CBAM pressure starts to show in the Western Balkans, putting EPS’s lignite model under scrutiny

Carbon pricing under the EU’s Carbon Border Adjustment Mechanism (CBAM) is moving from theory to cash implications across the Western Balkans, highlighting how differences in power-system design can change the timing and scale of losses. For investors, the early signals matter because they point to a shift in how electricity—and the carbon embedded in exported goods—will be priced into regional competitiveness.

Montenegro sees immediate CBAM losses; Serbia’s exposure is deferred

Montenegro’s Elektroprivreda Crne Gore (EPCG) has already recorded a €13 million loss in the first quarter of 2026. Serbia’s Elektroprivreda Srbije (EPS), by contrast, is confronting a more complex pattern: CBAM-related costs are largely delayed for now, but they are larger in magnitude because of how Serbia’s generation mix links to exports.

The divergence is driven less by policy timing than by system architecture. Montenegro’s smaller, more export-oriented power system has translated CBAM into immediate financial losses. Serbia’s electricity sector is more domestically absorbed, with exports typically around 10% of total production—an insulation that helps explain why EPS has not yet shown the same near-term cash outflows.

Lignite intensity turns carbon cost into an export competitiveness problem

Serbia’s vulnerability sits at the core of 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 places Serbia among Europe’s most emission-intensive electricity producers—an attribute that CBAM mechanics convert directly into cost when electricity is exported into EU markets.

Analysts estimate that exporting Serbian electricity into EU markets could incur an additional €50–60 per MWh in carbon-related costs. That matters because wholesale prices over the past year have averaged near €90–110 per MWh. The implied differential risks pushing Serbian supply out of the EU merit order during most trading intervals, turning profitability concerns into a gradual erosion of market access.

Latent losses and wider industrial spillovers

The story for Serbia is not only about what shows up on quarterly results today; it is also about what remains embedded for later settlement. While Montenegro has already realised losses that reflect both direct and indirect CBAM effects—including weaker export pricing and altered trading strategies—Serbia appears to be accumulating “latent losses”: costs not yet fully reflected in financial statements but likely to surface through future trading constraints and industrial pricing structures.

Estimates suggest CBAM-related exposure for Serbia’s electricity exports could reach approximately €200 million annually. When indirect effects are included, the broader economic impact could extend beyond €250 million per year.

Those indirect effects stem from CBAM’s coverage beyond cross-border electricity flows. It also captures carbon intensity embedded in exported industrial goods. In Serbia, sectors such as steel, non-ferrous metals and chemicals are closely tied to electricity consumption, meaning EPS’s emissions profile can become a system-wide pricing factor for export competitiveness.

Shifting exports can help short term—but tightens revenue upside

To manage near-term exposure, EPS can pivot exports toward non-EU markets within the Western Balkans, effectively bypassing CBAM in the short term. However, this approach has structural limits: regional markets are smaller, less liquid and typically priced at discounts to EU benchmarks. Over time, repositioning could transform EPS from a marginal EU exporter into more of a regional balancing utility—reducing exposure to coupled European price spikes while also narrowing revenue upside.

This trade-off arrives as capital requirements rise. EPS has 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. The projects are increasingly framed not just as part of a green transition narrative but as measures tied to preserving market access under CBAM.

A narrowing window before full cash settlement begins

The economics hinge on emissions intensity: each incremental megawatt of low-carbon generation reduces average system emissions intensity and lowers the effective CBAM burden. Delays compound future costs because carbon price differentials between Serbia and the EU remain wide—currently estimated at €50–60 per tonne of CO₂.

The timing of when these pressures fully hit financials remains uncertain because 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 adjusts earlier than costs are fully cash-settled—creating ambiguity in current reporting while providing EPS with a limited window to recalibrate its generation mix and investment strategy.

Investor implications: forward-loaded risk compared with EPCG

From an investor perspective, this makes EPS stand out versus EPCG. Montenegro already shows visible quarterly performance impacts from CBAM exposure; Serbia represents a forward-loaded risk profile where material implications for medium-term profitability and valuation may emerge later as settlement catches up with earlier market adjustments.

At the system level, CBAM effectively dismantles Serbia’s historical advantage as a low-cost lignite-based exporter by internalising carbon externalities across both power generation and export-linked industrial activity. The result is not only a technology transition—from coal toward lower-carbon supply—but also a change in market role: Serbia moves toward competitiveness defined by carbon efficiency, grid flexibility and integration with EU market structures rather than by cost alone.