Africa's energy gap is also an infrastructure opportunity.

Nigeria’s power deficit is only the beginning of the investment question. NERC reported average available grid-connected generation of 5,400 MW in Q4 2025, while average hourly generation was approximately 4,453 MW. These describe different stages of supply; neither measures total national electricity need. An investment model therefore has to identify which constraint it can actually resolve—plant availability, the route through the network, or the ability of a customer to buy and use the output. NERC · Q4 2025 report, pp. 11, 38–39

The distribution figures make the commercial problem more concrete. Aggregate technical, commercial and collection losses were 34.90% that quarter, but Eko recorded 14.20% and Kaduna 69.45%. This measure includes unpaid bills and unbilled energy, not just physical losses in wires. A national average conceals very different operating conditions. The implication is that the identity of the distribution partner, the customer mix and control over metering and collections can matter as much as the generation technology. NERC · Q4 2025 report, pp. 11, 38–39

Market geography is also becoming regulatory geography. NERC’s May 2026 update records the transfer of intrastate oversight to 15 states. This is a dated milestone, not a count of all subsequent transfers. For a proposed location, the useful next step is to establish which regulator currently has jurisdiction and how the proposed transaction interacts with the wider system. A successful arrangement in one state should not be assumed to carry identical approvals or commercial conditions into another. NERC · state regulatory transition, May 2026

Distributed supply offers a more specific development route. The World Bank approved $750 million for DARES in December 2023, with an objective of reaching over 17.5 million people through new or improved access and an ambition to mobilise private capital. Its 2024 implementation review discussed site-level productive-use strategies, committed productive loads, capacity-utilisation assumptions and state approvals. Those details reveal why connection counts are an incomplete business case: a site needs credible consumption throughout the day, with customers whose activities can sustain payment. Programme objectives and design conditions are not completed results or automatic access to a grant. World Bank · DARES approval, December 2023 World Bank · implementation review, 2024, p. 6

GEB’s interpretation is that a useful first screen is a defined customer cluster and a credible delivery arrangement. For industrial or commercial supply, examine interval demand, generator fuel spending, downtime costs, payment history and the proposed network interface. For a community mini-grid, test seasonal demand and the cost of connecting productive users. In either case, model revenue after losses, collection delays, maintenance and currency exposure. That work distinguishes a large unmet need from a project that can support its financing.

Ethiopia illustrates why an electricity-access headline can obscure the actual market. Its 2025 National Energy Compact reports that 65% of households had at least one electricity source, while 44% of the population received basic service at Tier 1 or above. These have different service definitions and denominators; they should not be subtracted to calculate a market gap. Neither establishes the reliability required to run machinery. For an enterprise, the relevant evidence is available hours, voltage quality and usable power at the premises. Ethiopia · National Energy Compact, 2025, pp. 1, 16

The compact estimates that distribution and access require $4.9 billion of the more than $9.6 billion needed through 2030. That allocation shifts attention toward the network between a power station and the customer. GEB reads this as a reason to investigate specific feeders, substations and connection clusters before making a generation-led proposition. The expenditure estimate is a programme requirement, not an awarded procurement pipeline or a return forecast. Ethiopia · National Energy Compact, 2025, pp. 1, 16

The financing sequence reinforces that reading. The World Bank’s April 2024 PRIME approval provided $522 million for the first phase of a programme whose early stages prioritise critical infrastructure and sector reforms, with later stages intended to mobilise private participation. The same source identifies hydrological variability as a risk to a hydro-dependent system and diversification as part of the response. For investors, the distinction is between an identified system need and a transaction with completed preparation, a contracting route and payment arrangements. World Bank · PRIME approval, April 2024

ASCENT provides another concrete entry lens. Announced in August 2025, it is designed to connect households, non-residential customers and towns near existing medium-voltage networks, supported by a $400 million IDA credit and a $24 million Danish grant. Danish support is intended to reduce connection costs for 480,000 new customers. This identifies both a geography and an affordability constraint. Being close to a network can make connection more practical, but an affordable connection does not by itself prove sufficient monthly consumption to repay privately financed equipment. World Bank · ASCENT financing, August 2025

GEB’s interpretation is to separate three propositions: strengthening service for existing users, financing access near existing networks, and developing additional generation that improves the system’s supply profile. Each needs a different customer, contract and risk model. A credible assessment should establish who pays, how imported equipment is financed, what happens when demand develops more slowly than expected, and whether the implementation schedule depends on public works still to be completed. Local service evidence is therefore more useful than simply extrapolating from national renewable capacity.

Egypt offers evidence of large-scale renewable financing, but the development stages must remain distinct. EBRD’s March 2026 account of the Nexus of Water, Food and Energy programme records more than 10 GW of signed renewable power-purchase agreements and almost 6 GW reaching financial close. A signed agreement, committed financing and a commissioned plant are different milestones. For an investor assessing a pipeline, the useful question is what still separates each asset from construction, connection and revenue. EBRD · NWFE progress as at March 2026

The buyer model is also evolving. The same account records three private-to-private pilot projects totalling 300 MW by March 2026, alongside the established state-buyer route. This is evidence of a developing corporate supply mechanism, not an unrestricted market available on identical terms to every sponsor. GEB’s reading is that corporate procurement deserves investigation where a buyer has a credible load and payment profile, but the applicable contracting and network arrangements must be established for the actual transaction. EBRD · NWFE progress as at March 2026

Transmission is a practical investment constraint rather than background infrastructure. EBRD’s 2025 €200 million financing package for the Egyptian Electricity Transmission Company includes a Cairo 500 kV substation upgrade associated with the retirement of Shoubra El Kheima and a line intended to evacuate more than 2.1 GW of renewables from the Gulf of Suez. These investments connect generation expansion with network capability. For a developer, a site with attractive wind or solar resources can still face a poor delivery timetable if the required network works and power plant are not ready together. EBRD · transmission financing, 2025

Obelisk demonstrates the importance of financial structure. Its 2025 financing announcement describes approximately 1.1 GW of solar and 200 MWh of battery storage, with a 25-year, US-dollar-denominated EETC power-purchase agreement backed by a sovereign guarantee. The package also includes development-finance and concessional support. Those are transaction-specific protections, not standard terms to assume for a new proposal. The announcement is evidence of financing design; its forecast construction dates are not confirmation of present operating status. EBRD · Obelisk financing terms, 2025

GEB’s interpretation is that Egypt should be assessed through the quality of the route to revenue. Establish who purchases the output, which party bears currency and payment risk, and how connection delays or restricted dispatch affect receipts. For storage, distinguish battery energy capacity from discharge power and determine which contracted service earns revenue; adding a battery is not automatically an additional income stream. The strongest proposition combines a competitive resource with a deliverable grid connection and a financeable allocation of obligations. That is a more discriminating screen than a headline renewable target.

DR Congo is best examined as distinct local delivery propositions rather than a single resource story. IFC’s 2023 Nuru disclosure describes a company that owns and operates generation and the distribution network reaching its customers. It also records discussions with prospective buyers in telecoms, water pumping and agricultural processing. These were prospective relationships, not a verified list of contracted customers today. The model nonetheless shows that an electricity investment can involve building the route to the customer and operating a service business, as well as financing a power plant. IFC · Nuru project disclosure, 2023

That changes the questions behind a project valuation. GEB would examine the cost per connected customer, the density of productive demand, network maintenance, collection capability and the resilience of the anchor customers. A strong daytime load may improve utilisation, but only a measured consumption profile and an enforceable payment arrangement can establish how much. Local land, security, community and operating conditions also need to be checked at the proposed site; a historical disclosure should not be read as a current operating assessment of an entire province.

The World Bank’s October 2024 EASE results illustrate why customer finance matters. The programme supported SNEL distribution rehabilitation and private operators through loans on attractive terms and subsidies to customers. It reported assistance to eight private electricity suppliers and connections for 827 companies and SMEs. This demonstrates an implementation approach that combines network investment with affordability support. It does not establish that an unconnected household can immediately sustain an unsubsidised tariff, or that the same assistance is currently available for another project. World Bank · EASE results, October 2024

Inga 3 sits on a separate development clock. In June 2025, the World Bank approved a $250 million first phase within a $1 billion development programme, beginning with communities, studies, institutional capability and project preparation. The Bank described a potential 2–11 GW development and around a decade for preparation and construction. This was not an announcement that the dam’s construction was fully financed or that its power was about to become available. The distinction affects the kind of capital, development capability and investment horizon required. World Bank · Inga 3 programme approval, June 2025

GEB’s interpretation is to keep operating-service opportunities and long-horizon hydro preparation separate in an investor’s pipeline. Distributed projects need evidence on customer acquisition, actual bills, collection history, technical uptime and the cost of the local network. Large hydro needs a sequence of studies, agreements, environmental and social work, financing and transmission arrangements before a revenue case can be treated as mature. In both cases, the resource is only one component of the proposition. The investable question is who receives dependable electricity, who pays for it, and what must be completed before those payments can begin.

Tanzania’s compact makes a useful distinction between access and connection: its Rural Energy Master Plan defines access by proximity to a distribution transformer, while connectivity counts people in connected households. Neither is a direct measure of energy sold. A settlement can fall inside a service area without every premises becoming a paying customer. For an investor, that means maps of electrified communities need to be paired with connection uptake and measured consumption. Tanzania · National Energy Compact, pp. 9, 21

The financial evidence needs the same care. The compact cites TANESCO’s 96% bill-collection rate in 2021/22, but its 2024/25–2034/35 corporate strategy identifies recovery of only around 80% of supply costs. These are different historical measures, not a combined 2026 financial snapshot. It also identifies approximately $1.87 billion in stabilisation, rehabilitation and operating improvements. GEB’s reading is that efficient collection cannot solve a tariff or consumption shortfall on its own, and that customer growth should be assessed alongside the cost of serving those customers. Tanzania · National Energy Compact, pp. 9, 21

Productive demand provides a more tangible lens. World Bank reporting from Buyuni in April 2025 describes electricity supporting refrigeration, printing, welding and brickmaking. These examples show how a connection can change business activity, but they are local observations rather than a national return forecast. An investment model should test whether prospective businesses have the appliances, working capital and end-market demand needed to use the electricity. Otherwise, a technically successful connection programme can still produce modest revenue per customer. World Bank · rural enterprise reporting, April 2025

Regional links also change what a new project must compete with and complement. AfDB’s 2025 Development Effectiveness Review reports that the Kenya–Tanzania interconnection, commissioned at the end of 2024, enabled power exchanges and improved voltage stability in northern Tanzania. A physical link creates system options, but it does not give every generator an export contract. For a proposed asset, the relevant assessment remains the actual connection point, dispatch arrangements, network charges and buyer, including how competing supplies affect its value. AfDB · Development Effectiveness Review 2025, p. 27

GEB’s interpretation is to prioritise a defined service area and a realistic demand-development plan. A network upgrade linked to existing productive customers, or a connection portfolio accompanied by finance for usable equipment, may warrant closer assessment than a forecast based solely on population. The model should examine load growth in stages, affordability, maintenance requirements and payment security under slower uptake. The opportunity is to make electricity economically useful to more customers while improving the performance of the system supplying them; the evidence required is local, commercial and operational.