Why Kenya Is Buying More Electricity From Ethiopia

Why It Matters

Cheaper, cleaner imports lower Kenya’s electricity tariffs and bolster its industrial competitiveness, while Ethiopia monetises surplus hydro capacity to fund electrification.

Key Takeaways

• Kenya’s Ethiopian imports hit 1,274 GWh, a historic high
• Hydro power from Ethiopia costs $0.066/kWh, versus $0.23/kWh locally
• Import savings equal roughly $10 m per year for Kenya
• Ethiopia earned $86.3 m from power sales, 73% of export revenue
• Thin reserve margin of 434 MW raises outage risk in Kenya

Pulse Analysis

Kenya’s reliance on Ethiopian hydroelectricity reflects a broader shift in East Africa toward regional power integration. As domestic generation struggles to keep pace with demand—recording 2,412 MW in October 2025 against 3,847 MW installed capacity—Kenya has turned to the 1,045‑km interconnector completed in 2022. The line, financed by the World Bank and AfDB, enables up to 2 GW of cross‑border flow, allowing Kenya to import low‑cost, renewable power while preserving its geothermal and wind mix. This arrangement not only curbs the need for expensive thermal generation but also stabilises the grid during periods of variable solar and wind output.

For Ethiopia, the surplus generated by the Grand Ethiopian Renaissance Dam (GERD) has become a strategic export commodity. In FY 2024/25 the country sold 7% of its 29,000 GWh output abroad, netting $86.3 million from Kenya alone. These revenues fund the nation’s electrification drive, which aims to lift household access from 44% to 75% by 2030. By monetising excess hydro capacity, Ethiopia can attract foreign exchange, reduce fiscal pressure, and justify continued investment in large‑scale generation projects, even as domestic electrification lags.

The Kenya‑Ethiopia trade exemplifies the economic logic behind the African Single Electricity Market initiative. When cross‑border tariffs are markedly lower—$0.066/kWh versus $0.18‑$0.23/kWh for Kenyan industry—regional trade becomes a cost‑effective bridge while domestic projects mature. However, scaling this model requires private investment in transmission infrastructure and innovative project structuring that pairs generation with evacuation lines. Successful examples, such as South Africa’s bundled transmission‑generation deals, illustrate a pathway to unlock capital, reduce bottlenecks, and ultimately create a continent‑wide electricity market that drives competition, lowers prices, and supports sustainable growth.