The European Union’s Carbon Border Adjustment Mechanism is no longer a theoretical policy instrument but a market-moving force that is reshaping electricity trade patterns across Southeast Europe. While much of the early analytical focus has been placed on bilateral cases such as Croatia and Bosnia and Herzegovina, the systemic implications are most clearly visible when the lens is shifted to Serbia, which today stands as the largest electricity producer in Southeast Europe outside the EU and the most structurally important transit and balancing hub between EU and non-EU power systems in the region.
Serbia’s electricity system occupies a unique position. It combines scale, diversity of generation assets, central geography, and dense interconnection with almost every neighbouring market. With total annual electricity generation fluctuating around 35–38 TWh, Serbia produces more power than any other Western Balkan country, and materially more than Croatia or Bosnia and Herzegovina individually. This scale matters under CBAM, because carbon pricing does not affect marginal trade flows alone; it reorders regional dispatch hierarchies, congestion patterns, and investment logic across interconnected systems.
At the core of Serbia’s power sector is Elektroprivreda Srbije, which operates a fleet dominated by lignite-fired thermal power plants complemented by large hydropower assets on the Danube, Drina, Lim, and Morava river systems. Lignite still accounts for roughly 65–70 percent of installed capacity and a similar share of generation in normal hydrological years. Average emissions intensity of Serbian baseload lignite units remains high, typically in the range of 0.9–1.05 tCO₂/MWh, placing Serbia among the most carbon-intensive power producers on the European continent.
For more than a decade, this structure enabled Serbia to act as a regional electricity exporter and price stabiliser, supplying neighbouring markets during peak demand and hydrological shortfalls. Power flows from Serbia into Bosnia and Herzegovina, Montenegro, North Macedonia, Hungary, Romania, and occasionally Croatia have been a routine feature of Southeast European market operation. Under a pre-CBAM environment, the absence of an explicit carbon price allowed Serbian lignite-based electricity to remain cost-competitive across borders, even when wholesale prices in EU markets tightened.
CBAM changes that arithmetic fundamentally. By imposing a carbon cost equivalent to the EU Emissions Trading System on electricity imports from non-EU countries, CBAM effectively internalises the carbon intensity of Serbian power when it enters EU markets. With EU ETS prices averaging €75–90 per tonne of CO₂ during 2025 and forward curves pointing toward €90–120 per tonne by 2030, the implied carbon surcharge on Serbian lignite-based electricity exported to the EU reaches €70–110 per MWh. This is not a marginal adjustment; it is a structural repricing that pushes lignite-based exports out of merit order in most trading hours.
The immediate implication is that Serbia’s historical export corridors into EU Member States, particularly Hungary, Romania, and Croatia, face declining utilisation under CBAM-aligned pricing. Even in hours of high demand, Serbian exports increasingly clear only when hydropower or low-carbon generation sets the marginal price. In contrast, lignite-based exports are crowded out by EU-based generation that already internalises carbon costs or by renewable sources with near-zero marginal emissions.
Yet Serbia’s importance does not diminish under CBAM; it changes character. Rather than acting primarily as a low-cost exporter of baseload electricity, Serbia is evolving into a regional balancing and transit hub, where internal dispatch decisions and cross-border flows influence price formation across multiple neighbouring systems simultaneously. This role is amplified by Serbia’s grid topology and its central position within the Energy Community network, linking Adriatic, Danube, and Pannonian power corridors.
CBAM also reshapes Serbia’s relationships with non-EU neighbours. Bosnia and Herzegovina and Montenegro, both smaller and more hydrologically volatile systems, increasingly rely on Serbian imports during periods when their own carbon-intensive generation becomes uneconomic or constrained. In such scenarios, Serbia may paradoxically shift from exporter to net importer of electricity from the EU, while simultaneously exporting power eastward or southward to non-EU markets. This triangular flow pattern increases congestion risks and places new operational demands on transmission system coordination.
From a system cost perspective, Serbia faces a dual pressure. On one hand, CBAM reduces export revenues from EU-bound electricity, particularly from lignite units that previously monetised surplus generation. On the other hand, higher regional prices driven by carbon costs can raise domestic wholesale price benchmarks, especially in dry hydrological years when thermal generation sets the marginal price. Wholesale prices in Serbia, which historically hovered in the €50–70/MWh range, are increasingly exposed to EU price signals exceeding €80–100/MWh during tight system conditions.
These dynamics directly affect investment incentives. For decades, lignite assets in Serbia were economically rational under a low-carbon-cost regime. Under CBAM, their long-term revenue certainty erodes, particularly if Serbia aligns its domestic carbon policy with EU standards. The financial exposure is significant: Serbia’s lignite fleet represents several gigawatts of installed capacity with residual technical life extending into the 2040s. Under high carbon price scenarios, capacity factors for these plants decline sharply, raising questions around stranded asset risk and balance-sheet stress for EPS.
At the same time, CBAM strengthens the investment case for low-carbon capacity in Serbia. Hydropower remains a cornerstone, but its expansion potential is limited by environmental constraints and hydrological risk. Wind and solar, by contrast, are entering a phase of rapid scale-up. Utility-scale solar projects in Serbia now routinely achieve levelised costs below €50/MWh, while onshore wind projects in favourable locations approach €45–55/MWh, even before accounting for carbon advantages. Installed capacity costs of €600–900/kW for solar and €900–1,200/kW for wind place these technologies firmly within bankable territory, particularly when paired with long-term offtake arrangements.
Grid flexibility emerges as a decisive factor. Serbia’s large hydropower reservoirs provide valuable short-term balancing, but the growing penetration of variable renewables across the region increases the need for fast-response assets. Battery energy storage systems, currently deployed at pilot scale, are expected to become economically viable as costs fall toward €200–250/kWh installed by the late 2020s. Such assets would allow Serbia to monetise its hub position by arbitraging price spreads between EU and non-EU markets under CBAM-driven volatility.
Regulatory alignment remains the strategic wildcard. Serbia is not yet part of the EU ETS, but discussions around carbon pricing mechanisms are intensifying. A domestic carbon tax or an ETS-like system, even at a lower introductory price, would allow Serbia to partially internalise carbon costs and recycle revenues into grid upgrades, renewable subsidies, and social transition measures. Without such alignment, Serbian exporters face CBAM charges at the EU border without capturing the fiscal upside domestically, effectively exporting carbon rent to EU treasuries.
Looking toward 2030, most credible energy outlooks anticipate sustained high carbon prices, tighter EU emission caps, and accelerated electrification of industry and transport. Under these conditions, Serbia’s electricity system will sit at the crossroads of decarbonisation pressures and regional market integration. Forecast scenarios suggest that by 2030 Serbia could remain a net exporter in energy terms, but only if low-carbon generation expands rapidly enough to offset declining lignite competitiveness. Otherwise, Serbia risks becoming a structural importer during peak periods, exposed to EU price volatility without the full benefits of market integration.
For investors, lenders, and policymakers, the message is clear. CBAM does not marginally adjust Serbia’s electricity trade; it redefines Serbia’s systemic role in Southeast Europe. The country’s future value lies less in exporting cheap carbon-intensive baseload and more in providing flexibility, interconnection, and low-carbon capacity to a region undergoing rapid regulatory convergence with the EU. Strategic decisions taken in the next five years—on carbon policy, grid investment, and generation mix—will determine whether Serbia consolidates its position as the indispensable power hub of Southeast Europe or sees that role gradually eroded by carbon-aligned markets to its west.
In this sense, CBAM acts as both constraint and catalyst. It constrains legacy export models built on lignite economics, while catalysing a transition toward a more resilient, flexible, and investment-grade power system. For Serbia, the largest electricity producer in the region, the stakes are correspondingly higher—and so is the opportunity to shape the future architecture of Southeast Europe’s electricity market.
Elevated by cbam.engineer
