Geothermal boost for Amsterdam: OMV and Cocreators selected to lead regional heat projects The Aardwarmte Regio Amsterdam consortium — made up of Vattenfall, the Municipality of Amsterdam and Energie Beheer Nederland (EBN) — has selected OMV, in collaboration with Cocreators, as the operator to advance geothermal projects for collective heat networks across the Amsterdam region. The decision, reached after a European tender process, brings an experienced international energy company and a project-management specialist together with local partners to test feasibility, design potential geothermy doublets and, where viable, develop and implement geothermal heat production for district heating systems. Why this matters Decarbonising heating is one of the most urgent and technically complex elements of the energy transition in dense European cities. In the Netherlands, where gas has historically supplied much of the built environment, scaling low-carbon alternatives for space heating and ho...
How Geothermal Energy Works: From Underground Heat to Electricity Grid
By: Robert Buluma
In 1904, the Italian town of Larderello lit five lightbulbs using nothing but the heat of the Earth. By 1913, a full-scale plant was producing 250 kilowatts there from natural steam vents. Yet more than a century later, geothermal remains one of the most underappreciated clean energy sources on the planet — today accounting for just about 0.5% of global electricity.
That is beginning to change. As the world searches for reliable, round-the-clock renewable power to complement intermittent wind and solar, geothermal is attracting unprecedented attention. "Geothermal could be the backbone to providing a clean, affordable, reliable, low-cost grid," says Katrina McLaughlin of the World Resources Institute. With emerging technologies poised to unlock heat virtually anywhere beneath our feet, understanding how this remarkable resource works has never been more important.
I. The Fiery Engine Deep Within
The Earth as a Natural Nuclear Reactor
To understand geothermal energy, one must first look down — far down. The Earth's core, a solid ball of iron about 1,500 miles wide, burns at an astonishing 10,800 degrees Fahrenheit (6,000°C) — as hot as the surface of the sun. This inferno is maintained by two ongoing processes: primordial heat leftover from the planet's formation 4.5 billion years ago, and the continuous radioactive decay of elements like uranium, thorium, and potassium naturally present in the Earth's crust.
From this scorching core, heat radiates outward through the mantle (where temperatures range from 392°F near the crust to 7,230°F deeper down) before reaching the rocky outermost layer: the crust. The total heat flow from Earth's interior to the surface is estimated at a staggering 43–49 terawatts.
Where the Heat Reaches Us
Not all locations are created equal when it comes to accessing this underground inferno. The Earth's crust varies dramatically in thickness: roughly 15–35 miles under continents and as little as 3–5 miles beneath the ocean floor. Geothermal resources are most accessible where the crust is thin, faulted, or near volcanic activity — conditions that typically occur along tectonic plate boundaries. This is why the Pacific "Ring of Fire" hosts such abundant geothermal activity, from the geysers of California to the volcanoes of Indonesia and the hot springs of New Zealand.
The Three Essential Ingredients
For a conventional geothermal system to generate electricity, nature must provide three elements in perfect combination: heat, fluid, and permeability. The underground rock must be hot, water must be present, and that water must be able to move freely through fractures in the rock. Where all three align, hydrothermal reservoirs form — natural underground chambers of steam or superheated water ready to be tapped.
II. Drilling Deep: The Path to the Reservoir
Finding the Needle in the Crust
Before a single drill bit turns, developers spend years characterizing potential sites. Seismic surveys map underground geology, revealing the thickness and layout of different rock layers. Geologists analyze existing hot springs, fumaroles (steam vents), and surface heat flow patterns. The most reliable confirmation, however, comes only from drilling itself — lowering borehole measuring equipment to record temperature, pressure, and rock properties in situ.
Drilling Techniques: Borrowed and Refined
Geothermal wells employ drilling technologies adapted from the oil and gas industry, but with critical modifications tailored for hotter, harder, more corrosive environments. The drill assembly — a derrick, rotating drill pipes, and a diamond-studded drill bit — can penetrate up to 3,000 meters (nearly 2 miles) or more into the Earth.
Precision is paramount. Wells are often drilled at angles (sometimes 45 degrees) to maximize contact with the reservoir, with sophisticated steering motors guiding the bit along desired trajectories. As drilling progresses, steel casings are cemented into place to reinforce the borehole, prevent collapse, protect shallower aquifers (including drinking water sources), and isolate different geological layers.
The drilling process for a typical two-well geothermal plant takes approximately 110 days (about 4 months). Costs remain substantial — a major barrier to wider deployment — but innovation is helping.
The Well Doublet: Production and Injection
Every geothermal electricity project requires at least two wells: a production well to bring hot water up, and an injection well to return cooled water back down. At the surface, these wellheads might sit just meters apart, but deep underground they intentionally diverge — often by 1,000 to 1,500 meters at reservoir depth. This separation prevents the injected cooled water from flowing directly back into the production well before it has time to reheat.
In the production well, specialized filter tubes allow hot water to enter while keeping unstable sand and rock particles out. The injection well receives the cooled brine back, often through perforations blasted into the pipe with explosives — a crude but effective method.
III. From Borehole to Breaker Box: The Power Plant
Once hot geothermal fluid reaches the surface, the method of converting its thermal energy into electricity depends entirely on its temperature. Three primary technologies dominate the landscape.
Dry Steam Plants: The Simplest Design
Dry steam plants are the oldest and most straightforward geothermal technology. They tap underground reservoirs that produce nothing but pure steam — no water mixed in. This steam is piped directly from production wells into a turbine, where it expands, spinning the turbine blades connected to a generator. After passing through the turbine, the steam enters a condenser, transforms back into liquid water, and is reinjected.
This elegant simplicity works well — but dry steam reservoirs are extremely rare. The world's largest and most famous is The Geysers in Northern California, a 1,875 MW complex at its peak that can still supply electricity to a city the size of San Francisco. The Geysers also offers a cautionary tale: during the 1970s and 1980s, competing operators extracted steam faster than it could be naturally replenished, causing reservoir pressures to plummet. A subsequent project injecting treated wastewater saved the field, demonstrating how careful reservoir management is essential to sustainability.
Flash Steam Plants: The Workhorses
If dry steam plants are the elegant exception, flash steam plants are the rugged workhorses — the most common type of geothermal power plant worldwide. They operate on reservoirs of water hotter than 360°F (182°C).
Here's how they work: extremely hot water under immense pressure flows up the production well. As it rises, pressure decreases. Suddenly, some of that superheated water instantly boils or "flashes" into steam, much like opening a shaken soda bottle. This steam is separated from the remaining hot water in a flash vessel and directed into a turbine.
More sophisticated designs use double-flash systems, where the leftover hot water is sent to a second, lower-pressure flash tank to produce even more steam — boosting overall efficiency by 15–25%. Flash plants are found across Indonesia, the Philippines, New Zealand, and elsewhere, forming the backbone of global geothermal generation.
Binary Cycle Plants: The Technology for the Future
For reservoirs with more modest temperatures — ranging from about 225°F to 360°F (107°C to 182°C) — binary cycle plants offer an ingenious solution. These facilities never allow the geothermal fluid to touch the turbine. Instead, the hot water from underground passes through a heat exchanger, where it transfers its thermal energy to a secondary "working fluid" — typically an organic compound with a much lower boiling point than water. This working fluid vaporizes and drives the turbine, while the original geothermal fluid remains in a closed loop, never exposed to the air.
Moderate-temperature water is by far the more common geothermal resource, and most experts believe binary-cycle plants will dominate future installations. They produce virtually no air emissions, can be deployed in far more geographic locations, and are increasingly paired with Organic Rankine Cycle (ORC) technology for even greater efficiency.
IV. The Next Frontier: Enhanced Geothermal Systems
The greatest limitation of conventional geothermal — the requirement for naturally occurring heat, water, and permeability — has confined almost all development to tectonically active regions. Enhanced Geothermal Systems (EGS) aim to shatter that constraint.
EGS essentially creates human-made reservoirs where nature provided only hot rock. The process begins by drilling into deep, hot but impermeable rock (often 3–10 km down). Then, using techniques adapted from oil and gas fracking, engineers inject high-pressure fluid to create a network of artificial fractures. This "stimulation" opens existing cracks and creates new ones, establishing permeability where none existed. Water injected through one well circulates through this man-made fracture network, absorbs heat, and is pumped out through a second production well.
The potential is staggering. One study projects that EGS could supply up to 20% of U.S. electricity by 2050. The U.S. Geological Survey estimates that 135 gigawatts of potential electric-power generation is available from EGS in the Great Basin of the U.S. Southwest alone. And EGS is already moving from theory to reality: the first large-scale commercial EGS power generator in the United States is under construction and expected online in June 2026.
Costs are falling rapidly. Adaptation of oilfield drilling strategies has shortened EGS drilling times by 50–70% compared to earlier projects. By 2027, EGS is expected to achieve a levelized cost of electricity around $80 per MWh — competitive with market electricity prices in many regions. Policy initiatives aim to reduce EGS costs even further, by 90% to $45 per MWh by 2035.
Induced seismicity remains a legitimate concern — earthquakes (typically small, but sometimes noticeable) have been associated with EGS development. However, improved monitoring, injection management, and operational protocols are steadily mitigating these risks.
V. Environmental and Economic Realities
A Truly Clean Energy Source
Geothermal's environmental credentials are exceptional. A typical flash plant emits about 50 times less carbon dioxide than an equivalent fossil-fuel power plant — largely from trace gases naturally dissolved in the geothermal fluid. Binary plants, because they never expose the geothermal fluid to the atmosphere, emit virtually nothing at all. Land use is minimal: a geothermal plant requires roughly one-tenth the land footprint per megawatt compared to solar or wind facilities.
The water footprint is also moderate. While geothermal plants do consume water (some evaporates in cooling towers), most of the produced fluid is reinjected back into the reservoir, perpetuating the cycle and helping sustain underground pressure. Closed-loop EGS designs can further reduce water consumption by circulating the same fluid repeatedly.
The Economics: High Capital, Low Operating Costs
The greatest barrier to geothermal expansion is not operational but upfront. Drilling deep wells is expensive: exploration and drilling can consume 30–50% of total project costs. Compared to natural gas peaker plants or even utility-scale solar, geothermal's initial capital requirements are daunting.
Yet once operational, geothermal shines. Its levelized cost of electricity (LCOE) ranges from approximately $0.06–$0.10 per kWh globally, and in many projects can compete directly with wind and solar. More importantly, geothermal plants operate with extraordinary reliability. One binary plant in Morocco achieved a capacity factor of 99.4% — meaning it generated near its maximum output almost all year round.
This is geothermal's secret superpower: while wind turbines spin only when the wind blows and solar panels generate only when the sun shines, a geothermal plant runs 24 hours a day, 365 days a year, completely independent of weather. In an increasingly renewable grid, this firm, dispatchable baseload power is becoming invaluable.
VI. Global Landscape and Future Potential
Who Leads the World?
By the end of 2025, global installed geothermal power capacity reached 17,173 megawatts, with activity across 35 countries. The top five producers are the United States (3,953 MW), Indonesia (2,742 MW), the Philippines (2,034 MW), Türkiye (1,797 MW), and New Zealand (1,259 MW). Together, the top 10 nations account for more than 93% of global installed capacity. This concentration illustrates both geothermal's enormous potential and its current limitations: development remains heavily clustered in a few geologically favored nations. In Kenya, geothermal supplies 47% of national electricity. In Iceland, it provides 90% of home heating and 30% of electricity. But globally, its share remains tiny.
The Future: Toward Ubiquitous Geothermal
Emerging technologies promise to fundamentally alter this picture. Advanced Geothermal Systems (AGS) or closed-loop designs circulate fluid through sealed pipes deep underground, requiring no fracture networks and posing minimal induced seismicity risk. Superhot rock systems, tapping reservoirs exceeding 750°F (400°C), could generate up to 10 times more power per well than conventional geothermal, though the technical challenges remain substantial.
Hybrid systems — combining geothermal with solar thermal, biomass, or waste heat — can boost efficiency further. One study found that adding just 2 MW of solar-thermal heat to a 33 MW geothermal plant increased net electrical output by 3.6%.
Perhaps most excitingly, geothermal brines often contain valuable dissolved minerals. Lithium extraction from geothermal fluids is already underway in California's Salton Sea, where companies are producing battery-grade lithium as a profitable co-product of geothermal power generation.
Conclusion: A Key to the Decarbonized Grid
From the scorching core of our planet to the flick of a light switch, geothermal energy represents one of the most elegant renewable technologies ever devised. It taps a source of power that has flowed for 4.5 billion years and will continue for billions more. It produces firm, reliable electricity around the clock, with near-zero emissions and a remarkably small physical footprint.
For decades, geothermal's Achilles' heel has been its geographic constraints — the need to build on top of specific, rare combinations of natural heat, water, and permeability. But with the rapid maturation of Enhanced Geothermal Systems, closed-loop designs, and superhot rock technologies, that constraint is dissolving. The heat beneath our feet is, quite literally, everywhere — and we are finally learning how to access it.
As wind and solar expand across global grids, their intermittent nature creates an increasingly urgent need for firm, clean power that can operate anytime. Nuclear, hydropower, and geothermal are the only mature technologies that fit this description. Of the three, geothermal is the only one that can be built nearly anywhere, operates without fuel costs, and poses none of the safety or waste concerns associated with nuclear fission.
The road ahead is not without challenges: upfront capital costs remain high, drilling in hot hard rock pushes engineering to its limits, and public acceptance of EGS will require careful management of induced seismicity risks. But the rewards are immense. If next-generation geothermal fulfills its promise, the lightbulbs lit in Larderello in 1904 will have sparked nothing less than a quiet energy revolution — one powered, as always, by the ancient fire beneath our feet.
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