Zanskar has not discovered a terawatt of geothermal power. The Utah-based company argues that conventional geothermal estimates miss hidden resources and that better exploration, drilling and development could reveal a much larger opportunity. Its terawatt figure is an ambitious company thesis, not a verified reserve, an independently established generation forecast or a buildable project pipeline.
For investors and energy readers, the key question is not simply how much heat may exist underground. It is whether Zanskar can repeatedly turn promising geology into productive wells, permitted plants and reliable electricity at financeable cost.
What does Zanskar mean by “1 TW”?
Zanskar CEO Carl Hoiland’s argument is that conventional assessments may count too few undiscovered geothermal systems and underestimate the output that modern drilling could obtain from known fields. More sites, multiplied by more power per site, could make the long-term opportunity much larger than the tens of gigawatts commonly discussed. That is the company’s strategic estimate, not a formal resource assessment. TechCrunch’s January 2026 report describes Hoiland’s reasoning; Zanskar says its platform aims to identify thousands of overlooked western U.S. sites with potential output at terawatt scale. The company’s site does not make that aggregate potential equivalent to proven reserves or committed generation.
The term “overlooked” can describe several different opportunities: an undiscovered system, a known field that was previously judged uneconomic, an operating plant that could be improved, or a higher output estimate for a site after better targeting. Those categories carry different levels of evidence and risk. A redevelopment project at an existing plant is not the same achievement as finding, proving and building a new geothermal field.
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The distinction matters because heat in place is not the same as electricity that can be recovered economically. A site can contain substantial heat yet fail as a power project if it lacks adequate permeability, temperature, sustainable flow, affordable drilling, grid access or the permits and financing needed to build.
Why might conventional geothermal have been underestimated?
Traditional exploration often starts with visible clues such as hot springs, fumaroles and volcanic features. But geothermal systems can be “blind”: heat and fluids may exist underground without an obvious surface expression. Expensive exploration drilling also discourages testing prospects that look marginal under older data or cost assumptions. Existing fields may have been assessed with limited subsurface information or drilled in less productive zones.
Zanskar says approximately 95% of geothermal systems lack an obvious surface tell, a company-attributed figure reported by TechCrunch. Without an underlying technical citation and definition of “system” and “surface tell,” it should not be treated as an independently established industry-wide statistic. The broader premise—that relying on visible surface signs can miss subsurface prospects—is the basis of Zanskar’s exploration strategy, not proof that every hidden anomaly is commercially useful.
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Geothermal has also had to compete for capital and attention with faster-growing wind and solar development and with newer enhanced-geothermal concepts. Better prospect selection could reduce one bottleneck, but it cannot by itself make drilling cheap, guarantee reservoir performance or provide a transmission connection.
How Zanskar’s AI-assisted exploration works
Zanskar presents itself as an “AI-native” geothermal developer, not just a software vendor. Its approach combines data analysis with geoscience, site visits, drilling and development. According to the workflow described in TechCrunch’s reporting, machine-learning models process geological, geophysical, historical and other subsurface data to rank prospects. Field teams then gather additional evidence, which informs target selection and the decision about where to drill.
The company also uses a method it calls Bayesian evidential learning to update hypotheses as evidence arrives and estimate probabilities across uncertain subsurface conditions. Its geothermal simulator is intended to evaluate scenarios and fill gaps where direct observations are unavailable. Zanskar says it grounds its models in real-world data and pairs them with fieldwork. Its description of its work emphasizes that combination.
These tools can help prioritize where to spend exploration money; they do not let a model directly observe the full reservoir or eliminate geological uncertainty. The commercial test is whether model-selected prospects repeatedly produce wells with suitable temperature, flow, pressure, uptime and cost—not merely whether software identifies anomalies worth investigating.
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What evidence has Zanskar reported so far?
The public milestones range from exploration claims to an operating-plant redevelopment. They are not interchangeable measures of commercial success.
| Evidence stage | What has been reported | What it establishes—and what remains open |
|---|---|---|
| Exploration | Zanskar characterized three sites explored in the prior funding period as successes. TechCrunch reported two new sites with more than 100 MW of combined potential. | Promising prospect or discovery claims, attributed to the company and its reporting. The public figures do not specify whether the 100 MW is thermal or electrical, gross or net, modeled or tested, or at what confidence level. Source |
| Operating-asset redevelopment | Zanskar says it acquired Lightning Dock in New Mexico in May 2024 and returned the underperforming plant to full capacity in less than a year after drilling into a deeper, hotter zone. | A concrete redevelopment claim, but “full capacity” needs a numerical output and operating period to be independently evaluated. An existing plant also starts with land, infrastructure, interconnection and operating history that a greenfield site lacks. Company account |
| Development pipeline | In January 2026, Zanskar said its pipeline could support at least 1 GW of generating capacity. | A company estimate of future projects, not 1 GW already operating or fully financed. Reported figure |
| Capital for growth | Zanskar announced a $115 million Series C in January 2026 and a $40 million development-capital facility in April 2026. | Capital supports exploration and project development, but neither financing announcement validates the 1-TW estimate or proves project economics. Series C announcement; development-capital announcement |
The scale gap is significant: the company’s reported pipeline of at least 1 GW is one-thousandth of 1 TW. The reported 100-plus MW at two sites is smaller still, and neither figure should be conflated with net electricity delivered to the grid. The comparison with U.S. benchmarks also needs care: TechCrunch cited roughly 60 GW of U.S. geothermal potential by 2050 in Department of Energy estimates and described conventional U.S. generation as about 4 GW. Those reported figures provide context, but they are not a like-for-like validation of Zanskar’s differently defined, longer-term opportunity.
Lightning Dock: the clearest operating example, with limits
Lightning Dock is Zanskar’s most concrete public case study. The company says it bought the New Mexico plant in May 2024 after years of underperformance, identified a deeper, hotter zone and returned the plant to full capacity in less than a year. Zanskar also describes the resulting well as the most productive pumped geothermal well in the United States. Its technical update and project account provide the company’s descriptions.
Those claims would be easier to assess with a defined megawatt figure, sustained operating data and a stated productivity metric—such as flow rate or net electrical output. Publicly described company claims alone do not establish those details independently. A successful redevelopment does show a potentially valuable ability to improve an existing asset, but it does not establish the success rate or economics of finding and building entirely new blind systems.
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Lightning Dock also illustrates that discovery is only one part of development. A New Mexico public-policy report discusses permitting and neighbor-impact issues around the site, including lighting concerns. The report is a reminder that a strong subsurface resource does not remove local land-use and permitting questions.
Conventional geothermal is not the same as enhanced geothermal
Conventional or hydrothermal geothermal
Conventional systems use naturally occurring heat, fluid and permeability. Commercial projects depend on finding a reservoir that can supply enough hot fluid sustainably. Zanskar’s main thesis is that natural systems have been missed or poorly characterized, particularly when they lack clear surface signs.
Enhanced geothermal systems
Enhanced geothermal systems seek to create or stimulate permeability in hot rock, often using techniques associated with hydraulic stimulation. They may expand geothermal development to more locations, but face their own drilling, cost, water-management and induced-seismicity questions. TechCrunch’s coverage discusses companies such as Fervo and Sage Geosystems in this broader category. The approaches are distinct, not mutually exclusive: naturally productive reservoirs may support nearer-term projects where they exist, while enhanced systems could extend the geographic reach if technology and economics improve.
Independent reader supportYour contribution helps us test, update, and keep practical guides available for everyone.Why geothermal attracts power developers—and what can block a project
Geothermal can provide firm, dispatchable electricity rather than depending on sunshine or wind at the moment of generation. A high-capacity-factor plant can support continuous loads, including data centers, and can contribute grid services near local demand. Zanskar describes geothermal as carbon-free, always-on and utility-scale on its company site; actual emissions and performance depend on project design and operations. Geothermal is not automatically cheap or impact-free: drilling, fluids, plant design, water, transmission, permitting and financing shape the outcome.
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- Exploration risk: A promising model output can still lead to a dry, cool, low-flow or uneconomic well. Historical data may also overrepresent geology that was explored before.
- Drilling and well costs: Deep wells, hard rock, high temperatures, corrosive fluids, lost circulation and integrity problems can raise costs. One successful production well may not be enough; injection and make-up wells may also be needed.
- Reservoir sustainability: Flow, pressure and temperature must persist. Reinjection, fluid chemistry, thermal breakthrough and declining production can affect equipment and long-term output.
- Plant and grid infrastructure: Resource confirmation comes before major plant investment, but turbines, cooling, substations and transmission still add cost. A remote resource without suitable grid access is not equivalent to a connected power plant.
- Land, water and permits: Drilling, water use, land access, noise, visual impacts, emissions, transmission and induced seismicity can prompt reviews or local opposition.
- Financing and offtake: Geological risk can make conventional project finance difficult. Hoiland told TechCrunch that Zanskar wanted at least 10 confirmed sites to attract project-finance investors, whose capital can be cheaper than venture funding. That is a company financing goal, not a universal lender threshold. Source
The April 2026 development-capital facility is more directly connected to the move toward construction than an exploration-only funding round, but financing by itself does not establish that a particular site is fully permitted, built or operating. Zanskar’s announcement describes the facility as development capital; the public announcement should not be treated as proof of the full 1-TW thesis.
What would validate the terawatt thesis?
The meaningful test is whether better exploration odds translate into a repeatable, financeable fleet of operating plants. Readers can assess progress through measurable milestones rather than headline-scale resource potential:
- Discovery accuracy: How often do ranked prospects produce commercially useful wells, across different geological settings? What are the false-positive and false-negative rates?
- Well performance: What temperatures, sustained flow rates, electrical output, decline rates and production-to-injection well ratios are achieved?
- Project economics: What are exploration cost per confirmed site, drilling cost per successful megawatt, installed cost and operating cost? How do these compare with competing power sources?
- Development execution: How long does each project take from prospect ranking through resource confirmation, permitting, financing and commercial operation?
- Pipeline conversion: How many megawatts move from modeled potential to discovered, drilled, proven, permitted, financed, under construction and operating? Are sites concentrated in one region?
- Bankability and durability: Are resources independently certified? Are there long-term power-purchase agreements, lender participation and sustained operating records? Do reinjection and reservoir management preserve output?
Until those stages are documented across a larger portfolio, the 1-TW figure remains an extrapolation. Three reported exploration successes are encouraging, but they are too small a sample to establish performance across hundreds or thousands of possible sites.
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