The first quarter of 2026 marks a decisive turning point for Serbia’s electricity market. The entry of the Carbon Border Adjustment Mechanism into its definitive phase has not simply altered regional trade flows; it has directly reshaped Serbia’s position within Southeast Europe’s power system. What emerges is a market undergoing a structural transition—from a historically export-capable, coal-anchored system integrated through arbitrage with EU markets, toward a more constrained, domestically anchored system facing tightening carbon-adjusted economics.
Serbia’s electricity pricing in Q1 2026 reflects this shift with unusual clarity. Average day-ahead prices settled at €94.7/MWh, significantly below neighbouring EU benchmarks, which remained clustered between €120–130/MWh. In a pre-CBAM environment, this spread—exceeding €30/MWh—would have translated into strong export flows toward Hungary, Croatia, and Romania. Instead, the spread persisted throughout the quarter, signalling a breakdown in the arbitrage mechanism that previously underpinned Serbia’s cross-border trading model.
The explanation lies in the embedded carbon cost. Under CBAM, Serbia’s default emission factor of 1.041 tCO₂/MWhtranslates into an import adjustment cost of approximately €78.45/MWh. This effectively transforms Serbia’s export price into a carbon-adjusted cost approaching or exceeding EU market prices. The result is a compression of export margins to near zero or negative levels, even when headline price spreads appear attractive. In practical terms, Serbia’s electricity becomes commercially uncompetitive in EU markets despite being cheaper at the point of generation.
This dynamic has immediate implications for Serbia’s export position. While the Western Balkans as a whole shifted into a net export position in Q1 2026, this was driven primarily by reduced imports rather than a meaningful expansion of exports. Serbia’s traditional export corridors, particularly toward Hungary, saw diminished commercial activity. Even where interconnection capacity remained available and highly allocated, the economic incentive to utilise that capacity weakened. This decoupling between physical availability and commercial utilisation reflects a structural change in how Serbia participates in regional trade.
The impact is further visible in the performance of the domestic power exchange, SEEPEX. As the largest exchange in the Western Balkans, SEEPEX has historically functioned as both a domestic trading platform and a regional transit hub. In Q1 2026, traded volumes declined by approximately 11%, diverging sharply from the growth observed in hydro-dominated markets such as Albania and Montenegro. This contraction reflects the erosion of transit-based trading strategies that relied on Serbia’s geographic position and price competitiveness. With CBAM reducing the attractiveness of such strategies, liquidity has shifted away from Serbia toward markets with lower carbon exposure.
This shift in liquidity has broader consequences for price formation. In a more liquid and integrated market, Serbia’s prices would be influenced by regional dynamics and cross-border arbitrage. With reduced trading activity and weaker integration, price formation becomes increasingly localised, driven by domestic supply conditions rather than regional equilibrium. In Q1 2026, this localisation was reinforced by strong hydro output across the region, which suppressed prices in the Western Balkans without translating into increased exports.
Serbia’s generation mix plays a central role in this transformation. Coal remains the dominant source of electricity, with output in Q1 2026 at 5.47 TWh, down from 6.08 TWh in the same period of 2025. This reduction reflects both lower demand for thermal generation due to strong hydro availability and the displacement of coal in the merit order. However, the structural reliance on coal continues to define Serbia’s carbon profile, and by extension, its exposure to CBAM costs.
This creates a fundamental tension in the market. On one hand, Serbia benefits from relatively low marginal generation costs, particularly in its coal fleet. On the other hand, these costs are effectively offset by carbon adjustments when electricity is exported to the EU. The result is a system that is competitive domestically but constrained externally, limiting its ability to monetise surplus generation in higher-priced markets.
The implications for Serbia’s trading strategy are significant. The traditional model of exporting baseload coal generation into EU markets during periods of price divergence is no longer viable under current CBAM conditions. Instead, trading activity is increasingly focused on intra-regional exchanges within the Western Balkans, where carbon costs do not apply. This inward shift reduces Serbia’s exposure to EU markets and alters the geography of its trading relationships.
At the same time, physical electricity flows continue to move through Serbia as part of the broader regional grid. The country remains a critical node in the south–north corridor linking Greece, the Western Balkans, and Central Europe. However, the divergence between commercial schedules and physical flows means that Serbia’s role as a transit country is no longer fully reflected in trading activity. Electricity may physically pass through the system, but the associated commercial value is diminished, reducing the economic benefits of its strategic position.
This divergence introduces operational challenges for the Serbian transmission system. Unscheduled or loop flows, driven by physical network conditions rather than commercial intent, can increase the complexity of system management. Transmission system operators must balance flows that do not align with scheduled trades, raising the cost of balancing and the risk of congestion. Over time, these factors could translate into higher network tariffs and increased system costs.
The interaction between CBAM and EU ETS adds further complexity to Serbia’s market outlook. With carbon prices averaging €75.36/tCO₂ in Q1 2026 and exhibiting volatility during the quarter, the cost of exporting electricity is now linked to developments in the carbon market. This introduces a new layer of financial risk for Serbian utilities and traders, who must manage exposure not only to electricity price fluctuations but also to carbon price movements. The integration of these two markets represents a shift toward a more financialised trading environment, requiring new capabilities in risk management and hedging.
From an investment perspective, the signals emerging from Q1 2026 are mixed and, in some respects, contradictory. The structural disadvantage imposed on coal-based generation suggests a need for accelerated decarbonisation. Investments in renewable energy—particularly wind and solar—offer a pathway to reducing carbon exposure and improving competitiveness in cross-border trade. At the same time, the fragmentation of markets and the reduction in cross-border flows can undermine the scale and integration needed to support such investments.
For Serbia, the challenge is compounded by the scale of its existing thermal fleet and the capital required to transition to a low-carbon system. The economics of new renewable projects depend not only on generation costs but also on access to markets and the ability to secure long-term contracts. If cross-border trade remains constrained, the effective market size for these projects is reduced, potentially affecting their bankability.
Grid infrastructure and system flexibility also become critical factors in this transition. The integration of renewable generation requires a more flexible and resilient grid, capable of managing variable output and balancing supply and demand in real time. In Q1 2026, the divergence between commercial and physical flows highlighted the limitations of the current system, underscoring the need for investment in transmission capacity, balancing mechanisms, and coordination with neighbouring systems.
The strategic position of Serbia within the regional grid remains an asset, but its value is evolving. Rather than serving primarily as a transit hub for arbitrage-driven trade, Serbia’s role may shift toward that of a balancing and flexibility provider within a more segmented regional system. This would require a reorientation of both market design and operational practices, as well as investment in technologies such as battery storage and demand-side management.
Looking ahead, the trajectory of Serbia’s power market will depend on several interrelated factors. The evolution of CBAM itself—particularly the potential refinement of emission factors and the treatment of transit flows—will influence the economics of cross-border trade. The development of carbon pricing mechanisms within Serbia could reduce the asymmetry with EU markets, aligning incentives and facilitating integration. At the same time, the pace of renewable deployment and grid modernisation will determine the country’s ability to adapt to a carbon-constrained environment.
What is already evident from Q1 2026 is that Serbia’s electricity market is entering a period of structural repositioning. The combination of price decoupling, export compression, and shifting liquidity patterns signals a departure from the model that has defined the market in recent years. The challenge now is to navigate this transition in a way that preserves system stability, supports investment, and aligns with the broader objectives of decarbonisation and regional integration.
In this emerging landscape, Serbia’s competitive position will increasingly depend not on the cost of its existing generation assets, but on its ability to adapt to a market where carbon intensity is a central determinant of value. The shift is already underway, and its implications will continue to unfold as CBAM moves from an initial shock to a defining feature of the region’s electricity markets.
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