Solar power is rapidly transitioning from a marginal contributor to a central pillar of the South-East European electricity system, with April 2026 developments confirming a broad-based acceleration in both utility-scale and distributed photovoltaic deployment across the region.
At system level, solar generation already accounts for approximately 15% of the regional power mix, with output increasing by +630 MW in early April compared with the previous period, even as overall demand declined due to seasonal temperature effects. This combination of rising supply and weaker consumption has reinforced midday oversupply dynamics, increasingly shaping price formation and export behavior across interconnected markets.
The pipeline of new projects reflects a shift toward both scale and diversification. In Bosnia and Herzegovina, state utility EPBiH has moved forward with a 50 MW solar development in Gračanica, backed by a financing structure combining €25 million from the EBRD and €15 million from UniCredit, positioning the project as one of the first utility-scale photovoltaic investments aligned with the country’s post-coal transition strategy. The project’s location on rehabilitated mining land underscores a broader regional trend of repurposing legacy industrial sites into renewable generation assets.
At the same time, distributed solar is beginning to scale across public infrastructure. EPBiH has launched a parallel rollout of rooftop photovoltaic systems across multiple operational facilities, with capacities ranging between 25 kW and 240 kW, signaling a shift toward decentralized generation models and internal energy balancing within state utilities. While relatively modest in aggregate capacity, such deployments are critical for reducing system losses and smoothing localized demand peaks.
Romania continues to stand out as one of the most dynamic solar markets in the region, with multiple large-scale portfolios combining photovoltaic generation with storage. Recent developments include large hybrid solar and battery projects supported by international investors, alongside a broader pipeline targeting gigawatt-scale capacity additions. This expansion is reinforced by parallel grid investments exceeding €280 million annually, aimed at accommodating rising renewable penetration and enabling cross-border exports.
In Greece, solar deployment has already reached industrial scale, with PPC completing 2.13 GW of solar capacity in Western Macedonia, transforming former lignite regions into renewable energy hubs. The scale of this build-out is beginning to influence regional price curves, particularly during daylight hours, where solar generation is increasingly displacing gas-fired marginal units.
Albania, traditionally dominated by hydropower, is also integrating solar into its energy mix, with projects such as the 140 MW Karavasta solar plant and new battery-linked installations near Fier. The strategic focus is not only on generation but on flexibility, with storage systems designed to mitigate hydrological variability and stabilize export capacity.
Montenegro presents a more nascent but strategically significant solar pipeline. Planned developments such as the 250–300 MW Briska Gora solar park and floating photovoltaic concepts at Krupac signal the country’s intention to leverage its interconnection with Italy as a conduit for renewable exports.
Across the region, a common structural constraint is emerging: grid capacity. More than 120 GW of renewable projects across Europe face potential delays due to network congestion, and SEE is no exception. Transmission limitations are increasingly dictating project timelines and investment decisions, with developers prioritizing locations where connection capacity remains available.
This constraint is also beginning to influence market outcomes. As solar penetration rises, midday prices are being systematically compressed, creating intra-day spreads that are reshaping trading strategies. Electricity prices across SEE exchanges during April 1–15 averaged between €94 and €102/MWh, but underlying volatility within the day is increasing as solar output peaks.
The implications for market structure are significant. Solar is no longer simply reducing fuel costs; it is actively redefining dispatch patterns, export flows, and price formation. As the marginal cost of generation during peak solar hours approaches zero, the value of flexibility—whether through storage, demand response, or cross-border capacity—is rising sharply.
Looking ahead, the trajectory of solar development in South-East Europe suggests continued expansion, but with a growing emphasis on system integration rather than capacity alone. Hybrid projects combining solar with storage, as well as co-location with existing hydro assets, are likely to dominate the next phase of investment. The region’s ability to translate this capacity into sustained export revenues will depend on resolving grid bottlenecks and aligning market design with the realities of high renewable penetration.
