For many years, hydropower has been the cornerstone of Southeastern Europe’s electricity market, providing low-cost energy generation and crucial balancing capabilities. Countries such as Montenegro, Bosnia and Herzegovina, Serbia, Albania, and Romania have relied on their extensive reservoir systems to ensure energy security and generate export revenues. However, recent developments indicate that this traditional model is undergoing a significant shift.
In May 2026, data revealed a notable decline in hydro generation across the HU+SEE system, with a decrease of approximately 357 MW compared to previous periods. This drop occurred despite favorable hydrological conditions in parts of the Western Balkans, highlighting a broader trend affecting the market value of hydroelectric exports.
This shift is not solely attributable to weather patterns; it reflects a structural transition within the energy market. Factors such as increased solar penetration, changing cross-border electricity flows, and fluctuating pricing dynamics are reshaping the landscape. For instance, in Montenegro, the state utility EPCG reported a reduction of around €13 million in export revenues during the first quarter of 2026 due to market effects related to the Carbon Border Adjustment Mechanism (CBAM), even amidst strong hydrological conditions.
Historically, robust hydrological conditions translated into higher profitability for utilities in the region. Reservoir-rich nations like Montenegro and Albania capitalized on surplus generation by exporting to higher-priced markets such as Italy. However, with Italy experiencing increased solar oversupply during midday hours, prices have compressed significantly at times when Balkan hydropower would typically maximize its exports. This has resulted in a marked decline in hydro monetization efficiency.
The impact of these changes is evident in regional commercial flow data; net exports from SEE to Italy shifted from approximately +310 MW previously to -148 MW in early May 2026. This reversal is critical as Italy has historically served as a premium balancing market for SEE exporters.
As hydropower transitions from being a straightforward baseload exporter to a more complex flexibility asset, operators must adapt their strategies accordingly. The value derived from hydro assets is increasingly linked to timing optimization rather than annual generation totals. This means that operators who can strategically manage water release during peak demand periods will gain competitive advantages akin to those enjoyed by battery storage systems.
The evolving operational environment necessitates that hydropower operators optimize their strategies around several factors: evening balancing spreads, cross-border congestion management, avoidance of negative pricing scenarios, and participation in ancillary service markets. This represents a significant departure from the traditional hydro-dominated system that has characterized the region for decades.
Infrastructure investment strategies are also being affected by these shifts. In Bosnia and Serbia, discussions about hydropower cooperation on projects like Drina highlight ongoing governmental interest in hydropower as a long-term resource. However, future hydro development faces rising construction costs driven by inflation and regulatory complexities alongside increasing market volatility due to renewable energy integration.
The competition from battery storage technologies is intensifying as well. With declining costs for batteries and their capacity for rapid response compared to traditional hydropower systems, they are becoming formidable contenders for balancing revenues and intraday arbitrage opportunities. As solar growth accelerates faster than transmission infrastructure can expand in SEE, the demand for flexible balancing solutions continues to rise.
This evolution suggests that while hydropower remains an essential component of the energy mix due to its scale and storage capabilities, its operational logic is changing fundamentally. Hydro operators are increasingly required to act like active market participants managing flexibility portfolios rather than passive baseload suppliers.
The political landscape complicates this transition further. Governments in the Western Balkans continue to advocate for hydropower as both a tool for decarbonization and a strategic asset for energy security. Yet local opposition based on environmental concerns poses challenges for new projects amid stringent ESG standards imposed by European financing institutions.
Consequently, regional energy systems may increasingly adopt hybrid models that integrate various resources—including hydropower, battery storage, gas balancing solutions, cross-border interconnections, and flexible industrial demand management—to create more resilient electricity networks.
The future electricity system in Southeastern Europe will likely depend less on individual dominant technologies and more on integrated flexibility ecosystems that can adapt to dynamic market conditions. As valuation methods evolve, analysts will need to consider factors such as hourly price capture and curtailment exposure alongside traditional metrics of generation capacity.
This financialization of hydro operations marks one of the most significant structural transitions currently taking place within SEE electricity markets. While hydropower continues to play an important role, it no longer stabilizes these markets in the predictable manner seen in previous decades.
