The electricity market in South-East Europe (SEE) is experiencing a significant transformation, solidifying its role as a crucial electricity export hub within the European power landscape. As of April 2026, the region recorded average net exports of approximately –1,289 MW, indicating a shift from a previously balanced energy system to one that consistently serves neighboring markets.
This export capability is largely supported by robust transmission corridors leading to Central Europe and Italy. Flows to Austria and Slovakia averaged around –2,625 MW, while exports to Italy reached about 643 MW. This trend underscores Italy’s growing importance as a premium destination for SEE’s electricity exports. Additionally, significant eastward flows toward Ukraine and Moldova, averaging around 791 MW, highlight the region’s increasing contribution to Eastern European energy stability.
The generation landscape in SEE is characterized by a hybrid structure that combines traditional assets with competitive renewable energy sources. Hydropower remains foundational, contributing 26% of total generation, while coal accounts for 17%. Nuclear power, primarily sourced from Romania and Bulgaria, adds another 21%, ensuring reliable baseload capacity across interconnected grids.
Solar energy is becoming increasingly influential, now comprising 15% of the energy mix. In the first half of April, solar output surged by approximately 630 MW, contrasting with declines in coal and gas generation by –2,203 MW and –1,781 MW, respectively. This shift reflects both seasonal changes and evolving dispatch strategies that favor lower-cost renewable generation during daylight hours.
Despite these advancements, the region faces challenges in maximizing its export potential due to transmission bottlenecks and limited cross-border capacity allocation. Existing physical interconnections are often hampered by operational constraints and fragmented allocation practices, leading to congestion on key routes connecting the Western Balkans with Central Europe and Italy.
The integration of SEE into the broader European price framework is becoming more pronounced. Electricity prices across major exchanges from April 1–15 clustered between €94 to €102/MWh. Hungary’s HUPX recorded an average price of €102.23/MWh, Romania’s OPCOM at €100.62/MWh, and Serbia’s SEEPEX at €98.39/MWh. This convergence illustrates deeper market coupling despite ongoing structural price spreads due to congestion and differing liquidity levels.
From a trading perspective, these price differentials present notable arbitrage opportunities. Export routes from lower-priced markets such as Serbia or Bosnia and Herzegovina towards Hungary and Romania can yield spreads between €2–5/MWh. Flows towards Italy can capture premiums ranging from €12–30/MWh, particularly during peak demand periods. For a standard export position of 100 MW baseload capacity, this could translate into annual revenue potentials from intra-regional trades of around €4 million, escalating to over €15 million when optimized against Italian market conditions.
<pThe internal demand profile within SEE has softened recently, exerting downward pressure on prices. Total consumption dropped by approximately 3,788 MW, primarily due to warmer weather conditions that raised average temperatures by around 2–3°C. This decline in demand coupled with increased solar generation has reinforced the region’s export surplus while intensifying competition among exporters.
The changing generation mix is also introducing new volatility into the electricity system. A reduction in wind output by –1,494 MW emphasizes the intermittency issues tied to renewable expansion; concurrently, heightened solar penetration leads to pronounced intra-day price fluctuations. Midday prices are increasingly suppressed due to surplus generation while evening peaks are bolstered by residual demand paired with diminished renewable availability.
This evolving landscape is driving interest in energy storage solutions across SEE. Battery storage systems are emerging as essential tools for optimizing intra-day price spreads and stabilizing grid operations. A typical battery installation of 100 MW / 200 MWh, under current market conditions, could exploit price differentials around €50/MWh, potentially generating annual revenues between €2.5–3 million.
The strategic future of South-East Europe’s power sector will be shaped by three critical factors: ongoing renewable deployment—especially solar—will enhance export capacity while necessitating greater flexibility solutions; grid expansion will become vital as transmission infrastructure emerges as the primary growth constraint; and deeper integration with European markets will continue fostering price convergence while enhancing overall market liquidity and efficiency.
This evolution positions South-East Europe not merely as an ancillary player but as an integral component within Europe’s electricity framework. The region’s role now extends beyond local supply-demand balance to providing essential support for neighboring markets during periods of volatility. With competitive generation costs and strategic geographical advantages coupled with expanding interconnections, SEE stands poised as a fundamental pillar in Europe’s shifting energy architecture.
