Recent market data indicates that South-East Europe (SEE) is solidifying its role as a significant electricity export region within the European power landscape. As of April 2026, the region has transitioned to average net exports of approximately –1,289 MW, reflecting a shift from a previously balanced energy system to one that consistently supplies neighboring markets.
The region’s export capabilities are bolstered by robust transmission corridors leading to Central Europe and Italy. Notably, flows towards Austria and Slovakia averaged around –2,625 MW, while exports to Italy reached about 643 MW. This trend underscores Italy’s position as the region’s most lucrative market. Additionally, eastward flows to Ukraine and Moldova were significant at around 791 MW, highlighting SEE’s increasing role in supporting the stability of Eastern European energy systems.
The diverse generation mix in SEE underpins its export potential, featuring a combination of traditional dispatchable assets and competitive renewable sources. Hydropower remains critical, contributing 26% of total generation, while coal accounts for 17%, particularly vital during periods of heightened exports. Nuclear energy, primarily from Romania and Bulgaria, adds another 21%, ensuring baseload stability across interconnected networks.
A notable increase in solar generation, now constituting 15% of the energy mix, is influencing intra-day price dynamics and export trends. In early April, solar output surged by approximately 630 MW, coinciding with declines in coal and gas generation by –2,203 MW and –1,781 MW, respectively. This shift illustrates the impact of seasonal variations and changing dispatch priorities favoring lower-cost renewable energy during daylight hours.
Despite these advancements, the region’s ability to maximize its export potential is hindered by transmission bottlenecks and limited cross-border capacity allocation. Although physical interconnection exists, operational margins and fragmented allocation mechanisms often restrict effective market access. This situation leads to congestion on key corridors linking the Western Balkans with Italy and Central Europe, impeding full price convergence across markets.
The integration of SEE into the broader European price formation framework is evident, with electricity prices across major exchanges from April 1–15 clustering between €94 to €102/MWh. Hungary’s HUPX averaged €102.23/MWh, Romania’s OPCOM at €100.62/MWh, and Serbia’s SEEPEX at €98.39/MWh. This convergence indicates a deepening market coupling while underscoring persistent structural spreads due to congestion and liquidity disparities.
<pFrom a trading perspective, these price spreads create arbitrage opportunities for exporters. Routes from lower-priced markets like Serbia or Bosnia and Herzegovina towards Hungary and Romania can yield spreads ranging from €2–5/MWh, while exports to Italy may capture premiums between €12–30/MWh during peak demand periods. For a typical 100 MW baseload export position, this translates into potential annual revenues from intra-regional trades of around €4 million, escalating to over €15 million when optimized against Italian market conditions.
The internal demand profile in SEE has softened recently, exerting downward pressure on prices. Total consumption declined by approximately 3,788 MW, largely attributed to warmer weather conditions with average temperatures rising by 2–3°C. This reduction in demand coupled with increased solar generation has reinforced the region’s export surplus while intensifying competition among exporters.
The evolving energy mix is also introducing new volatility into the system. A decrease in wind output by –1,494 MW highlights challenges associated with renewable intermittency, while increased solar penetration results in pronounced intra-day price spreads. Midday prices are increasingly suppressed by surplus generation, whereas evening peaks are supported by residual demand amid reduced renewable availability.
The current dynamics are accelerating interest in energy storage solutions across the region. Battery storage systems are emerging as essential tools for capturing intra-day price spreads and stabilizing grid operations. A typical installation of 100 MW / 200 MWh could leverage price differentials of around €50/MWh, generating annual revenues estimated between €2.5–3 million, depending on operational parameters. This potential is attracting attention from utilities and financial investors alike, particularly in rapidly expanding renewable markets like Romania, Bulgaria, and Greece.
The strategic outlook for South-East Europe’s power sector will be influenced by three main factors: ongoing renewable deployment—especially solar—will enhance export capacity while necessitating flexible solutions; grid expansion and modernization will become crucial for growth as transmission infrastructure emerges as a primary bottleneck; deeper integration with European markets will continue driving price convergence, ultimately enhancing overall market liquidity and efficiency.
This transition positions South-East Europe not merely as a peripheral player but as an integral component of Europe’s electricity framework. The region’s evolving role extends beyond balancing supply and demand; it increasingly provides structural support to neighboring markets during volatility periods. With competitive generation costs and strategic geography complemented by expanding interconnections, SEE stands poised as a pivotal element in Europe’s shifting energy architecture despite ongoing infrastructure constraints and market design challenges.
