For Serbia, the CBAM story in electricity is no longer theoretical. Since 1 January 2026, electricity imported into the EU from non-EU countries has been subject to CBAM’s administrative and financial regime. In 2026, the CBAM certificate price is calculated as a quarterly average of EU ETS auction prices, with a shift to weekly pricing from 2027. That matters because Serbian power sold into the EU is now exposed to a carbon-cost overlay that did not previously sit directly on cross-border trade.
Serbia is the most exposed electricity exporter in the Western Balkans under this framework. The Energy Community’s 2025 CBAM Readiness Tracker, using 2024 scheduled commercial exchanges, estimates that electricity flows sourced via Serbia into the EU amounted to 9,181,098 MWh, with an average annual marginal CBAM cost of €66.71/MWh and total annual CBAM exposure for EU importers of €612.5 million. The same report states plainly that Serbia has the largest scheduled volume toward the EU and therefore the highest CBAM exposure among the Contracting Parties covered.
That cost level is large enough to rewrite export economics. In a regional market where annual average day-ahead prices across the Energy Community stayed close to €100/MWh in 2024, a CBAM burden of roughly €66.71/MWh is not a marginal adjustment. It can erase most of the historical gross spread that made Serbian exports commercially attractive in normal market conditions. Put differently, coal-linked Serbian baseload power may still move west in scarcity hours, but it is much less competitive as a routine export product once carbon is priced at the border.
The reason Serbia is so exposed is structural. Its power system is still heavily shaped by lignite, and the transition is incomplete. Serbia’s Just Transition Plan states that the country is not part of the EU ETSand does not yet have an established greenhouse-gas emissions trading or taxation system, while the same document notes that CBAM’s financial phase starts from 1 January 2026 and that domestic carbon pricing is being considered as one mitigation route. At the same time, the Energy Community tracker records the commissioning of the 350 MW Kostolac B3 lignite unit at the end of 2024, bringing Serbia’s total lignite-based capacity to more than 4.3 GW.
That does not mean Serbia’s system is standing still. The same Energy Community material shows a broader regional decline in coal’s role and growth in renewables, and Serbia’s own policy documents point to a much more renewable-heavy system over time. But the immediate commercial problem is not the long-run direction of travel. It is the mismatch between today’s export carbon intensity and today’s border pricing. Until Serbia either lowers the effective emissions intensity of exportable power, introduces a recognized domestic carbon-pricing framework, or reaches the conditions for exemption through market integration, Serbian electricity exports into the EU will trade under a structural handicap.
This is already changing trader behavior. The old model of regional power trading—buying Serbia on nominal price advantage and selling into neighboring EU markets when spreads opened—is giving way to carbon-adjusted arbitrage. Traders now have to think not only about border spreads, congestion and hydrology, but about embedded emissions, documentation, compliance handling and the likelihood that the effective CBAM charge destroys the economics of the position. In practice, that means shorter tenor, more hour-selective trading, and lower appetite for generic Serbian baseload exports into the EU unless the hour is genuinely tight or the source mix is demonstrably cleaner. That inference follows directly from the CBAM pricing methodology and Serbia’s quantified exposure.
The market structure inside Serbia is evolving at exactly the same time. SEEPEX will introduce negative prices from 5 May 2026, with the day-ahead floor shifting to -€500/MWh and the intraday floor to -€9,999/MWh. This is an important market-development step because it makes Serbian power trading more similar to mature EU exchanges, where value increasingly depends on timing, balancing and flexibility rather than on flat generation alone. For Serbian traders and generators, this means the domestic and regional playbook is becoming more complex at the same moment that CBAM is making EU export flows more expensive.
That combination points to a clear shift in commercial patterns through 2026–2027. First, Serbian coal-heavy baseload exports to the EU are likely to lose share except during high-price scarcity periods. Second, intraday and short-term optimization should become more important as traders try to place lower-carbon or better-timed volumes instead of running broad baseload books. Third, domestic price formation may become more volatile: if some exportable volumes are pushed back into the Serbian or wider regional market because CBAM makes EU off-take uneconomic, local oversupplied hours could become weaker, while flexible assets, hydro, storage and balancing positions gain relative value. The introduction of negative prices on SEEPEX reinforces exactly this kind of volatility-driven market.
For EPS and for Serbian-origin generation portfolios more broadly, the implication is that the export stack is being repriced by quality, not only by quantity. A megawatt-hour is no longer just a megawatt-hour once it crosses into the EU. Traders will increasingly separate volumes by likely carbon burden, delivery profile and documentation confidence. In commercial terms, Serbian hydro, renewable-backed supply and flexibility-linked structures gain strategic importance, while undifferentiated lignite-linked exports lose value. Even before Serbia fully decarbonizes, portfolio optimization will start shifting toward ring-fenced green supply, storage pairing, and more selective export scheduling. This is an inference from the CBAM regime and current Serbian market reforms, but it is the most plausible one.
The exemption pathway exists, but it is not immediate. Serbia’s Just Transition Plan states that exemption from CBAM for electricity can come either through participation in the EU ETS or a linked ETS, or through an electricity market integrated with the EU internal market via market coupling, combined with timely acquis transposition, a 2050 climate-neutrality commitment, and a commitment to implement an electricity emissions trading scheme with a price equivalent to the EU ETS by 1 January 2030. Separately, recent regional market commentary says the first Western Balkan–EU electricity market coupling is expected only in early 2028 or the beginning of 2029, not in 2026. That timing implies Serbia must operate with CBAM as a real commercial constraint for at least the next several years.
The forecast from here is relatively clear. In the base case for 2026–2027, Serbian electricity exports into the EU continue, but volumes become more episodic and more dependent on scarcity pricing, hydro conditions and short-term system tightness. Average realized export margins should compress materially for carbon-heavy flows, and traders should migrate toward shorter-dated, intraday and origin-conscious strategies. In this environment, Serbian power is less likely to function as a stable baseload export product and more likely to trade as a conditional, hour-specific product.
In the 2028–2030 upside case, Serbia moves closer to EU market coupling, scales renewables, improves guarantees-of-origin and carbon-accounting credibility, and begins implementing a domestic electricity carbon-pricing path. In that scenario, the export mix gradually shifts away from lignite-dominant economics toward flexibility, hydro, solar-wind shaping and cross-border optimization. Export volumes to the EU could recover in quality even if not in the same legacy form, because the value would come from cleaner and more flexible megawatt-hours rather than from simple coal-based price arbitrage. Serbia’s own transition documents point in that direction, but the calendar is tight.
In the downside case, Serbia delays carbon-pricing implementation, coupling slips beyond 2029, and lignite remains too dominant in the exportable stack. Then CBAM will keep acting as a persistent tax on Serbian electricity sold into the EU, pushing traders further away from Serbian-origin baseload and reducing exports to occasional tight-market windows. Under that scenario, domestic and regional oversupply risk in certain hours rises, captured prices weaken, and the market premium shifts even more decisively toward hydro flexibility, batteries and cleaner contracted supply.
The commercial conclusion is that CBAM is not simply raising Serbia’s export cost. It is changing the very type of Serbian electricity that remains bankable in the EU market. The winning Serbian export product over the next few years is unlikely to be generic lignite-backed baseload. It is more likely to be selectively timed, lower-carbon, better-documented power, increasingly supported by renewables, hydro flexibility and more sophisticated trading on SEEPEX and across neighboring borders.
Elevated by cbam.engineer
