The implementation of the European Union’s Carbon Border Adjustment Mechanism (CBAM) is significantly altering the dynamics of electricity trade in Southeast Europe, particularly for Serbia. As the largest electricity producer outside the EU, Serbia’s pivotal role as a regional power hub is being redefined under this new regulatory framework, which aims to internalize carbon costs associated with electricity imports from non-EU countries.
Serbia’s electricity generation capacity stands out in the region, with annual production between 35–38 TWh, surpassing that of its Western Balkan neighbors, including Croatia and Bosnia and Herzegovina. This scale positions Serbia not only as a major power producer but also as a crucial transit point within interconnected energy markets. The country’s diverse generation assets, including lignite-fired thermal plants and substantial hydropower resources across major river systems like the Danube and Morava, contribute to its strategic importance.
Historically, Serbia has functioned as a regional exporter and stabilizer of electricity, especially during peak demand periods or hydrological shortfalls. Neighboring countries such as Bosnia and Herzegovina, Montenegro, North Macedonia, Hungary, and Romania have relied on Serbian electricity to balance their own supply challenges. However, with CBAM now operational, the economic calculus for these cross-border trades is undergoing a fundamental shift.
CBAM introduces a carbon cost that reflects the EU Emissions Trading System (ETS) pricing on Serbian electricity exports to EU markets. Projections indicate that by 2025, EU ETS prices will average between €75–90 per tonne of CO₂, potentially rising to €90–120 per tonne by 2030. This translates into an additional cost burden of approximately €70–110 per MWh for Serbian lignite-based exports. Such pricing pressures are likely to displace Serbian electricity from competitive positions in EU markets during high-demand periods.
The implications of this shift are already evident. Export pathways into key EU markets like Hungary and Romania are facing reduced utilization rates under CBAM conditions. Serbian exports may only be viable when low-carbon or hydropower sources dictate market prices. Consequently, Serbia is transitioning from a predominantly low-cost exporter to a more complex role as a regional balancing hub where it must manage internal dispatch decisions while influencing price formation in adjacent markets.
This transformation affects not just Serbia’s export strategies but also its relationships with neighboring non-EU countries. Bosnia and Herzegovina and Montenegro are increasingly dependent on Serbian imports during times when their own carbon-intensive generation becomes less economically viable. This dependency could lead Serbia to become a net importer from the EU while simultaneously exporting power to non-EU markets, creating new challenges for transmission coordination and congestion management.
From an economic perspective, CBAM presents dual pressures on Serbia’s power sector. On one hand, reduced revenues from traditional lignite exports threaten financial stability; on the other hand, rising regional prices influenced by carbon costs may elevate domestic wholesale price benchmarks beyond historical averages of €50–70/MWh, potentially exceeding €80–100/MWh during critical system conditions.
These evolving market dynamics are reshaping investment incentives within Serbia’s energy landscape. The long-term viability of lignite assets is increasingly uncertain under high carbon price scenarios. In contrast, there is growing momentum for investments in low-carbon technologies such as wind and solar energy. Recent developments indicate that utility-scale solar projects can achieve levelized costs below €50/MWh, while wind projects are approaching costs between €45–55/MWh. These trends highlight a potential pivot towards more sustainable energy sources amid shifting regulatory frameworks.
The necessity for grid flexibility is becoming apparent as variable renewable penetration increases across the region. Serbia’s existing hydropower reservoirs provide essential short-term balancing capacity; however, integrating battery storage solutions could further enhance operational flexibility as costs decline toward €200–250/kWh by the late 2020s.
A key factor influencing these developments will be Serbia’s regulatory alignment with EU standards regarding carbon pricing mechanisms. While discussions around implementing a domestic carbon tax or an emissions trading system are underway, failure to align could result in Serbian exporters facing CBAM charges without capturing corresponding fiscal benefits domestically.
Looking ahead to 2030, projections suggest that sustained high carbon prices and tighter emission caps will continue to challenge Serbia’s energy landscape. The country may remain a net exporter if it can effectively scale up low-carbon generation sufficiently to counteract declining competitiveness of lignite-based production; otherwise, it risks becoming structurally dependent on imports during peak demand periods.
The ongoing evolution of CBAM serves both as a constraint on traditional export models reliant on lignite economics and as a catalyst for transition toward more resilient energy systems capable of adapting to market changes. As the largest electricity producer in Southeast Europe grapples with these shifts, its future role will hinge on strategic decisions regarding carbon policy and investment in renewable capacities over the coming years.
