The early financial impact of the European Union’s Carbon Border Adjustment Mechanism is beginning to crystallise across the Western Balkans, exposing structural divergences between national power systems. Montenegro’s Elektroprivreda Crne Gore has already recorded a €13 million loss in the first quarter of 2026, while Serbia’s Elektroprivreda Srbije is confronting a more complex dynamic: a delayed but significantly larger exposure embedded within its generation model and industrial linkages.
This divergence is not a function of policy timing, but of system architecture.
Montenegro’s power system, smaller and more export-oriented, has translated CBAM into immediate financial losses. Serbia’s electricity sector, by contrast, remains largely domestically absorbed, with exports typically accounting for around 10% of total production. This has insulated EPS from the first wave of CBAM-related cash outflows. Yet the absence of immediate losses masks a deeper structural vulnerability that is only beginning to surface.
At the core of Serbia’s exposure lies its generation mix. EPS operates more than 4.3 GW of lignite-fired capacity, anchoring a system where coal remains the dominant baseload source. In carbon terms, this positions Serbia among the most emission-intensive electricity producers in Europe. Under CBAM mechanics, that intensity translates directly into cost.
The implied adjustment is substantial. Analysts estimate that exporting Serbian electricity into EU markets could incur an additional €50–60/MWh carbon cost, effectively eroding competitiveness in a market where wholesale prices have averaged near €90–110/MWh over the past year. In practical terms, this differential risks removing Serbian electricity from the EU merit order altogether during most trading intervals.
The consequence is not merely reduced profitability. It is the gradual loss of market access.
Where Montenegro is already experiencing a realised financial impact, Serbia is accumulating what can be described as latent losses—costs that are not yet reflected in financial statements but are embedded in future trading constraints and industrial pricing structures. Estimates suggest that CBAM-related exposure for Serbia’s electricity exports could reach approximately €200 million annually, with the broader economic impact extending beyond €250 million when indirect effects are included.
These indirect effects are central to understanding the scale of the issue. CBAM does not operate solely at the level of cross-border electricity flows; it also captures the carbon intensity embedded in exported industrial goods. For Serbia, where sectors such as steel, non-ferrous metals and chemicals are deeply intertwined with electricity consumption, the emissions profile of EPS becomes a system-wide pricing factor.
Electricity, in this context, acts as a transmission mechanism for carbon costs across the entire export economy.
The feedback loop is increasingly visible. Carbon-intensive generation raises the implicit cost of electricity. That cost is then reflected in the embedded emissions of industrial exports entering the EU. The result is a layered competitiveness penalty that extends well beyond the utility itself, reshaping margins across Serbia’s industrial base.
In contrast, Montenegro’s experience illustrates the immediate version of this dynamic. The €13 million loss recorded in the first quarter reflects both direct and indirect CBAM effects, including weaker export pricing and a shift in trading strategies. Electricity has increasingly been redirected toward regional markets to avoid EU carbon exposure, even at the cost of lower realised prices.
Serbia is already moving along a similar trajectory, albeit more gradually. EPS has the option to pivot exports toward non-EU markets in the Western Balkans, effectively bypassing CBAM in the short term. However, this strategy has structural limits. Regional markets are smaller, less liquid, and typically priced at a discount to EU benchmarks, constraining revenue potential.
Over time, this repositioning transforms EPS from a marginal EU exporter into a regional balancing utility, with reduced exposure to price spikes in coupled European markets. The trade-off is a narrowing of revenue upside precisely at a time when capital requirements are rising.
Those capital requirements are substantial. EPS has already outlined a pipeline of renewable and flexibility investments, including approximately 1 GW of solar capacity, new wind developments and the long-delayed Bistrica pumped-storage hydropower project. These projects are not simply part of a green transition narrative; they are increasingly tied to the preservation of market access under CBAM.
The economics are straightforward. Each incremental megawatt of low-carbon generation reduces the average emissions intensity of the system, lowering the effective CBAM burden. Conversely, delays in deployment compound future costs, as carbon price differentials between Serbia and the EU remain wide—currently estimated at €50–60 per tonne of CO₂.
This creates a narrowing window for strategic adjustment.
Montenegro’s experience offers a forward signal. Despite a more diversified renewable base, the presence of the coal-fired Pljevlja plant has been sufficient to generate immediate CBAM-related losses. Serbia’s heavier reliance on lignite implies that, once fully priced, the impact could be significantly larger in absolute terms.
The timing of that impact remains uncertain. Full financial settlement under CBAM will only begin to materialise from 2027, covering emissions embedded in 2026 exports. Until then, utilities operate in a transitional environment where market behaviour is already adjusting, but cost realisation remains partially deferred.
This lag is critical. It provides EPS with a limited window to recalibrate its generation mix and investment strategy before CBAM costs become fully cash-settled. It also introduces a degree of ambiguity into current financial reporting, as the true cost of carbon exposure is not yet fully reflected in earnings.
From an investor perspective, this places EPS in a distinct category. Unlike EPCG, where CBAM is already visible in quarterly performance, Serbia’s utility represents a forward-loaded risk profile, with material implications for medium-term profitability and valuation.
At the system level, the implications extend further. Serbia’s position as a regional electricity exporter has historically been underpinned by low-cost lignite generation. CBAM effectively dismantles that advantage by internalising the carbon externality, forcing a repricing of the entire model.
What emerges is a transition not only in generation technology, but in market role. Serbia is moving from a cost-advantaged exporter toward a system where competitiveness is contingent on carbon efficiency, grid flexibility and integration with EU market structures.
The early €13 million loss recorded in Montenegro provides a tangible benchmark of what this transition looks like in practice. For EPS, the equivalent figure has yet to appear on the balance sheet. But the underlying dynamics suggest that, when it does, it will reflect a much broader realignment—one that extends from power generation into the core of Serbia’s export economy.
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