**Categories:** ONA Feature **Tags:** Africa, wind energy, renewable energy, GWEC, electricity infrastructure **Excerpt:** Africa has estimated onshore wind potential of 58,400 GW, while installed capacity reached 11.1 GW at the end of 2025. The sector’s next phase of growth will depend less on natural resources than on grids, financing, power purchase rules and project preparation. **Slug:** potentiel-eolien-afrique-capacites-installees-investissements **Image alt:** A wind farm on an African plateau, with turbines connected to the electricity grid.
Africa has considerable wind resources, but only a tiny fraction is converted into electricity. According to the Global Wind Energy Council (GWEC), the continent’s technical onshore potential is estimated at 58,400 gigawatts, while installed capacity stood at 11.1 GW at the end of 2025. The report published on October 7, 2026, highlights a striking gap between physical possibilities and equipment actually connected to the grid.
The same report identifies 186 GW of planned wind projects across more than 250 initiatives and estimates that African capacity could reach between 30 and 50 GW in 2035. These projections indicate momentum and a project pipeline, but they are not guaranteed capacity. Announced projects can be delayed, resized or abandoned before construction. The challenge now is to move some of these ambitions toward final investment decisions and commissioning.
Technical potential is not a construction plan
An estimate of potential indicates where wind conditions could support electricity generation under certain assumptions. It does not mean that every site is accessible, connectable, profitable or acceptable to communities. Assessments must account for roads, power lines, soil conditions, land uses, protected areas and proximity to consumers.
Africa’s geography offers diverse resources: coastal corridors, high plateaus, desert areas and regions with steady winds. Egypt, Morocco and South Africa are among the most established markets, with facilities already operating and expansion projects. Other countries have promising potential but still need to build power purchase frameworks and infrastructure capable of accommodating variable generation.
The aggregate potential of 58,400 GW must therefore not be interpreted as a realistic short-term target. The figure alone does not account for demand backed by the ability to pay, grid expansion or the cost of capital. It signals an abundance of potential resources; the next step is to identify sites where wind, access, grid capacity and demand combine to make a competitive project possible.
Grids and contracts determine bankability
A wind farm generates when wind is available, following profiles that do not always coincide with peak consumption. The grid must be able to integrate this output, transport it and balance differences with other generating sources. Insufficient lines can force a plant to curtail output even when the turbines are working properly. Planning must therefore link investment in wind farms with investment in transmission, interconnection and storage.
Power purchase agreements play an equally important role. Lenders and developers need clarity on electricity prices, contract duration, the buyer’s creditworthiness and rules governing grid interruptions. When tariffs are revised unpredictably or payments are delayed, financing costs rise. Public guarantees can help unlock projects, but must be assessed against the fiscal risks they transfer to the state.
GWEC indicates that demand from businesses and industrial users is supporting a new wave of projects and that new financing models are emerging. Direct contracts between producers and private buyers can complement public tenders. However, they are mainly suited to companies with a strong ability to pay and consumption profiles compatible with generation. Their development must align with grid rules and national planning.
A value chain still to consolidate
Wind deployment can create benefits beyond electricity generation: construction jobs, maintenance, engineering services, training and component manufacturing. However, industrial localization depends on market volumes and continuity. An equipment factory cannot be viable if projects are sporadic and demand remains uncertain.
Governments can strengthen these benefits by providing visibility on tenders, training technicians and encouraging regional suppliers. Local content rules must nevertheless be calibrated to avoid raising costs or slowing the first capacity additions. A gradual strategy can begin with services, assembly and maintenance before targeting more complex components when the market reaches sufficient scale.
Local acceptance deserves the same attention. Site selection, compensation, shared benefits and consultation must begin early. Projects are located in areas where land may serve agriculture, pastoralism or other activities. Transparent planning reduces the risk of conflict and improves investment decisions.
Turning the pipeline into actual capacity
The 186 GW identified in the pipeline reflect growing interest from developers and investors. To distinguish the most advanced projects from preliminary announcements, permits, signed contracts, financial close, construction starts and grid connections must be tracked. These milestones, more than the number of projects announced, allow the pace of deployment to be assessed.
The possibility of reaching 30 to 50 GW in 2035 will depend on decisions made now. States will need to prepare sites that can be connected, accelerate grid studies, organize regular tenders and ensure coordination between producers and grid operators. Financial institutions can reduce the cost of capital, but cannot replace credible rules or a buyer capable of honoring its commitments.
The contrast between technical potential and existing installations thus captures the sector’s challenge. Wind is available, but the ability to harness it depends on institutions, financing and infrastructure. If execution conditions improve, wind power can diversify electricity systems, reduce their dependence on imported fuels and support industrial activity. The next measure of progress will be converting the pipeline into financed construction projects, then into reliably delivered electricity.