Cross-border flows were one of the defining features of SEE electricity trading in Week 25. While regional net imports declined by 20.4% to 1.03 TWh, the headline figure conceals a far more nuanced market picture. Italy remained the region’s largest net importer with 1.12 TWh, Croatia increased its net imports by 26.0%, Greece and Bulgaria strengthened their export positions, and Serbia shifted from net imports of 107 GWh to net exports of 21 GWh. These movements highlight how rapidly regional power balances can change as market conditions evolve.
This was a week in which cross-border transmission capacity proved just as important as generation costs. The region simultaneously contained areas with surplus electricity and markets facing stronger demand and higher prices. Greece and Bulgaria traded at comparatively lower price levels, while Italy, Hungary, Romania, and Croatia recorded significantly higher averages. As a result, the key commercial challenge was not only identifying where electricity was cheapest, but also determining whether power could be delivered efficiently to the markets where it was most valuable during the right trading hours.
Italy’s import demand remained a major driver of regional flows. An average electricity price of €127.69/MWh created a substantial premium over most SEE markets and reinforced incentives for cross-border trading. Hungary, Romania, and Croatia also entered higher-price territory, increasing the value of cross-border optionality for traders and market participants. Serbia’s transition into a net export position further demonstrates how markets with relatively lower prices can quickly become suppliers when neighboring systems experience tighter conditions.
The week also underscored the growing significance of network congestion. Price spreads alone do not create trading opportunities if transmission capacity is unavailable. A low-price market without sufficient export capability remains isolated, regardless of its generation surplus. Conversely, a moderately priced market with reliable access to higher-priced neighboring zones can unlock substantial commercial value. This dynamic is increasingly shifting the regional trading focus toward hourly transmission capacity, nomination strategies, balancing exposure, and the monetization of congestion rents.
For renewable energy developers, cross-border flows are becoming an increasingly important factor in project economics and long-term bankability. Projects located in markets with recurring periods of local oversupply may experience weaker capture prices unless they are supported by export opportunities, storage assets, or structured offtake arrangements. For industrial electricity consumers, greater regional integration introduces additional procurement considerations, as domestic prices can remain elevated even when local generation conditions improve.
Week 25 confirms that Southeast Europe is no longer a collection of largely independent national electricity markets connected by occasional trading activity. Instead, the region is evolving into a more integrated and interconnected scarcity-driven power network, where price formation is increasingly influenced by regional rather than purely domestic fundamentals. In this environment, the market participants most likely to succeed will be those capable of analyzing price spreads, transmission constraints, and hourly generation patterns as part of a single integrated trading strategy.
