Geothermal heat sources provide consistent output that complements intermittent renewable electricity generation from wind and solar. This baseload heating capacity supports grid stability while reducing reliance on imported gas for heating applications.

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Once installed, the technology produces no direct operational emissions. Performance projections suggest that a 10 MWth-capacity geothermal facility could deliver 44 GWh of heat annually, achieving approximately 8,000 tons of CO2 savings per year.⁹

Community and Environmental Factors of Oil and Well Conversion

Repurposing wells addresses environmental concerns regarding abandoned infrastructure while establishing productive land use. Transitioning sites like Kirby Misperton from contested fossil fuel operations to renewable energy applications may also improve community acceptance.¹⁰

Geothermal operations could also provide local employment in areas previously reliant on oil and gas.

Importantly, geothermal heat extraction does not involve hydraulic fracturing, removing associated concerns such as induced seismicity.

Scaling Requirements and Future Development

Broader sector development requires several enablers. To facilitate assessments, regulatory modifications must extend timelines between hydrocarbon production cessation and well abandonment. Enhanced R&D funding could improve well performance optimization and temperature enhancement techniques.

Integration with district heating network expansion represents a critical scaling pathway. The government’s commitment of over £288 million to heat network development helps provide infrastructure for wider geothermal deployment.⁶ Standardized conversion procedures and performance assessment protocols would reduce project costs and technical risks, supporting commercial viability across multiple sites.

Performance Data and Commercial Viability

Early demonstrator projects provide essential performance data for assessing commercial scalability. Key factors include well depth, geological conditions, proximity to heat demand, and regulatory support mechanisms.

Long-term operational data from projects such as Kirby Misperton will inform economic modeling for future conversions. Temperature performance, system reliability, and maintenance requirements represent critical variables affecting project returns.

Is Turning Fracking Wells into Geothermal Sites the Future?

Repurposing former fracking wells for geothermal heat production represents a viable pathway to expand the UK’s renewable heat capacity.

Although economic and technical challenges remain, demonstrator projects provide valuable data for assessing scalability.

Success depends on continued government support, regulatory adaptation, and the demonstration of commercial viability through operational projects. The approach offers the potential to address UK heating decarbonization requirements while utilizing existing subsurface infrastructure.

References and Further Reading

1. Yorkshire Post. (2023). Owners of controversial fracking site in Yorkshire to turn it into a geothermal energy extraction facility instead. Available at: https://www.yorkshirepost.co.uk/business/owners-of-controversial-fracking-site-in-yorkshire-to-turn-it-into-a-geothermal-energy-extraction-facility-instead-4274370
2. Oil and Gas People. Former Fracking Site Transforms into Geothermal Energy Project in UK. Available at: https://www.oilandgaspeople.com/news/story/former-fracking-site-transforms-into-geothermal-energy-project-in-uk
3. Watson, S.M., et al. (2020). Repurposing Hydrocarbon Wells for Geothermal Use in the UK: The Onshore Fields with the Greatest Potential. Energies, 13(14), 3541. Available at: https://www.mdpi.com/1996-1073/13/14/3541
4. GOV.UK. (2024). Future of the subsurface: geothermal energy generation in the UK (annex). Available at: https://www.gov.uk/government/publications/future-of-the-subsurface-report/future-of-the-subsurface-geothermal-energy-generation-in-the-uk-annex
5. Power Technology. (2023). UK awards £22m for deep geothermal heating. Available at: https://www.power-technology.com/news/uk-government-deep-geothermal-heating/
6. GOV.UK. (2023). Thousands to benefit from low-cost heat in push to drive down energy bills. Available at: https://www.gov.uk/government/news/thousands-to-benefit-from-low-cost-heat-in-push-to-drive-down-energy-bills
7. Ground Engineering. (2023). White paper calls for more financial support for geothermal energy. Available at: https://www.geplus.co.uk/news/white-paper-calls-for-more-financial-support-for-geothermal-energy-19-07-2023/
8. Reece Foundation. (2024). Reece Foundation funds UK's First National Centre Launched to Advance Geothermal Energy in the UK. Available at: https://www.reece-foundation.org/reece-foundation-funds-uks-first-national-centre-launched-to-advance-geothermal-energy-in-the-uk/
9. UK Parliament. Written evidence submitted to Environmental Audit Committee. Available at: https://committees.parliament.uk/writtenevidence/110141/html/
10. CPRE North and East Yorkshire. (2023). Yorkshire Fracking Site to Geothermal Energy Hub. Available at: https://www.cpreney.org.uk/news/yorkshire-fracking-site-geothermal-energy-hub-sustainable-solution/

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