The first quarter of 2026 marks a significant shift in Serbia’s electricity market as the Carbon Border Adjustment Mechanism (CBAM) enters its definitive phase, fundamentally altering the country’s role in Southeast Europe’s power landscape. This transition reflects a movement away from a historically export-oriented, coal-dependent system towards one that is increasingly constrained and focused on domestic needs amid tightening carbon regulations.
In Q1 2026, Serbia’s average day-ahead electricity prices were recorded at €94.7/MWh, notably lower than the EU benchmarks, which ranged between €120 and €130/MWh. Previously, such a price differential would have encouraged substantial electricity exports to neighboring countries like Hungary, Croatia, and Romania. However, this quarter saw a persistent price spread that indicates a breakdown of the arbitrage opportunities that once characterized Serbia’s cross-border trading model.
The underlying issue is the carbon cost embedded within the CBAM framework. Serbia’s default emission factor stands at 1.041 tCO₂/MWh, leading to an import adjustment cost of approximately €78.45/MWh. This effectively raises Serbia’s export prices to levels comparable to or exceeding those in the EU market, thereby compressing export margins to near-zero or negative figures. Consequently, Serbia’s electricity becomes less competitive in EU markets despite its lower generation costs.
This situation has significant implications for Serbia’s export dynamics. While the Western Balkans as a region transitioned into a net exporter during this period, this change was largely due to decreased imports rather than an increase in exports. Traditional export routes from Serbia to Hungary have seen reduced activity, and even with available interconnection capacity, there is less economic incentive to utilize it. This disconnect between available infrastructure and commercial activity highlights a fundamental shift in Serbia’s role within regional trade.
The domestic power exchange, SEEPEX, which serves as both a trading platform and regional hub, experienced an approximate 11% decline in traded volumes in Q1 2026. This downturn contrasts sharply with growth trends observed in hydro-centric markets like Albania and Montenegro. The decline signals a diminishing reliance on transit-based trading strategies that previously leveraged Serbia’s geographic advantages and price competitiveness.
As liquidity shifts away from Serbia towards markets with lower carbon exposure, price formation within the country is increasingly dictated by local supply conditions rather than regional dynamics. In Q1 2026, strong hydroelectric output across the region suppressed prices without leading to increased exports from Serbia.
Coal remains the primary source of electricity generation in Serbia, with output recorded at 5.47 TWh in Q1 2026, down from 6.08 TWh in the same period of the previous year. This reduction is attributed to lower demand for thermal generation due to favorable hydro conditions and the displacement of coal in the merit order. The ongoing reliance on coal continues to shape Serbia’s carbon profile and its exposure to CBAM-related costs.
The current market dynamics create tension for Serbia as it benefits from low marginal generation costs while facing challenges when exporting electricity to the EU due to carbon adjustments. This scenario limits Serbia’s ability to capitalize on surplus production in higher-priced markets.
In light of these developments, Serbia’s trading strategy is undergoing transformation. The previous model of exporting baseload coal generation during price divergences is no longer feasible under CBAM conditions. Trading activities are now increasingly concentrated on intra-regional exchanges within the Western Balkans, where carbon costs do not apply.
Despite these changes, physical electricity flows through Serbia continue as part of the broader regional grid network. The country remains integral to the south-north corridor linking Greece and Central Europe; however, discrepancies between commercial schedules and actual flows indicate that Serbia’s status as a transit country is not fully reflected in trading activities.
Operational challenges also arise from unscheduled flows driven by network conditions rather than commercial intent. These complexities can increase system management costs and may lead to higher network tariffs over time.
The interplay between CBAM and the EU Emissions Trading System (ETS) further complicates Serbia’s market outlook. With carbon prices averaging €75.36/tCO₂ during Q1 2026 and exhibiting volatility throughout the quarter, Serbian utilities face new financial risks linked to both electricity price fluctuations and carbon market developments.
Investment signals emerging from this period are mixed. The structural disadvantages faced by coal generation highlight an urgent need for decarbonization efforts. Investments in renewable energy sources such as wind and solar could reduce carbon exposure and enhance competitiveness in cross-border trade; however, fragmented markets may hinder these investments’ viability.
The existing thermal fleet’s scale poses additional challenges for transitioning towards a low-carbon energy system. The financial feasibility of new renewable projects will depend on not only generation costs but also access to markets and long-term contract security.
Grid infrastructure and flexibility will be crucial for integrating renewable energy sources effectively. The divergence between commercial transactions and physical flows during Q1 2026 underscores the necessity for investments in transmission capacity and mechanisms that facilitate coordination with neighboring systems.
Serbia’s strategic position within the regional grid remains valuable but is evolving towards providing balancing services rather than acting solely as a transit hub for arbitrage-driven trade. Adjustments in market design and operational practices will be essential alongside investments in technologies such as battery storage.
Looking forward, several interrelated factors will shape Serbia’s power market trajectory. Developments regarding CBAM—specifically potential adjustments to emission factors—will affect cross-border trade economics. Additionally, progress on carbon pricing mechanisms within Serbia could help align incentives with EU markets.
Overall, it is clear that Serbia’s electricity market is entering a phase of structural repositioning characterized by price decoupling and shifting liquidity patterns, necessitating navigation through this transition while maintaining system stability and investment support amidst ongoing decarbonization objectives.
