Why U.S. Geothermal Land Is Suddenly Attracting Bigger Bets

Published August 17, 2026

The U.S. geothermal industry is attracting a level of investment that would have been difficult to imagine only a few years ago. A June 2026 Bureau of Land Management (BLM) auction in New Mexico generated more than $16.5 million in total receipts from 47 geothermal lease parcels covering more than 152,000 acres. One 4,479-acre parcel received a winning bid of $701 per acre, bringing the value of that single tract to approximately $3.14 million. These figures stand out because geothermal development has historically faced significant exploration, drilling and capital risks. The latest auction therefore offers a useful indicator of changing expectations around the technology. The U.S. geothermal market is also developing beyond conventional power plants, with enhanced geothermal systems (EGS), improved drilling techniques and new corporate power purchase agreements creating additional interest. The 2025 U.S. Geothermal Market Report found that U.S. geothermal nameplate capacity reached 3.97 GW in 2024, up 8% from 2020, while 27 new power purchase agreements had been signed since 2020 as of June 2025. The question now is why developers are placing larger bets on geothermal resources and whether those investments can translate into commercially viable electricity generation.

Geothermal Lease Prices Are Rising

The New Mexico auction provides a clear measure of how developer interest is changing. According to Enverus Intelligence Research, 47 of the 68 parcels offered in the sale were purchased at an average price of $107 per acre. That was more than three times the $32-per-acre average recorded at Nevada’s October 2025 geothermal auction and approximately four times Enverus’ pre-sale estimate. The $701-per-acre bid for the 4,479-acre parcel also set records for both per-acre pricing and the total value of a single geothermal tract.

The change is also visible in the number of parcels receiving only the minimum bid. Enverus reported that 76% of parcels sold at the $2-per-acre minimum in 2019. In the 2026 New Mexico auction, that share had fallen to 17%. This suggests that competition is becoming more concentrated around parcels that developers believe have stronger commercial potential.

A federal geothermal lease is only the beginning of the development process. The BLM describes leasing as the first step, with subsequent site-specific proposals and additional environmental analysis required before energy development can begin. A high lease price therefore does not mean that a geothermal power plant will necessarily be built. It indicates that developers are willing to spend more upfront to secure resources they believe could support future projects.

The change in bidding behaviour is important because geothermal development has traditionally been highly dependent on finding suitable underground conditions. Developers need sufficient heat, permeability and fluid availability, while also managing the technical challenges and costs associated with drilling. Greater competition for acreage indicates that companies are increasingly confident in their ability to evaluate and develop these resources.

Technology Is Changing the Value of Geothermal Resources

One reason behind the growing interest is the rapid development of next-generation geothermal technologies. Conventional geothermal projects generally rely on naturally occurring underground reservoirs where heat and fluids can be accessed relatively easily. This has historically restricted commercial development to areas with favourable geological conditions.

Enhanced geothermal systems could expand that potential. EGS aims to create or improve underground reservoirs so that heat can be extracted from formations that do not have the same natural permeability as conventional geothermal resources. The U.S. Department of Energy has identified EGS and related technologies as important drivers of future geothermal deployment, with the 2025 market report highlighting both technological progress and declining costs.

Drilling is particularly important because it represents a major portion of geothermal project costs. DOE states that drilling can account for 50% or more of total capital costs for geothermal projects. Its FORGE research programme in Utah has demonstrated significant improvements in drilling performance, reducing on-bottom drilling time at an equivalent depth of 6,000 feet from 440 hours to 60 hours.

These improvements matter because geothermal economics are highly sensitive to the cost and speed of drilling. If developers can drill faster, reduce equipment and labour requirements, and more accurately identify productive underground resources, the economic value of previously marginal geothermal acreage could increase. DOE analysis has also found that recent EGS demonstrations have achieved substantial reductions in drilling costs and improvements in drilling rates.

Higher Lease Prices Reflect Expectations About Future Demand

The stronger competition for geothermal resources is also developing alongside a changing U.S. electricity market. Electricity demand is expected to increase as data centres, industrial facilities and other large loads expand. This creates greater interest in generation technologies that can provide consistent electricity over long periods.

Geothermal has a distinctive characteristic in this market because power generation can operate independently of short-term changes in solar irradiation or wind conditions. The BLM describes geothermal as a resource capable of supporting baseload electricity, while the 2025 U.S. Geothermal Market Report identifies growing interest in geothermal as a reliable energy source as one factor supporting future market growth.

Corporate demand is already beginning to influence the sector. The 2025 market report identified 27 new geothermal power purchase agreements signed since 2020, alongside growing interest from utilities and corporate buyers. This creates an additional incentive for developers to secure resources that could eventually support long-term electricity contracts.

For energy buyers, the appeal of geothermal depends on more than the availability of underground heat. The cost of development, expected output, operating performance and the structure of a long-term power contract all influence whether a project can compete with other generation sources. For developers, meanwhile, paying millions of dollars for a lease increases the importance of successfully converting the underlying resource into a productive asset.

The trend therefore needs to be viewed carefully. Rising bids show that expectations are changing, but they do not eliminate geothermal’s technical and financial risks. Exploration can still fail to produce the expected resource, drilling can remain expensive, and projects must move through permitting and environmental review before construction. The BLM’s process includes environmental analysis and opportunities for public participation before development can proceed.

Conclusion

The record-setting New Mexico geothermal auction provides a useful snapshot of where the U.S. geothermal industry may be heading. Developers are paying significantly more for selected federal geothermal acreage, while the share of parcels receiving only minimum bids has fallen sharply. At the same time, advances in drilling and enhanced geothermal systems are changing assumptions about where geothermal resources can be developed and how much they may cost to produce.

The bigger question for the industry is whether these expectations can be converted into operating projects. The economics of geothermal will ultimately depend on the ability to identify productive resources, drill efficiently, manage project costs and secure customers for the resulting electricity. Recent progress provides evidence that some of these barriers are becoming more manageable.

For the U.S. energy market, geothermal could therefore become an increasingly important source of firm generation as electricity demand grows. The rising value of geothermal leases suggests that developers are already placing larger bets on that possibility. The next stage will be determining whether those bets can deliver reliable power at a competitive cost.