Africa Is Attracting More Energy Capital Than Ever. The Problem Is Everything That Comes After Generation.

The Capital Moment The scale of energy investment flowing into Africa has crossed a threshold that demands serious analytical attention. Gulf Cooperation Council countries alone have committed over USD 100 billion to African energy infrastructure, with the United Arab Emirates, Saudi Arabia, and Qatar deploying capital through sovereign wealth vehicles, state energy companies, and bilateral development finance into renewable energy projects, LNG infrastructure, and long-term power generation assets across the continent. This is not portfolio diversification at the margins. It is a strategic repositioning by capital-rich, hydrocarbon-dependent economies that are simultaneously managing their own energy transitions and seeking to lock in long-term infrastructure relationships with high-growth emerging markets. The Gulf capital story sits alongside a separate but complementary wave of investment driven by global demand shifts in the LNG market. Europe's structural pivot away from Russian gas following the 2022 invasion of Ukraine created an urgent and sustained demand signal for alternative LNG supply that has accelerated investment decisions in Mozambique, Tanzania, and potentially other East African gas-bearing jurisdictions. The intersection of Gulf renewable capital and European LNG demand with East Africa's resource endowment has created a financing environment for energy projects that is more favourable than anything the region has experienced in at least two decades. And yet, across the coverage region, power outages remain a daily reality for industrial users and households alike. Manufacturing operations run diesel generators because grid power is unreliable. Mining companies build captive power plants because connecting to the national grid exposes them to voltage fluctuations and supply interruptions that damage equipment and disrupt production. Farmers lose perishable produce because cold chain infrastructure cannot function without consistent electricity. Small businesses absorb the cost of backup power systems that represent a significant proportion of their operating budgets. The contradiction is real and it is structural. Capital is flowing. Power is not. The reason is that the energy investment wave is concentrated in generation, the most visible, most financeable, and most commercially legible part of the electricity value chain. The infrastructure that connects generation to end users, the transmission lines, substations, distribution networks, metering systems, and market coordination frameworks, is not attracting capital at the same pace, is not being built at the same pace, and is not receiving the same policy attention. The result is a growing mismatch between installed generation capacity and delivered economic value that will define the region's energy challenge for the next decade if it is not addressed deliberately. Generation Is Not the Constraint. Systems Are. The analytical framing that has historically dominated African energy discourse, that the continent's power problem is fundamentally a generation deficit that more power plants will solve, is increasingly incomplete and in some contexts actively misleading. Tanzania's Julius Nyerere Hydropower Station, with an installed capacity of 2,115 megawatts, is one of the largest hydropower facilities in Africa and a transformative addition to the country's generation portfolio. Kenya's geothermal capacity, centred on the Olkaria complex in the Rift Valley, has made the country a global leader in geothermal power generation and significantly diversified its electricity mix. Uganda's Karuma and Isimba hydropower stations have added nearly 800 megawatts of new capacity to the national grid in recent years. Zambia has multiple hydropower stations and is developing solar capacity at scale. Rwanda is building toward nuclear. Across the coverage region, generation capacity is growing. But the transmission infrastructure required to move that power from generation points to demand centres is not growing at a comparable pace. Tanzania's national transmission grid, managed by TANESCO, has historically been characterised by significant losses, bottlenecks between generation-rich southern regions and demand-heavy northern and coastal zones, and limited interconnection capacity with neighbouring countries. Kenya's transmission system, managed by Kenya Electricity Transmission Company, has undergone significant investment but still faces constraints in evacuating power from geothermal fields in the Rift Valley to industrial and commercial demand centres in Nairobi, Mombasa, and the coast. Uganda's grid struggles to absorb the full output of its new hydropower additions because the transmission infrastructure to distribute that power to domestic users and export it to neighbours has not been built at the scale the new generation capacity requires. The distribution layer is worse. Across the coverage region, distribution networks, the medium and low voltage infrastructure that delivers power from transmission substations to individual homes, businesses, and industries, are characterised by high technical losses, ageing equipment, inadequate maintenance, and insufficient coverage in peri-urban and rural areas. Distribution losses in several regional utilities exceed 20 percent of power entering the distribution system, meaning that more than one unit in five generated never reaches a paying customer. The commercial and financial implications of these losses are severe: they reduce revenue, increase the cost of delivered electricity, undermine utility financial sustainability, and create a reinforcing cycle in which financially stressed utilities cannot invest in the infrastructure improvements that would reduce losses and improve financial performance. The Regional Electricity Market: The Architecture of Integration The most strategically significant energy development in East Africa that is not receiving the analytical attention it deserves is the construction of a regional electricity market framework. The Eastern Africa Power Pool, which brings together the national utilities of Ethiopia, Kenya, Uganda, Tanzania, Rwanda, Burundi, the DRC, and several other countries, has been developing the technical and regulatory architecture for cross-border power trading for over two decades. The ambition is to create a functioning regional electricity market in which surplus generation in one country can be sold to deficit countries, in which the least-cost generation resources across the region can be dispatched to serve regional demand efficiently, and in which the investment case for large-scale generation projects is strengthened by access to a regional market rather than dependence on a single national buyer. The economic logic of this regional market is compelling and the numbers are significant. Ethiopia's Grand Ethiopian Renaissance Dam, with an eventual installed capacity of 5,150 megawatts, generates far more power than Ethiopia's current domestic demand can absorb. A functioning regional market would allow Ethiopia to export surplus power to Kenya, Uganda, and beyond, generating export revenue, reducing the average cost of electricity across the region, and improving the return on one of Africa's largest infrastructure investments. Kenya's geothermal surplus could flow to Uganda and Rwanda during periods of low domestic demand. Tanzania's hydropower capacity could serve the DRC's industrial mining zones in the east of the country. The regional resource complementarity is real and could be transformative. What stands between this vision and operational reality is a set of constraints that are simultaneously technical, regulatory, commercial, and political. The physical interconnection infrastructure, the high-voltage transmission lines that cross national borders and connect national grids, exists in some corridors and is absent or inadequate in others. The Kenya-Ethiopia interconnector is operational. The Tanzania-Zambia interconnector has been in development. The DRC-Rwanda-Burundi connections are limited. The Uganda-Kenya-Tanzania triangle needs upgrading to handle the volumes that a functioning regional market would require. Beyond the physical infrastructure, the regulatory and market coordination framework is still being constructed. A regional electricity market requires agreement on pricing mechanisms, on grid access rules, on dispute resolution procedures, on financial settlement systems, and on the allocation of costs and benefits between surplus and deficit countries. These are not purely technical questions. They are political economy questions about how the gains from regional energy integration are distributed, and they require sustained political commitment and institutional development that is inherently slower than building a power plant. Gulf Capital and the Renewable Buildout: What Is Being Financed and What Is Not The Gulf capital deployment into African energy deserves more precise analysis than the headline figure of USD 100 billion suggests. Understanding where that capital is going, and where it is not, is essential for assessing its actual impact on the region's energy challenge. The UAE's clean energy vehicle, Masdar, has been among the most active renewable energy investors on the continent, with projects across solar and wind in multiple African markets. Saudi Arabia's ACWA Power has developed significant renewable energy assets across Africa, including in South Africa and Egypt, and is expanding its regional presence. Qatar's investment vehicles have been active in LNG infrastructure financing in East Africa. Collectively, this Gulf capital has been instrumental in driving down the cost of renewable energy in African markets and accelerating the deployment of solar and wind generation at scale. But the concentration of this capital in generation, and specifically in utility-scale generation assets with clear offtake agreements and bankable revenue streams, means that it is flowing into the most commercially legible part of the energy value chain while the less commercially structured transmission, distribution, and market coordination infrastructure continues to rely primarily on development finance, government balance sheets, and multilateral loans. The incentive structure is clear: a 200-megawatt solar plant with a 20-year power purchase agreement backed by a creditworthy government counterparty is a financeable project with a defined return profile. A rural distribution network rehabilitation programme in western Tanzania or southern Zambia is a development finance project with limited commercial return and significant execution risk. This financing gap between generation and systems infrastructure is not a failure of capital markets. It is a structural feature of how energy infrastructure is financed globally, and it requires deliberate policy intervention, through subsidy mechanisms, blended finance structures, regulatory frameworks that improve the commercial viability of distribution investment, and utility reform programmes that make national utilities creditworthy offtake counterparties, to address. Utility Reform: The Precondition That Is Not Optional No discussion of East Africa's energy systems challenge is complete without confronting the utility reform question directly. The national electricity utilities of the coverage region, TANESCO in Tanzania, Kenya Power in Kenya, UMEME and UEGCL in Uganda, ZESCO in Zambia, ESCOM in Malawi, and their counterparts elsewhere, are the organisations through which the energy transition must ultimately be delivered. They are also, with some exceptions, financially stressed, technically constrained, and operationally underpowered relative to the challenge they face. The financial stress of regional utilities is both cause and consequence of the systems infrastructure deficit. High distribution losses reduce revenue. Underpriced tariffs that do not cover the full cost of supply reduce revenue further. Poor collection rates reduce revenue further still. The result is utilities that cannot service debt, cannot fund capital investment, cannot attract and retain technical talent, and cannot maintain ageing infrastructure to the standard required for reliable supply. Donors and development finance institutions have financed generation assets and transmission upgrades that connect to utilities whose financial and operational condition means they cannot maintain the new assets effectively or pay the independent power producers whose output they are contractually obligated to purchase. Tariff reform is the most politically sensitive element of utility rehabilitation because it directly affects consumer energy costs, with disproportionate impact on lower-income households and energy-intensive industries. The tension between financially sustainable tariffs and affordable access is real and cannot be resolved through technical means alone. It requires explicit subsidy mechanisms that target affordability support to those who need it while allowing cost-reflective pricing for commercial and industrial users, and it requires the political will to implement and sustain these mechanisms over the years required to restore utility financial health. Several countries in the coverage region are making progress on utility reform, through independent power producer frameworks, through partial privatisation of distribution functions, through performance-based management contracts, and through regulatory strengthening that improves the credibility of tariff-setting processes. Kenya's electricity sector reforms have been among the more substantive in the region. Tanzania's ongoing efforts to improve TANESCO's operational and financial performance are moving in the right direction. But the pace of reform across the region remains slower than the pace of generation investment, and the gap between new capacity being connected to the grid and that capacity being reliably delivered to end users continues to widen. Cross-Border Energy Systems: The DRC's Untapped Centrality Any serious analysis of East and Central Africa's energy integration potential must confront the DRC's position in the regional energy architecture, because the numbers are extraordinary and the gap between potential and reality is among the largest of any single country in the world. The Congo River and its tributaries represent the largest hydroelectric potential of any river system on earth. The Grand Inga hydropower site alone, on the lower Congo River, has a theoretical installed capacity potential of approximately 44,000 megawatts, more than the entire current installed generation capacity of Sub-Saharan Africa combined. Even the more modest Inga 3 project, a 4,800-megawatt first phase of a larger development, would be transformative for the regional energy balance if developed and connected to regional transmission infrastructure. The Inga 3 project has been in various stages of development, negotiation, and stalling for decades. A development agreement between the DRC government and a consortium including AECom and the Spanish infrastructure group, followed by the cancellation of that agreement, followed by renewed interest from Chinese developers, reflects the extraordinary complexity of developing large-scale infrastructure in the DRC context. The project's financing, estimated at over USD 14 billion for Inga 3 alone, requires a combination of sovereign financing, development finance, private capital, and anchor offtake agreements from regional buyers that has proven consistently difficult to assemble. If even a fraction of the Congo River's potential were connected to the Eastern Africa Power Pool's transmission infrastructure, the regional energy equation would be fundamentally different. Industrial mining operations in the DRC, eastern Zambia, and western Tanzania that currently run on expensive diesel or captive thermal power could be supplied with low-cost hydro electricity. The processing economics that currently make in-country mineral value addition unviable would shift. The regional power market that the Eastern Africa Power Pool is trying to build would have a resource anchor of extraordinary scale and low marginal cost. The gap between this potential and current reality is not primarily technical. It is a governance, financing, and political economy problem of the kind that the DRC has faced across multiple development domains. Solving it is a long-horizon challenge. But it belongs at the centre of any serious analysis of East and Central Africa's energy future. The Transmission Financing Gap: Where the Money Needs to Go The practical implication of the analysis above is that the region's energy investment agenda needs to rebalance deliberately toward transmission, distribution, and market coordination infrastructure, and that this rebalancing requires financing instruments and policy frameworks that do not currently exist at sufficient scale. The African Development Bank's Desert to Power initiative and its broader energy financing programme represent the most significant institutional effort to address the full energy value chain rather than generation alone. The World Bank's regional energy integration programmes and the Power Africa initiative have similarly attempted to address transmission and distribution alongside generation. But the scale of these programmes remains substantially below what the infrastructure gap requires, and the commercial financing that has been mobilised for generation has not followed into transmission and distribution at comparable scale. Closing the transmission financing gap requires several things simultaneously. It requires regulatory frameworks that allow private capital to invest in transmission and distribution infrastructure with defined return parameters. It requires regional political agreements that make cross-border transmission investment commercially viable by guaranteeing access and pricing terms across national boundaries. It requires utility reform programmes that create creditworthy offtake counterparties for private distribution investors. And it requires development finance institutions to deploy concessional capital specifically targeted at the systems infrastructure that commercial finance will not reach at the required scale. None of this is beyond the region's institutional capacity to design and implement. Several of the building blocks are already in place. But the urgency needs to match the scale of the problem, because the generation capital being deployed today is creating obligations and expectations that a fragmented, underdeveloped transmission and distribution system cannot honour. The Bottom Line Africa's energy capital moment is real. The Gulf investment, the LNG financing, the renewable energy buildout, and the development finance flowing into generation infrastructure represent a genuine inflection point in the region's energy investment history. The risk is that this capital moment produces a generation surplus that cannot be delivered to end users because the systems infrastructure required to move power from where it is generated to where it is needed has not been built. The region does not have an energy resource problem. It has an energy system problem. Solving it requires investment in transmission, distribution, and market coordination that is less glamorous, less commercially straightforward, and less politically visible than building a power plant, but more consequential for the economic impact of every megawatt that gets generated. Capital is flowing. The question is whether it flows to the right places. And whether the systems that turn generated electricity into delivered economic value are built before the generation investments that depend on them become stranded. Africa has energy resources. It does not yet have integrated energy systems. The window for building them, while capital is available and political momentum is present, is open. But it will not stay open indefinitely. ____________________________________________________________________________________ Sources: International Energy Agency Africa Energy Outlook 2024, African Development Bank Energy Sector Report 2024, Eastern Africa Power Pool Annual Report 2024, World Bank Private Participation in Infrastructure Database, Masdar Africa Investment Portfolio Disclosures, ACWA Power Project Database, Power Africa Transaction Database, TANESCO Annual Performance Report, Kenya Power Annual Report 2024, Grand Inga Development Project Documentation, International Renewable Energy Agency Africa Renewable Energy Status Report 2024. _____________________________________________________________________________________ Uchumi360 covers business, investment, and economic policy across East, Central, and Southern Africa.