CBAM electricity risk tied to power market integration
Serbia could avoid paying CBAM on electricity shipments into the EU if the ongoing process of market integration with Hungary and Bulgaria is finished by the end of 2026. The mechanism is designed to align carbon costs across borders, but the practical outcome for exporters depends on how quickly regulatory conditions are met. If integration is not completed, CBAM-related impacts would begin affecting Elektroprivreda Srbije starting next year, while other covered sectors would have a longer adaptation runway between 2026 and 2034, with full pricing applied only in 2034.
This creates a compliance sequencing issue for Serbian power stakeholders: electricity is singled out for earlier operational consequences, even as other industrial categories move through later phases. For importers and traders, it also raises the need for tighter documentation and carbon cost forecasting around the timing of market arrangements.
Lignite intensity drives higher carbon charges per megawatt-hour
The central driver of Serbia’s CBAM exposure in electricity is the carbon profile of its generation mix. Serbian electricity production relies heavily on lignite, producing a carbon footprint estimated at three to four times higher than the EU average. No other CBAM-covered sector is described as showing such a large emissions disparity relative to EU benchmarks.
In cost terms, exporting one megawatt-hour of Serbian electricity to the EU would incur an additional €60 attributable to high carbon emissions. With EPS’s current average export price slightly above €100 per megawatt-hour, that added levy would be large enough to undermine competitiveness and complicate commercial operations.
EU conditions for avoiding payments—and their scale
The EU has established conditions under which Serbia could avoid CBAM payments for electricity, but meeting them comes with additional constraints. Completing market integration with Hungary and Bulgaria by 2026 is presented as essential for avoiding CBAM-related payments on electricity exports.
Even if technical pathways exist beyond that deadline, the post-2030 cost picture for EPS under EU carbon pricing rules could be severe. The source scenario places potential annual costs at approximately €3 billion if EPS were treated under EU carbon pricing rules, potentially doubling electricity prices for households and weakening domestic competitiveness. By comparison, CBAM exposure is estimated at €200–300 million per year, making it comparatively lower than the alternative described.
Emissions performance gap shapes relative burdens
Serbia’s disadvantage is linked to long-running energy and climate policy gaps that have left emissions reductions behind EU progress. Although CBAM applies equally to market participants in principle, Serbian products face higher relative burdens because production remains more carbon intensive than EU averages.
Between 2010 and 2023, central and eastern European countries reduced emissions by about 20%, while Serbia achieved only a 3–4% reduction. That divergence matters because CBAM calculations for electricity are tied to national average emissions rather than individual plant performance in the described approach.
How CBAM electricity charges are calculated
For electricity, CBAM charges are calculated using Serbia’s average emissions over a five-year period from 2019 to 2023. The charges are then applied with a two-year lag, meaning compliance planning must account for both historical emission levels and timing effects in reporting.
The described method also implies that low-carbon producers within Serbia could still face high charges if national averages remain elevated. This creates an incentive misalignment risk: CBAM could inadvertently discourage investment in renewables because charges reflect system-level averages rather than actual emissions from individual generators.
Transition financing and domestic policy options
Limited support for modernizing Serbia’s electricity production is highlighted as another constraint compared with EU member states. Under the Modernisation Fund framework, countries with GDP per capita below 75% of the EU average can access funding intended to improve energy systems and reduce CO2 emissions; nearly €20 billion had been allocated by mid-2025 according to the source facts.
Several countries—including Poland, Romania, Hungary, Croatia, and Lithuania—are cited as having used Modernisation Fund resources to cut electricity-related CO2 emissions in recent years, while Serbia has fallen behind. In this context, fiscal policy is presented as a key lever: introducing domestic CO2 charges could steer investment toward cleaner technologies and more efficient energy use while keeping transition funds within Serbia’s budget rather than paying additional costs associated with imports into the EU.
Broader compliance implications across covered sectors
Starting in 2026, roughly two-thirds of Serbian exports are expected to face additional costs in the EU due to new climate regulations, rising to nearly 80% if Balkan markets connected through free trade agreements are included. While electricity faces earlier pressure tied to market integration timing, other covered sectors—cement, steel, aluminium, fertilisers, hydrogen—are described as having more time to adapt between 2026 and 2034 before full CBAM pricing applies in 2034.
For importers and exporters operating across these categories, the practical takeaway is that carbon cost pass-through will depend on both phase timing and how emission data feed into charge calculations. For EU producers already under the EU ETS and broader Green Deal policy architecture, these developments reinforce incentives around decarbonisation pathways that can withstand border-adjusted demand shifts—especially where national averages or reporting lags could amplify perceived carbon intensity.