The implementation of the European Union’s Carbon Border Adjustment Mechanism (CBAM) is reshaping the electricity trading landscape in Southeast Europe. Initially intended to curb carbon leakage, CBAM is now influencing price disparities and trading strategies, particularly in the Western Balkans, where power traders are increasingly active.
As of early 2026, a notable influx of new trading firms has been observed in the Balkan electricity markets. These entities are capitalizing on the expanding price spreads arising from differences between EU carbon-priced markets and those in neighboring countries that lack similar carbon pricing mechanisms. This shift indicates a broader impact of carbon regulation on electricity markets beyond its original scope.
At the heart of these emerging arbitrage opportunities lies the disparity between markets governed by the EU Emissions Trading System (EU ETS) and those outside its framework. Under EU ETS regulations, electricity producers must acquire allowances for their carbon emissions, significantly affecting operational costs for fossil-fuel plants.
Recent trading data shows that EU carbon allowances have fluctuated between €60 and €80 per tonne of CO₂. For coal-fired power plants, which emit approximately 0.9–1.1 tonnes of CO₂ per MWh, this translates to costs ranging from €55 to €80 per MWh. In contrast, gas-fired plants face lower carbon costs, typically between €20 and €35 per MWh. These expenses are directly reflected in wholesale electricity prices across EU markets.
The situation is markedly different in the Western Balkans, where many countries do not fully participate in the EU ETS. Consequently, electricity prices in this region often reflect only fuel and operational costs without an explicit carbon price component. This creates a structural price differential compared to EU markets, which CBAM aims to address when electricity crosses into the EU.
Coal generation remains predominant in the Western Balkans, making it one of Europe’s most carbon-intensive electricity regions. Countries like Serbia rely heavily on lignite-fired power plants operated by Elektroprivreda Srbije, with coal accounting for about two-thirds of Serbia’s electricity production. Similarly, Bosnia and Herzegovina and North Macedonia depend on lignite-based generation.
This reliance on coal has historically allowed these nations to export electricity at competitive prices due to low fuel costs and a lack of environmental pricing through carbon markets. However, with CBAM’s introduction, imports into the EU from non-carbon-priced countries will incur implicit carbon costs aligned with EU ETS prices. This change diminishes the cost advantage previously held by coal-based exports and introduces volatility into trading strategies.
Electricity trading thrives on price discrepancies across interconnected markets; traders can leverage these differences by purchasing power where it is cheaper and selling it where prices are higher. The introduction of CBAM adds complexity by making carbon intensity a factor in determining price competitiveness.
As traders adjust their pricing models to account for anticipated CBAM costs, divergences between Balkan electricity prices and EU benchmarks—such as Hungary’s HUPX exchange or Italy’s IPEX—are becoming more pronounced. Recent trends suggest that Balkan prices are beginning to decouple from these benchmarks as market participants factor in future impacts from CBAM.
This environment has prompted some trading firms to develop strategies aimed at profiting from these new price spreads driven by CBAM dynamics. Traders must now consider various factors such as carbon intensity across different markets, expected trajectories for EU ETS prices, renewable generation variability, cross-border transmission constraints, and local hydropower availability when formulating their approaches.
The increased activity has attracted not only traditional energy traders but also financial investors looking to capitalize on evolving market conditions. Modern trading firms operate at the nexus of commodity and financial markets using instruments like futures contracts and options linked to both electricity and carbon allowances to manage risks effectively.
The long-term implications of CBAM for regional power markets could be profound. By effectively exporting the EU carbon price into neighboring systems, countries that export electricity will increasingly be incentivized to reduce their generation portfolios’ carbon intensity. This shift could enhance the value of renewable energy resources not only for domestic consumption but also for maintaining competitiveness in exports.
Such dynamics may accelerate renewable energy deployment across Southeast Europe as wind and solar generation sources become more favorable compared to traditional fossil-fuel-based production methods burdened by CBAM adjustments.
The evolution of the region’s electricity systems reflects not only climate policy influences but also emerging economic realities shaped by market dynamics driven by regulatory frameworks like CBAM.
