Neptune Energy launches Pilot Phase II for lithium extraction in the Altmark: paving the way for European battery supply Neptune Energy has begun the second pilot phase of its Altmark Lithium Extraction Project (ALE). After a broad evaluation of Direct Lithium Extraction (DLE) technologies in pilot phase I, the company is now focusing on an adsorption process and testing various adsorbent materials together with the Fraunhofer Institute for Energy Infrastructures and Geotechnologies (IEG). The project aims to recover lithium from thermal deep groundwater in northern Saxony-Anhalt economically and with environmental safeguards , a step toward regional supply chains for battery raw materials in Europe. Project status and technical objectives A project-related resource of around 43 million tonnes of lithium carbonate equivalent (LCE) has been identified in the Altmark. The lithium is dissolved in thermal water at depths between approximately 3,000 and 4,000 metres. Neptune Energy...
The Economics of 10 MW, 50 MW, and 100 MW Geothermal Plants
Image: A thematic image of a geothermal power plant
Geothermal power has a simple promise and a complicated price tag. It turns heat from deep underground into steady electricity, but the money goes out long before the power comes in, because exploration, drilling, plant construction, and grid connection all happen up front.
That is why plant size matters so much. In general, 10 MW projects tend to be the most expensive per kilowatt, 50 MW projects usually strike a better balance, and 100 MW plants can be the most efficient on a cost per electricity basis if the reservoir is strong enough.
Why geothermal costs so much upfront
The economics of geothermal are driven by risk and scale. A developer has to locate the resource, confirm temperature and flow, drill wells, build surface facilities, and connect everything to the grid before a single dollar of revenue is earned.
That makes geothermal very different from technologies where the fuel is easier to access or the resource is visible on the surface. In geothermal, the underground reservoir is the asset, and proving that it exists is one of the most expensive parts of the job.
The fixed nature of those early costs is what creates the scale effect. If the same exploration and drilling bills support a 100 MW plant rather than a 10 MW plant, each unit of electricity carries a smaller share of the burden.
Why 10 MW is usually the priciest
A 10 MW geothermal plant is small in utility terms, and that small size often works against it economically. One source reports a 10 MW binary plant at about US$5,300 per kW installed, and another case study found a levelized cost near US$140 per MWh.
The reason is straightforward. A small plant still needs wells, turbines, heat exchangers, pumps, cooling equipment, civil works, and interconnection, but it spreads those costs over only 10 megawatts of output.
That does not make 10 MW geothermal useless. It can be the right answer for a remote area, a small grid, a high price electricity market, or a project where energy security matters more than lowest possible cost. In those cases, the economics may still be acceptable even if the plant is not the cheapest option on paper.
Where 50 MW begins to work better
At around 50 MW, geothermal starts to look far more balanced. Reported figures include about US$3,650 per kW for a 50 MW steam plant, and some estimates put levelized cost around US$88 to US$92 per MWh.
This is the zone where scale begins to help without making the project too hard to manage. The plant is large enough to spread fixed exploration and drilling costs more effectively, but not so large that it automatically exceeds what the reservoir can support.
That is why many developers and analysts see 50 MW as a practical middle ground. It is often big enough to be economically credible, yet still realistic for a geothermal field that has been carefully studied and proven.
Why 100 MW can be the best scale
In classic cost studies, 100 MW often sits near the minimum cost zone. The logic is simple, bigger output means shared costs are diluted, so the cost per unit of electricity can fall as the project grows.
But geothermal does not behave like a standard industrial plant. The reservoir underneath the surface has to be strong enough to keep delivering hot fluid over the long term, and that is where the limits appear.
A 100 MW plant can be excellent if the field is large and dependable. If not, the project may become overbuilt, and the larger size stops being an advantage. In other words, the best scale is not just a question of finance, it is a question of geology.
The costs that matter most
Three forces dominate geothermal economics. The first is exploration and drilling risk, because the project can fail before it ever reaches operation.
The second is plant and well field cost. Larger projects usually lower the cost per megawatt because turbines, controls, roads, pipelines, and other infrastructure can serve more generation.
The third is financing. Even when the engineering looks sound, high borrowing costs or cautious lenders can make a geothermal project difficult to close. That is why the same plant can look attractive in one country and marginal in another.
Operation and maintenance are usually not the main problem. One source notes O&M costs of about 1.5 to 2.5 percent of total investment costs, which is relatively modest compared with the upfront capital burden.
A simple way to compare the three sizes
A 10 MW plant is usually the most expensive per unit of electricity, but it can still be useful where power needs are small or local. A 50 MW plant often gives the best balance between cost and practicality.
A 100 MW plant can be the most efficient if the reservoir is robust enough to support it. The catch is that geothermal does not reward size blindly, because the underground resource has to match the surface ambition.
So the economic story is not simply “bigger is better.” It is more accurate to say that bigger is often cheaper per unit, but only when the geology, drilling success, and financing all line up.
The United States has some of the most developed geothermal regions, especially in the western states. Recent sources show that geothermal projects can still be commercially relevant, but they remain highly sensitive to drilling cost and resource quality.
For a typical 50 MW hydrothermal project in the western U.S., one source gives a rough upfront cost of about US$200 million to US$250 million, while enhanced geothermal systems can cost more because they require deeper and more complex drilling. That wide range is a reminder that geology drives the budget.
A 10 MW project can work in a niche setting, but it is usually harder to justify because the fixed costs are spread over fewer megawatts. A 100 MW project can look excellent on paper, but only if the reservoir is large enough and reliable enough to support that output over time.
Canada’s geothermal story is shaped by its resource geography and long clean energy outlook. The economics still follow the same pattern, 10 MW is usually the toughest size to make cheap, while 50 MW is often more manageable and 100 MW may be attractive only where the field is especially strong.
For Canadian developers, the challenge is not only the technology but the timeline. Geothermal projects need patience, because wells must be drilled, tested, and refined before the final generation profile becomes clear.
That makes financing and policy support important. If lenders see a small project with high uncertainty, the risk premium can be heavy, but a larger project with better data can start to look much more bankable.
Germany is a useful example of how economics change when a country has limited high temperature geothermal resources. In a market like that, the cost of drilling uncertainty becomes even more important, because every unsuccessful well makes the project harder to recover.
That means a 10 MW plant may struggle to look attractive unless it serves a very specific local purpose. A 50 MW plant can be more compelling if the reservoir is suitable, because scale helps absorb the fixed costs.
A 100 MW project would be ideal only if the underground resource is exceptionally strong. In practice, the main question in Germany is not whether geothermal can work in theory, but whether the site can support the scale needed to make it pay.
The United Kingdom has growing interest in geothermal, especially for local energy resilience and district heating. The same economics apply here too, small plants are often expensive per unit, and larger plants are better positioned to spread their fixed costs.
A 10 MW project may be easier to build into a local system, but it often needs a stronger policy or pricing environment to compete. A 50 MW project is more likely to create a credible business case if the geology supports it.
For the UK, drilling risk is the central issue. If the reservoir underperforms, the economics can deteriorate quickly, and that reality makes site selection and technical diligence especially important.
Australia has strong interest in energy transition technologies, and geothermal fits that discussion because it can deliver steady power with low fuel risk. Yet the economics are still ruled by the same size effect, 10 MW usually carries the highest unit cost, while 50 MW and 100 MW can be more efficient.
Australia’s distance from major population centers can actually make local dependable generation attractive. In regions where grid reliability matters, geothermal may compete not only on cost but also on firmness and long term energy security.
Still, the reservoir has to justify the plant. A larger project only makes sense if the subsurface resource is strong enough to supply it continuously, otherwise the advantages of scale disappear.
New Zealand is one of the best real world examples of geothermal done well. The country has long used geothermal resources for electricity, and official country data show geothermal contributing around 30 percent of electricity generation and about 65 percent of primary energy supply from geothermal sources.
That success matters because it shows how geology and experience can reduce project risk. Once a country has a mature geothermal industry, larger plants can become especially effective because developers know how to manage wells, reinjection, and field performance.
In New Zealand, the economics can therefore look better than in countries with less experience. The lesson is not that every geothermal project works, but that a strong resource base and technical maturity can transform the business case.
Japan has considerable geothermal potential, but development often faces land use and permitting complexity. That makes project economics even more important, because developers need each project to justify the time and effort required to bring it online.
A 10 MW plant may fit local needs, but it is usually the least efficient size from a unit cost perspective. A 50 MW plant tends to be more appealing if the reservoir is suitable, because it better balances capital intensity and output.
A 100 MW project would be highly attractive in theory, but it requires a field with enough temperature, flow, and recharge to sustain the output. In geothermal, the best business plan still has to obey the underground reality.
Iceland is the clearest example of geothermal power operating at national scale. Country data show that geothermal provides about 30 percent of electricity and a large share of primary energy, with 90 percent of indoor heating based on geothermal energy.
That makes Iceland unusually important in any discussion of geothermal economics. It shows what can happen when the resource is abundant, the policy environment is supportive, and expertise has built up over decades.
One source notes geothermal electricity production in Iceland at roughly 30 percent of total generation, while another points to highly favorable geothermal costs in the country. The message is clear, when the resource is excellent and the system is mature, geothermal can be both clean and competitive.
France and Italy
France and Italy are both relevant to geothermal, though their opportunities are more location specific. In both countries, the economics depend on matching the right site with the right scale rather than assuming geothermal will work everywhere.
A 10 MW plant may serve a local use case, but it will often be the most expensive per unit of electricity. A 50 MW project is usually more compelling if the field is confirmed and the power market can absorb the output.
For a 100 MW plant, the upside is scale efficiency, but the limiting factor is still the reservoir. Geothermal rewards good geology more than bold slogans, and that is especially true in markets where resource availability is uneven.
The main investment lesson is that geothermal becomes more attractive as plant size rises, but only up to the point where the reservoir can support the project. A 10 MW plant may be strategic, but it often carries the highest unit cost.
A 50 MW plant is often the most practical compromise, offering better economics without requiring an extreme resource commitment. A 100 MW plant can be the most efficient on paper, but it needs strong subsurface confidence and disciplined development.
That is why geothermal is often called a high risk, high reward clean energy source. It can deliver very stable electricity once operational, but the path to that point is expensive and uncertain.
The big picture
If you strip geothermal down to the essentials, the story is simple. Small plants are usually costly per unit because fixed costs are hard to hide, medium plants often offer the best balance, and large plants can be very efficient if the reservoir is strong enough.
That pattern shows up across the United States, Canada, Germany, the United Kingdom, Australia, New Zealand, Japan, Iceland, France, and Italy. The details change from country to country, but the economic logic stays the same.
Geothermal is not the cheapest energy source everywhere, and it is not the easiest to build. But where the heat is right, the wells perform, and the scale is chosen wisely, it can become one of the most reliable and valuable forms of clean power.
Comments
Post a Comment