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The “drill” behind claims of unlimited clean energy is a millimeter-wave drilling system developed by Quaise Energy. It uses high-power electromagnetic waves to remove rock, with the aim of reaching the deep, superhot formations that could supply geothermal power. The technology is real, and Quaise has reported field demonstrations, including a 100-meter drilling milestone in 2025. But it has not yet demonstrated a commercial superhot well or a power plant delivering electricity to the grid. It may help geothermal reach more places; it has not unlocked limitless energy.
What is the drill?
Quaise Energy’s system is designed to use millimeter-wave energy to bore through very hard rock. A surface-based device called a gyrotron generates high-frequency electromagnetic waves, which travel down a waveguide and interact with the rock at the bottom of the borehole. Rather than depending only on a conventional bit to grind the rock away, the waves heat it so that it fractures, melts or vaporizes. The resulting fragments or fine material must then be removed from the hole.
This is not a microwave oven placed underground. Gyrotrons are high-power electromagnetic devices used in applications including fusion research. In Quaise’s proposed drilling setup, the gyrotron and other major equipment remain at the surface while energy is transmitted downhole.
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Repair common Windows errors and clear accumulated junk for a smoother, more stable PC - no reinstall needed.Free scan · no reinstallThe approach is intended to complement, not simply replace, conventional drilling. Quaise describes using standard drilling through formations where it is practical, then switching to millimeter waves in especially hard or hot rock. The company’s hybrid-drilling explanation describes that division of work.
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Why drill for superhot rock?
Geothermal power uses heat from within Earth. Conventional geothermal plants generally rely on a favorable combination of underground heat, water and permeable rock, which limits where they can be built economically. Deep, hot rock exists in more places than conventional geothermal resources can currently be developed, but reaching it and creating a reliable route for heat to reach the surface are major challenges.
Superhot geothermal generally refers to resources above about 375°C, a threshold used by the U.S. Department of Energy for superhot enhanced geothermal systems. At such temperatures, water under sufficient pressure can carry substantial heat. That could mean more energy from a well or a smaller project footprint—but temperature by itself does not guarantee a productive reservoir. The project still needs controlled fluid flow, durable equipment, a workable power plant and acceptable costs. DOE’s overview of EGS pilot demonstrations describes the superhot category and related projects.
Quaise says it is targeting depths as great as 20 kilometers and temperatures up to 500°C. Those are company ambitions, not demonstrated operating conditions. Even successful drilling would not make every location suitable: temperature gradients, rock structure, water or working-fluid management, seismic risk, permits and access to electricity infrastructure all matter.
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What has Quaise demonstrated?
The strongest public milestones in the supplied record are company-reported demonstrations in 2025:
- Quaise said it began field testing in a granite quarry in Texas after earlier laboratory development. Its account is available in the company’s lab-to-field update.
- The company reported drilling continuously to 100 meters in the field and said the result was ten times faster than its previous drilling demonstrations. Its demonstration announcement gives the company’s account of the milestone.
- Quaise also reported a full-scale rig demonstration using a 100-kilowatt gyrotron at a Nabors-operated oil-and-gas rig. The report is on Quaise’s site.
These results matter: they show progress in applying the rock-removal concept outside a laboratory and integrating it with drilling infrastructure. But the figures are company-reported, and a 100-meter field bore is not the same as a multi-kilometer well drilled through hot rock. The milestones do not establish that the system can drill at superhot temperatures, complete and case a commercial well, sustain fluid circulation, or generate grid electricity. A reported plan to move toward a one-megawatt system is a next step, not evidence that such a system is already operating commercially.
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Drilling is only the first link in the power chain
A geothermal project needs much more than access to hot rock. A plausible superhot project would have to:
- Choose a site with suitable temperature, rock mechanics and access to infrastructure.
- Drill and complete wells that remain stable at depth and temperature.
- Access or create a permeable region so a fluid can move through the hot rock.
- Circulate water or another working fluid through the formation and bring heated fluid back to the surface.
- Convert that heat to electricity, manage cooling and reinject the cooled fluid where appropriate.
- Maintain pressure, flow and useful temperatures over years of operation.
The millimeter-wave system addresses a potential bottleneck: drilling through deep, hard rock. It does not, on its own, solve reservoir permeability, well completion, fluid circulation, power conversion, reinjection or long-term reservoir management. A hole that reaches hot rock but cannot deliver sustained, controlled flow is not a power plant.
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The key question is not just whether electromagnetic energy can remove rock. It is whether a complete drilling-and-power system can do so reliably and at a cost that makes sense.
- Depth and direction: A 100-meter demonstration does not establish performance at several kilometers. Transmitting energy down a longer, narrower or deviating borehole, steering accurately and maintaining the waveguide all add engineering challenges.
- Rate, hole size and energy use: A fast penetration figure is meaningful only alongside borehole diameter, rock-removal rate and the electricity consumed per meter or volume of rock removed. The finished hole must also be large and suitable enough to complete for useful heat extraction. Public milestones cited here do not establish a commercial drilling cost or net energy return.
- Removing material: Vaporized or fragmented rock has to leave the borehole without blocking it, damaging equipment or making the process inefficient.
- Well integrity: Deep wells can fracture, deform or collapse. Casing, cement, seals, valves, sensors and other components must withstand heat, pressure and corrosive fluids. Superhot conditions make those demands especially severe.
- Reservoir performance: Hot rock is not automatically permeable rock. The project needs a reliable path for fluid to absorb heat and return. Poor connectivity or rapid cooling could undermine output even if drilling succeeds.
- Commercial operation: The decisive test is sustained net electricity after accounting for drilling, pumping and plant loads—not a drilling demonstration alone. Verified well costs, operating costs and long-term output are not established by the reported milestones.
Claims that a superhot well could produce many times more power than a conventional one should be treated as projections unless they identify a model and its assumptions. Actual output depends on temperature and pressure, flow rate, well geometry, plant design, energy used by the project and how long the reservoir remains productive.
Renewable and clean—but not impact-free or literally limitless
Geothermal heat is commonly considered renewable on human timescales when a reservoir is responsibly managed. But an individual reservoir can cool or lose productivity if heat is extracted faster than it is replenished. “Unlimited” is therefore an overstatement: Earth contains vast heat, but economically recoverable power depends on geology, engineering, environmental constraints and the rate at which a site can sustain extraction.
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Geothermal power may have a climate advantage, but a project still has impacts. Drilling uses materials and energy; projects can require water, land and transmission infrastructure; fluid handling can present scaling or corrosion issues; and engineered reservoirs can raise induced-seismicity concerns. Stimulation and pressure changes require site-specific monitoring, mitigation and public review. Waste heat also has to be rejected, so water availability and local conditions can affect plant design.
How it fits with other geothermal technologies
- Conventional hydrothermal geothermal taps naturally occurring hot water and permeable formations. It is commercially established in suitable locations, but geology limits its reach.
- Enhanced geothermal systems (EGS) engineer or stimulate flow through hot rock to expand the resource base. They must manage flow, reservoir life and potential induced seismicity. DOE is funding and tracking multiple next-generation geothermal demonstrations; its EGS demonstration page lists projects and program information, including Fervo’s Milford, Utah project.
- Closed-loop geothermal circulates fluid through a sealed or engineered loop, potentially reducing some groundwater or stimulation concerns. Heat transfer and the drilling needed to build the loop remain important design and cost challenges.
- Oil-and-gas-derived geothermal applies drilling, completion and subsurface skills developed by the hydrocarbon industry. That experience can help, but project economics still depend on geology, wells, flow and reliable output.
Millimeter-wave drilling is one of several advanced approaches to reaching hotter, deeper rock. A congressional hearing document on superhot-rock energy discusses multiple technical pathways, including millimeter-wave and plasma-based concepts. None should be confused with proof that a commercial superhot power system is already routine.
What would make it a game changer?
A convincing case would go beyond drilling records. It would show a documented deep well reaching superhot conditions; a completed well and casing that withstand them; sustained, commercially meaningful fluid flow; and net electricity delivered after the project’s own energy use. It would also provide independently reviewed performance data, transparent cost estimates, months or years of reliable operation, evidence the reservoir does not quickly cool, and a credible path to repeating the project at other sites.
Government support and industry partnerships can help move a technology toward those tests, but they are not proof of success. For example, DOE announced up to $171.5 million in February 2026 for next-generation geothermal field tests and related drilling. That is a funding opportunity, not evidence that every funded project has succeeded.
The verdict
Quaise’s millimeter-wave drill is a serious attempt to overcome one of geothermal energy’s constraints: reaching hot, hard rock. Its reported field work is a meaningful step beyond laboratory demonstrations. Yet the distance between removing rock and delivering dependable, competitively priced electricity remains substantial. The fair conclusion is that this technology could help make superhot geothermal power more widely available; it has not shown that clean energy is unlimited, available everywhere or commercially solved.
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