How a Kenyan state-steam, private-power model pushed the continent's geothermal leader past 1,000 megawatts.
Kenya's passage through the 1 gigawatt geothermal threshold is the headline, but the structural story underneath it is more durable than any single capacity milestone. Africa's geothermal leader reached that mark in early 2025 through a combination of state-owned infrastructure and private generation that has taken two decades to assemble - and which other rift-zone nations are now studying as a replicable template. At the center of the model is a division of labor that sounds simple but is politically difficult to execute: the public Geothermal Development Company drills the wells and absorbs the exploration risk that kills commercial lending, while independent power producers like Sosian Energy build the turbines and sell the electricity. The result is that Kenya now generates more geothermal power per capita than any country outside Iceland, with an estimated 20,000 megawatts of additional potential still untapped along the East African Rift System.
For most of East Africa, geothermal energy has always been a state affair - expensive, slow, and inseparable from the political risks of public ownership. The logic was straightforward enough: only governments could absorb the upfront exploration costs, only state balance sheets could take the write-down if a well came up dry. The result was that the continent's vast geothermal endowment - an estimated 20,000 megawatts of untapped potential along the East African Rift System - developed at a geologist's pace rather than a market pace.
Kenya disrupted this pattern almost by institutional design. When the state-owned Geothermal Development Company was founded in 2008, its mandate was narrow but consequential: drill the wells, build the steam gathering systems, and then step back. GDC would absorb the exploration risk - the part that terrifies commercial lenders - and private independent power producers would take the generation risk. The public sector acts as insurer of last resort on the geology. The private sector handles the machines and the money after that.
The Menengai Caldera, a massive dormant volcano crater roughly 180 kilometres northwest of Nairobi near Nakuru, became the proving ground for this model. GDC identified its geothermal potential early, sank wells through the 2010s, and by 2013 was ready to competitively tender three 35MW power plant contracts to private IPPs. The companies that won those tenders - Sosian Energy, OrPower 22, and Quantum Power East Africa (later acquired by Globeleq) - would each build, own, and operate their own plants, buying steam from GDC under 25-year project implementation and steam supply agreements. Kenya Power, the national distributor, signed corresponding 25-year power purchase agreements as offtaker.
The structure looked elegant on paper. It took over a decade to actually build.
The first plant to enter commercial operation at Menengai was Sosian's - and it did so with a speed that caught even seasoned observers off guard. Construction began in 2021. By August 2023, the 35MW Sosian Menengai Geothermal Power plant was fully commissioned and feeding electricity to Kenya's national grid. Sixteen months from groundbreaking to commercial operation, for a geothermal plant in sub-Saharan Africa, is a genuinely unusual achievement.
The technology choice was deliberate. Sosian selected Kaishan Group, a Chinese equipment manufacturer, as its EPC contractor at a cost of $65 million. Rather than a conventional centralized turbine design, Kaishan built a hybrid system: two steam screw expanders and three wet steam organic Rankine cycle modular power units. The modular approach reduced installation complexity and allowed the plant to begin generating revenue from individual units as they were commissioned, before the full facility was complete. By June 2023, three of five units were already supplying 18 megawatts to the grid. Full commissioning followed two months later.
The contrast with the other Menengai IPPs was stark. Globeleq's plant - awarded its EPC contract in February 2023 and granted financial close in January 2024 with a financing package from the African Development Bank, the Eastern and Southern African Trade and Development Bank, and Finnfund - is not expected to reach commercial operations until mid-2026. OrPower 22, now owned by China's Kaishan Group following a 2023 acquisition of the original developer Ormat Technologies, completed its 30-day stability test on 5 March 2026 and was awaiting commercial operation certification at that date. Sosian was already producing power for Kenya Power customers before its two competitors had broken ground.
At a tariff of $0.08 per kilowatt-hour - a rate that Sosian's director Kigen Moi publicly described as the cheapest in Kenya's history at the time - the plant represents not just a capacity milestone but a price point. Steam costs Sosian $14.5 million annually, paid to GDC. Against a 25-year PPA with Kenya Power, the economics are predictable if not spectacular.
On 5 March 2026, when OrPower 22 completed its stability testing, Kenya's installed geothermal capacity crossed the 1,000 MW threshold. It became only the eighth country in the world to join what the geothermal industry informally calls the "1GW Club" - a cohort that includes the United States, Indonesia, the Philippines, Turkey, New Zealand, Iceland, and Italy.
The milestone was years in the making. Kenya had 985MW of installed geothermal capacity before the OrPower plant came online, with the bulk of it concentrated at the Olkaria complex near Lake Naivasha - five KenGen stations with a combined 799MW capacity, plus a 150MW plant owned by Nevada-based Ormat Technologies. Geothermal already supplied approximately 47% of Kenya's total electricity generation, the largest share of any single source. The 1GW line crossed by OrPower 22 added 35MW to that base; the Olkaria I rehabilitation expected by June 2026 will add another 18MW; and Globeleq's completion later in 2026 will add a final 35MW, completing the initial Menengai build-out at 105MW.
The commercial significance runs deeper than the number. Every megawatt at Menengai was built by a private investor receiving steam from a state entity - a structural arrangement that, if replicated, could transform how Africa approaches its own geothermal endowment. GDC has already begun preparing PPP tenders for its next field: the 100MW Paka prospect, with production targeted for 2028. The Menengai framework - public exploration risk, private generation capital - is now the explicit template.
Sosian's project history offers a lesson in how political economy complicates clean energy ambitions even when the engineering cooperates. The firm was originally linked to Gideon Moi, son of the late President Daniel arap Moi and chairman of Kenya's KANU party, through his stake in the venture. In 2017, cement and steel industrialist Narendra Raval acquired full ownership through his Devki Group - reportedly attracted by the long-term PPA economics and the industrial demand for cheaper power. Then, in 2022, Raval sold the stake back to Gideon Moi at a loss, citing the incessant delays that had stretched the project well past its original 2017 commissioning target.
The African Development Bank, which had been evaluating financing for Sosian, withdrew its support entirely in April 2022 and demanded a change of ownership as a precondition for re-engagement. The bank eventually stepped back from the project altogether; the $68 million financing that Sosian ultimately secured came from the Development Bank of Southern Africa in July 2024, in a transaction that DBSA described as the first time an African-owned company in the geothermal sector had been financed entirely by an African-owned development bank.
Meanwhile, the communities surrounding the Menengai Caldera have not uniformly celebrated the project. The Menengai West Stakeholders Forum, representing roughly 100,000 residents from the Olrongai and Arahuka communities, filed legal challenges in 2021 arguing that public participation before the project's environmental approvals was inadequate. In March 2025, Kenya's High Court agreed, revoking Sosian's drilling license and ordering a new comprehensive Environmental and Social Impact Assessment before further exploration can proceed. The ruling does not affect the existing operating 35MW plant, which produces power under a separate license. But Sosian's plans to expand capacity from 35MW to 45MW using the DBSA loan are now on hold pending the environmental review.
Kenya is, without question, the outlier. Of the African nations with commercially scalable geothermal resources - Ethiopia, Tanzania, Uganda, Rwanda, Djibouti, and others - none has yet successfully replicated the GDC steam-sales model at any meaningful scale. Ethiopia's geothermal development remains entirely state-led under Ethiopian Electric Power, with private IPPs at projects like Tulu Moye and Corbetti still in early stages. Djibouti lacks the regulatory framework to attract private capital. Uganda has identified resources but not progressed to development.
The barrier is always the same: who absorbs the exploration risk? Geothermal drilling to the depths required for commercial generation costs tens of millions of dollars per well, with no guarantee of viable output. Commercial lenders will not touch it. Without a GDC-equivalent institution willing to sink capital into the ground before a private developer arrives, the IPP model has no starting point.
Kenya built that institution over fifteen years. The result - 1GW of installed geothermal capacity, a $0.08/kWh tariff from the Sosian plant, and a functioning template for private participation - is the asset that the rest of Africa is watching. GDC's steam supply now supports three privately-owned power plants. The 1,600MW estimated potential of the Menengai field alone has barely been touched; the long-term development plan targets 465MW. And beyond Menengai, Kenya has licensed thirteen additional IPPs to develop greenfield geothermal prospects at sites including Longonot, Akiira, and Baringo. The Paka field PPP tender, expected to target 100MW, is the next test of whether the model can scale.
The 1GW threshold is a number. The private power model is the mechanism. Whether the mechanism can travel beyond Kenya's borders is the question that 2026 has not yet answered - but has made impossible to ignore.