Menengai’s Broken Promise: How Kenya’s Geothermal Model Lost the Steam Thematic image of the Olkaria Geothermal Field Kenya’s Menengai geothermal project was sold as a model of modern public-private partnership. The state would carry the difficult and expensive burden of geothermal exploration and drilling. Private power producers would then build, own and operate power plants. Geothermal Development Company would supply the steam; the independent power producers would convert it into electricity; Kenya Power would buy the output. On paper, the arrangement was elegant. In practice, Menengai has exposed a far more uncomfortable reality: Kenya’s public steam-supply model is not delivering the certainty it promised. Menengai Phase I was designed to produce 105 megawatts from three 35 MW plants. GDC’s own project page says the three plants were awarded to Globeleq Menengai Geothermal, Sosian Menengai Geothermal Power and OrPower Twenty Two under a build-own-operate structure. Yet the ...
The Billion-Dollar Gamble Beneath Our Feet: Why Geothermal Exploration Is the Industry’s Greatest Risk
Exploration Risk: The Billion-Dollar Gamble Beneath Our Feet By: Robert Buluma
Image credit: Kane Watikson on LinkedIn
Geothermal energy is often described as the sleeping giant of the clean energy transition constant, weather-independent, capable of delivering 24/7 baseload power without the intermittency that defines solar and wind. Yet despite this extraordinary promise, geothermal remains underdeveloped in most parts of the world. The reason is not lack of heat. It is not lack of demand. It is not even lack of technology and not even FINANCE, Whilst many will throw that policy card, but Alphaxioms is already future proofing that.
The real barrier lies several kilometers beneath our feet in uncertainty.
Exploration risk is the defining challenge of geothermal energy. Unlike wind turbines that can measure wind speeds before construction, or solar farms that can predict output from sunlight data, geothermal developers must make multimillion-dollar decisions based on incomplete knowledge of what lies underground. Seismic surveys, magnetotelluric imaging, geochemical sampling all provide clues. None provide certainty. The only way to truly confirm a geothermal reservoir is to drill into it. And drilling is brutally expensive.
Across the world, this uncertainty has reshaped national energy strategies, bankrupted projects, and forced governments to redesign policy frameworks.
In Japan, one of the world’s most technologically advanced geothermal nations, engineers attempted to drill deep at the Kakkonda field in pursuit of super-high temperatures that could revolutionize output. Instead, they encountered extreme heat conditions that degraded drilling fluids and forced termination of the well before reaching intended depths. What was supposed to be a technological leap became a sobering lesson in geological unpredictability. The heat was there but not in the way engineers anticipated. The project had to be rethought, delayed, and partially abandoned. Yet still companies are beating the odds.
Germany tells a different but equally painful story. In Geretsried, near Munich, a geothermal project once promised to heat an entire town. After drilling, the expected hot water flow did not materialize in commercially viable quantities. The project stalled. Years passed. Gas systems remained in place. Only recently have new deep closed-loop technologies revived hopes of success in the same region. The geology did not cooperate the first time and that initial miscalculation cost years of momentum. The country is still derisking and even financing its precious prospects
In Turkey, rapid geothermal expansion during the 2010s was punctuated by wells that failed to meet temperature expectations and reservoirs that produced lower flow rates than projected. Investors grew cautious. Environmental concerns around non-condensable gases complicated financial modeling. Exploration risk became not just a technical issue but a financing bottleneck.
Across Europe from France to the Netherlands, Denmark to Poland, Croatia to the United Kingdom studies of sedimentary geothermal projects show that roughly one in four failed outright. Not because turbines were flawed. Not because policy was hostile. But because subsurface conditions did not match forecasts. Permeability was insufficient. Temperature gradients were weaker than modeled. Water chemistry complicated operations. The earth simply refused to cooperate.
Indonesia and the Philippines sit atop some of the richest geothermal reserves on the planet along the Pacific Ring of Fire. Yet even there, where heat is abundant and surface manifestations are visible, exploration risk continues to deter private capital. High upfront drilling costs, long development timelines, and uncertainty about resource size make financiers demand higher returns or government guarantees. The paradox is striking: immense heat potential paired with cautious investment behavior.
In East Africa, Kenya has managed to mitigate this risk through a deliberate institutional strategy. The Geothermal Development Company (GDC) absorbs the early exploration burden by drilling confirmation wells before handing steam over to private developers. This model has helped Kenya grow from a few hundred megawatts to nearly a gigawatt of geothermal capacity within a decade. Yet even in Kenya, early wells in fields like Menengai required substantial public investment before productivity was proven. The success visible today rests on years of geological gambling.
Ethiopia, Armenia, Costa Rica, and other emerging geothermal markets have experienced similar patterns strong geological indicators followed by slow progress due to drilling uncertainty and financing hesitancy. In many cases, exploration phases stretch for years because governments must secure concessional funding or risk-mitigation instruments before drilling even begins.
The brutal mathematics of exploration risk are simple. A single deep well can cost several million dollars. A commercial field may require multiple successful wells. Some wells will fail. If early wells underperform, entire projects collapse before producing a single kilowatt-hour. Unlike oil and gas, where production volumes can compensate for dry holes, geothermal projects depend on consistent thermal flow over decades. The margin for geological error is thin.
What makes exploration risk uniquely nerve-shredding is that geothermal developers operate in the most hostile drilling environments on Earth. Temperatures can exceed 300°C. Pressures are extreme. Drilling fluids degrade. Equipment fails. Unexpected fractures release steam and gases under violent conditions. Every meter drilled deeper multiplies technical complexity.
And yet, geothermal remains one of the most stable and resilient forms of renewable energy once operational. Operating costs are low. Output is steady. Carbon intensity is minimal. Plants can run for decades. The risk is front-loaded concentrated entirely in the exploration phase. This asymmetry shapes the entire industry.
Some nations have responded creatively. Iceland reduced private exposure by allowing the state to shoulder a significant portion of exploration costs. Germany introduced exploration insurance schemes to compensate developers when wells fail to meet temperature projections. International financial institutions created geothermal risk mitigation funds to de-risk early drilling in developing countries. Artificial intelligence and advanced subsurface modeling now attempt to reduce blind drilling by integrating geological datasets at unprecedented scale.
But even with innovation, the central truth remains unchanged: geothermal energy demands faith in what cannot be seen.
Exploration risk is not just a technical inconvenience. It is the reason geothermal contributes a small fraction of global electricity despite its enormous theoretical potential. It determines where capital flows, how governments structure energy policy, and whether private developers step forward or retreat.
The next breakthrough in geothermal will not simply be a better turbine. It will be a breakthrough in certainty in imaging, modeling, drilling efficiency, or risk underwriting that transforms subsurface ambiguity into bankable confidence.
Until then, every geothermal well drilled anywhere in the world from Japan’s volcanic depths to Germany’s sedimentary basins, from Turkey’s western fields to Indonesia’s volcanic arcs, from Kenya’s rift systems to Europe’s aquifers carries with it the same question:
Will the earth deliver?
That question, more than any other, defines the billion-dollar gamble beneath our feet.
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