Middle-East And Africa Wind Power Market Size & Share Analysis - Growth Trends and Forecast (2026 - 2031)

Middle-East And Africa Wind Power Market Trends and Insights

Government Renewable-Energy Targets & Auctions

Sovereign auction programs are anchoring the Middle East and Africa wind power market by offering hard-currency PPAs, sovereign guarantees, and rapid bid-award cycles that shorten financial-close timelines by up to nine months.^{[3]Egyptian Electricity Transmission Company, “Annual Grid Curtailment Report 2024,” eetc.gov.eg} Saudi Arabia’s Round 6 awarded 1.5 GW of wind at USD 0.0133 per kWh, 40% below prevailing gas generation costs, and Round 7 has pre-qualified 5.3 GW of bids slated for award in 2026. Egypt issued land allocations exceeding 10 GW in 2024, front-loading its 2030 renewables target and catalyzing USD 3.5 billion of incoming foreign direct investment. Morocco and Tunisia scheduled 1.7 GW and 2 GW auctions beginning in 2026, both featuring indexed tariffs to hedge currency risk. The cumulative effect is a predictable demand pipeline that underwrites localization investments in towers, nacelles, and blades.

Falling Onshore LCOE Below Fossil Benchmarks

Levelized cost of energy for prime onshore projects in the GCC and North Africa has dropped to USD 0.030-0.035 per kWh, materially undercutting combined-cycle gas even before carbon-pricing assumptions.^{[4]International Renewable Energy Agency, “Renewable Cost Database 2024,” irena.org} Bulk procurement of nacelles, dedicated port berths at Jeddah and Sokhna, and declining financing spreads shaved capital expenditure by 13% during 2024. Capacity factors now average 38-42% against a global mean of 35%, aided by taller towers and high-energy blades. As a result, grid operators are forecasting merit-order displacement of mid-merit gas plants by 2028, accelerating planned retirements of 15-20 GW of thermal capacity. Cheaper wind also enhances fiscal positions by freeing subsidy budgets previously earmarked for imported liquefied natural gas.

Expansion of Corporate PPAs

Mining conglomerates, cement producers, and hyperscale data-center operators are locking in 10- to 20-year wind PPAs to hedge tariff escalation and address Scope 2 emissions. South African miners wheel Northern Cape wind through Eskom’s network, bypassing municipal surcharges that have risen 12% annually since 2020. In Morocco, ACWA Power’s 500 MW wind-plus-2,000 MWh battery system supplies Gotion’s EV-battery gigafactory under a fixed tariff that qualifies the factory for EU Carbon Border Adjustment Mechanism exemptions. Corporate offtakers value predictable monthly output, which varies less than 8% from long-run averages in Class 5 sites, simplifying treasury hedging. This emerging C&I segment is attracting commercial-bank club loans priced 150-200 basis points above export-credit agency debt but remains accretive given rising grid tariffs.

Grid-Expansion Investments Across GCC & East Africa

Transmission build-outs are converting stranded wind resources into bankable assets. The 530 km GCC-Oman interconnector will carry 1,600 MW when commissioned in 2027, enabling Saudi wind surpluses to meet Omani evening peaks. Extension plans toward Iraq and Jordan create a 180 GW synchronized market that can absorb 25 GW of variable renewables without curtailment. In East Africa, the Kenya-Tanzania 400 kV line energized in 2024, and the pending Tanzania-Zambia corridor will unlock eight GW of high-wind zones, lifting capacity factors to 38-42% and boosting project internal rates of return by up to four percentage points. Improved grid access reduces reliance on diesel backup, enhancing bankability and drawing pension-fund capital previously deterred by infrastructure risk.

Policy Uncertainty in Several Sub-Saharan Markets

Nigeria, Kenya, and Ethiopia illustrate how absent or shifting policy frameworks deter capital despite solid wind resources. Nigeria’s lack of sovereign guarantees leaves a 2 GW theoretical pipeline stalled at feasibility. Kenya imposed a 12-month licensing moratorium in 2024 pending grid-stability studies, freezing 800 MW of shovel-ready projects. Ethiopia’s civil conflict delayed the 300 MW Aysha plant by two years, activating force-majeure claims that spooked lenders. These markets now demand internal rates of return of 14-16%, versus 8-10% in North Africa and the GCC, to offset perceived political and currency risk. Until multilateral partial-risk guarantees scale, capital will continue flowing toward auction-driven markets with hard-currency revenue streams.

Grid Stability & Curtailment Risk

Legacy networks designed for centralized coal or gas dispatch struggle with low-inertia wind penetration. South Africa curtailed 1.2 GW of renewable output during 180 days of Stage 6 load shedding in 2024 to maintain 49.8-50.2 Hz frequency. Kenya’s 310 MW Lake Turkana project lost 22% of potential generation due to a single-circuit evacuation line, while Tanzania’s grid code requires a 10% spinning reserve that forces developers to co-locate costly battery storage. Solving these issues demands USD 8 billion for synchronous condensers, grid-forming inverters, and 4-hour batteries, investments that utilities hesitate to pass through to end-users. Curtailment, therefore, acts as an implicit 15-25% tax on wind revenues in weak-grid jurisdictions.

*Our updated forecasts treat driver/restraint impacts as directional, not additive. The revised impact forecasts reflect baseline growth, mix effects, and variable interactions.

Segment Analysis

By Location: Onshore Dominance Reflects Regulatory Gaps

Onshore projects represented the entire 18.49 GW installed base in 2025, and that figure is forecast to climb at a 16.7% CAGR to 2031, keeping onshore above 90% of the Middle East and Africa wind power market size for the rest of the decade. Developers gravitate to Saudi interior deserts, Egypt’s Gulf of Suez corridor, and South Africa’s Northern Cape because Class 4-6 resources intersect with paved roads and 132 kV interties, reducing soft-cost contingencies. Liberalized auction regimes allow rapid capital recycling, so financial close is often reached within two years of site award, versus the four-plus years typical for offshore zones.

The absence of firm seabed-leasing rules outside Morocco and Egypt leaves offshore risk matrices unresolved, so lenders demand higher equity cushions that dilute sponsor returns. While Morocco completed feasibility work for 10 GW of Atlantic capacity, and Egypt for Red Sea export hubs, neither government has issued a contract for difference templates. As a result, offshore will account for less than 5% of incremental capacity through 2031, limiting its influence on the overall Middle East and Africa wind power market share. Near term, hybrid onshore-plus-battery designs, such as the 500 MW Kenitra project, are out-competing offshore by firming output to baseload profiles without incurring marine costs.

Note: Segment shares of all individual segments available upon report purchase

By Turbine Capacity: Scaling Up for LCOE Compression

Turbines rated 3-6 MW held 74.4% of 2025 deployments, anchoring the cost curve and defining transport-route requirements across the Middle East and Africa wind power market. Above-6 MW machines are now the fastest expanding class at a 19.5% CAGR, aided by local tower fabrication in Saudi Arabia that cuts logistics by up to 15%.

A 7 MW turbine on a 140 m tower can lift site capacity factor by nearly 18% versus legacy 5 MW models, which slices levelized cost by 9-11 cents over a 20-year term. OEMs respond by shipping segmented blades and partnering with Gulf steel firms to sidestep over-height bridge restrictions. The result is a steady climb in average rating, with 6 MW-plus orders projected to approach 50% of annual additions in 2028, pushing the weighted average toward 5.8 MW. That technology pivot underpins future declines in the Middle East and Africa wind power market size per-megawatt capital requirement, a metric closely watched by Gulf sovereign-wealth funds.

By Application: Utility-Scale Anchors, C&I Accelerates

Utility plants supplied 85.3% of installed capacity in 2025, reflecting the dominance of 20-25-year sovereign-backed PPAs that attract export-credit agency debt at sub-200 basis points. These multigigawatt pipelines stabilize order books for Western and Chinese OEMs alike, anchoring the revenue base of the Middle East and Africa wind power market.

Commercial and industrial demand is rising at a 21.0% CAGR as miners, cement makers, and hyperscale data-center operators hedge grid-tariff inflation and Scope 2 exposure. Fixed 10-15-year contracts, such as the Kenitra wind-plus-storage deal, now account for about 12% of annual offtake. Although the segment remains smaller in absolute megawatts, shorter development cycles enable quicker compound growth, which broadens the customer base and diversifies cash-flow risk for independent power producers. Community schemes stay marginal because net-metering laws are either absent or capped at low quotas in most markets, so they contribute less than 2% to the Middle East and Africa wind power market share.

Note: Segment shares of all individual segments available upon report purchase

Geography Analysis

South Africa retained 30.6% of installed capacity in 2025, benefiting from six bid windows under its Independent Power Producer Procurement Program that locked in 3.8 GW of wind. Bid Window 7 added another 1.4 GW scheduled for grid connection between 2027 and 2029, yet Eskom’s Stage 6 load shedding curtailed 1.2 GW of renewable output during 2024, underscoring an urgent need for grid-forming inverters and synchronous condensers. The state utility prioritizes coal retirement in its Just Energy Transition Plan, so transmission upgrades lag generation additions, placing a soft cap on future wind awards until wheeling charges and grid bottlenecks ease.

Saudi Arabia stands out as the fastest-growing contributor to the Middle East and Africa wind power market, projected to expand at 25.7% CAGR through 2031 on the back of Vision 2030’s 50% renewable target. Round 6 and Round 7 auctions together exceed 6.8 GW of wind, while localization policies funnel USD 27.69 billion into tower, nacelle, and generator plants that will cover 60% of domestic needs by 2028. NEOM’s integrated 1,670 MW wind-to-hydrogen complex advances the export narrative and diversifies offtake beyond the Saudi grid.

Egypt, Morocco, and the wider North Africa corridor represent the third growth pole, with Egypt alone hosting a pipeline above 10 GW. Egypt’s pound depreciation of 38% versus the US dollar during 2024-2025 pushes developers to insist on hard-currency tariffs indexed to inflation. Morocco’s 1.7 GW auction program plus feasibility studies for 10 GW offshore align with a 52% renewable electricity goal, while cross-Strait proximity to Europe attracts hydrogen-linked offtake. East-African opportunities remain contingent on transmission corridors such as the Kenya-Tanzania 400 kV line, energized in late 2024, which trimmed Lake Turkana curtailment by eight percentage points.

Note: Segment shares of all individual segments available upon report purchase