Kenya’s Geothermal Leadership and the Wider African Picture
Kenya has become one of the world’s most notable geothermal success stories. Since the 1980s the country has tapped the heat stored in the Great Rift Valley, and today it ranks sixth globally for installed geothermal capacity, delivering roughly half of its national electricity demand from this renewable source.
How Geothermal Works in the Rift Valley
Geothermal plants function like a giant kettle: water deep beneath the Earth’s surface is heated by magma, turns to steam when a well reaches the hot reservoir, and that steam drives turbines to generate electricity. Kenya’s flagship Olkaria IV complex exemplifies this process, supplying clean, baseload power that helps shield the economy from volatile fossil‑fuel prices.
Expanding Kenya’s Geothermal Footprint
The momentum shows no sign of slowing. Several new projects are either under construction or in advanced planning stages:
- Menengai 35 MW plant – expected to be fully operational later this year, adding to the existing Olkaria complex.
- Olkaria I Units 6 and 7 – slated for completion by 2026, together contributing an additional 140 MW.
- Baringo‑Silali geothermal field – feasibility studies indicate potential for up to 200 MW, with drilling scheduled to begin in 2025.
These developments reinforce Kenya’s goal of achieving 100 % renewable electricity by 2030, a target supported by the country’s Vision 2030 development plan and the African Development Bank’s New Deal on Energy for Africa.
Why Neighboring Nations Lag Behind
Despite sharing the same Rift Valley geology, countries such as Ethiopia, Tanzania, Uganda, and Djibouti have struggled to translate geothermal potential into measurable power output.
Capital Intensity and Risk Perception
At a recent International Renewable Energy Agency (IRENA) meeting in Abu Dhabi, Tanzania’s Energy Minister Deogratius Ndejembi summed up the regional hesitation: “In the long term, it’s good to have geothermal energy, but do I want to do it now? Probably not.” He highlighted two core concerns:
- High upfront costs – drilling a geothermal well resembles oil and gas exploration, requiring significant capital before any guarantee of a commercially viable resource.
- Financing risk – low‑income governments often prioritize quicker‑to‑deploy technologies like solar and wind, which have lower levelized cost of electricity (LCOE).
Sveinn Hannesson, CEO of Island Drilling—a firm specializing in super‑hot geothermal drilling—confirmed that the price per kilowatt‑hour for geothermal can be up to ten times higher than for solar in the early stages. He argued that reducing the cost per kilowatt by 25‑50 % is essential for broader adoption across the continent.
Technical Challenges Beyond Cost
Even when financing is secured, geological uncertainty remains a barrier. Island Drilling’s 2018 campaign in Djibouti accessed substantial heat but found the reservoir lacked sufficient permeability to allow steam flow, rendering the wells non‑productive for electricity generation. Hannesson noted that emerging techniques—such as hydraulic stimulation akin to fracking in oil and gas—could someday unlock these “tight” resources, but the technology is still nascent and carries its own environmental considerations.
Path Forward for African Geothermal Development
Experts agree that a combination of policy de‑risking, innovative financing, and regional cooperation can accelerate geothermal uptake:
- Government guarantees and risk‑sharing mechanisms – models like Kenya’s Geothermal Development Company (GDC), which absorbs early‑stage exploration risk, have proven effective.
- Blended finance** – combining concessional loans from institutions such as the World Bank’s Climate Investment Funds with private equity can lower the effective cost of capital.
- Regional data sharing** – creating a centralized Rift Valley geothermal atlas would reduce duplicated drilling efforts and improve site selection.
- Capacity building** – training local engineers and technicians ensures long‑term operational sustainability and builds domestic expertise.
The African Union’s Programme for Infrastructure Development in Africa (PIDA) already earmarks geothermal as a priority corridor; aligning national strategies with PIDA’s framework could unlock further funding streams.
Conclusion
Kenya’s experience demonstrates that geothermal can become a cornerstone of a low‑carbon, resilient power system when supported by clear policy, targeted risk mitigation, and sustained investment. For the rest of East Africa, the geological promise is undeniable; the remaining challenge lies in translating that promise into projects that are financially viable, technically sound, and socially acceptable. With coordinated action and innovative financing, the Rift Valley’s steam could soon power more than just Kenya’s homes—it could illuminate the entire region.
