The implementation of the Carbon Border Adjustment Mechanism (CBAM) has significantly altered the landscape of electricity trading in Southeast Europe, particularly affecting traditional corridors that have long linked the Western Balkans with European Union markets. As of Q1 2026, a notable shift is evident, with cross-border exchanges between the Western Balkans and the EU experiencing a decline of approximately 25% compared to the same period in 2025. This trend reflects a broader reconfiguration driven by regulatory pressures and the need for carbon efficiency.
Historically, the Western Balkans served as a vital transit zone for electricity, enabling flows that capitalized on price differentials across various markets. Key routes such as Hungary–Serbia–Bulgaria and Croatia–Serbia–Romania were instrumental in facilitating these arbitrage transactions. However, recent data indicates a marked decrease in flows from the EU into the Western Balkans, which fell sharply by −40.7%. This shift has led to a reversal in net trade dynamics, with the region transitioning from being a net importer to a net exporter of electricity, recording approximately 1.35 TWh in exports.
The decline in imports from the EU is closely tied to uncertainties surrounding CBAM’s application to electricity transiting through non-EU countries. Traders are increasingly wary that power passing through these regions might incur carbon costs despite originating from EU sources. Consequently, this regulatory ambiguity has diminished the appeal of using Western Balkan corridors for intra-EU trade, prompting a pivot towards routes that are either fully compliant with EU regulations or involve low-carbon systems.
This transition is reshaping the role of the Western Balkans as an electricity transit hub. Electricity that would have previously traversed through Serbia or Bosnia and Herzegovina is now being redirected via alternative pathways that prioritize low-emission systems capable of avoiding CBAM costs. Albania stands out as a significant beneficiary in this evolving landscape due to its hydroelectric generation capacity and minimal emission factors. In Q1 2026, Albania increased its scheduled exports across borders to Greece, Kosovo, and Montenegro by approximately 1.2 TWh, capitalizing on its unique position within the CBAM framework.
The surplus generated by Albania has not been confined to neighboring countries but has extended into broader EU markets such as Bulgaria and Italy via Greece. The increased hydro generation capacity in Greece has positioned it as an essential intermediary for Albanian electricity moving northward and westward into EU markets. This emerging south-to-north corridor emphasizes low-carbon generation as an alternative to traditional routes reliant on coal-heavy systems.
This shift underscores a growing trend where traders optimize their routes based on carbon exposure rather than merely economic considerations. The focus is increasingly on minimizing CBAM-related costs, even if it means selecting longer or less direct pathways for electricity transport. Intra-regional trading within the Western Balkans has intensified as well; with constrained cross-border exchanges with the EU, regional markets are now looking inward for trade opportunities.
The implications of this inward shift extend to market liquidity and price formation within the Western Balkans. While increased intra-regional trading can bolster liquidity and enhance price discovery processes, it does not fully compensate for reduced access to higher-priced EU markets. Consequently, there is a redistribution of trading activity rather than genuine expansion, which may affect revenue generation and overall market depth.
The performance of specific interconnectors highlights this reconfiguration further; for instance, utilization rates for the Montenegro–Italy submarine cable have declined despite offering access between lower-priced WB6 markets and higher-priced EU markets. Scheduled flows from Montenegro to Italy decreased by over 2,100 MWh per day, indicating that CBAM costs have negated previous economic advantages associated with these interconnections.
This evolving dynamic illustrates that interconnector value is increasingly influenced by regulatory environments rather than solely by price differentials or capacity limitations. Interconnectors linking low-carbon systems with EU markets may retain or even increase their value while those connecting high-emission systems face declining utilization rates.
A divergence between commercial schedules and physical flows adds complexity to this new landscape; while traders adapt their schedules to mitigate CBAM exposure risks, actual electricity flows continue according to grid characteristics. This mismatch introduces inefficiencies into transmission operations, raising concerns about congestion management and operational stability.
As Southeast Europe’s energy landscape continues to evolve under these regulatory pressures, questions arise regarding future infrastructure development strategies. Existing projects based on stable arbitrage assumptions may require reassessment due to changing market conditions influenced by CBAM mechanisms.
The broader strategic implication suggests that Southeast Europe’s electricity network is transforming from one focused on economic efficiency towards one shaped increasingly by carbon policy frameworks. The traditional approach—prioritizing cost-effective routes—now coexists with new imperatives aimed at managing carbon exposure effectively.
Looking forward, ongoing trends will likely hinge on several factors including clearer guidelines concerning transit flows under CBAM regulations and potential adjustments to emission factor methodologies within both EU and non-EU contexts. While some shifts may occur towards aligning incentives across these regions, it remains clear that carbon pricing will play an integral role in shaping future trade patterns within Southeast Europe’s electricity markets.
