CBAM starts to bite into EPCG’s export model as Montenegro utility posts €13m Q1 loss

Montenegro’s state-owned utility EPCG has entered a new financial reality in 2026, as the EU’s Carbon Border Adjustment Mechanism (CBAM) begins to reshape how electricity exporters price their output. In the first quarter alone, CBAM translated into direct and indirect revenue losses of €13 million—an early signal of how carbon-cost equalisation is moving from policy design into balance-sheet strain.

€13 million loss points to structural export pressure

The figure covers January through March 2026 and is being treated as one of the first concrete financial indicators for Western Balkan electricity exporters. The exposure is particularly relevant for producers still reliant on coal-based generation, where emissions intensity makes competitiveness more sensitive to EU-linked carbon pricing.

CBAM is designed as a carbon cost equalisation mechanism: it imposes a CO₂-linked levy on imported electricity into the EU, penalising generation sources with higher emissions intensity. For Montenegro—where roughly 40–45% of electricity output comes from the coal-fired TPP Pljevlja—the risk is not cyclical but embedded in the generation mix.

Not just a levy: CBAM compresses regional prices

EPCG’s management says the immediate impact extends beyond explicit payments. The company highlights a transmission channel through which CBAM reduces export prices and erodes competitiveness across regional markets. Coal-generated electricity, it argues, is being forced into discounted sales levels as buyers adjust to expectations of future carbon costs—even when CBAM is not directly invoiced.

This price distortion is visible in regional spreads. Electricity prices in Western Balkan markets are trading €20–70 per megawatt-hour below EU levels, reflecting CBAM-adjusted expectations and buyer reluctance to absorb future carbon costs. For exporters like EPCG, that translates into a structural margin squeeze rather than a one-off cost item.

Sales shift toward non-EU markets, but strategy fragments

To manage exposure, EPCG has redirected sales toward regional (non-EU) markets where possible and has limited EU exports to surplus volumes when necessary. The company describes this as a change that fragments market strategy—prioritising volume stability over price optimisation.

Cost structure mismatch widens the gap

A key issue for investors is alignment between domestic and EU carbon pricing. Montenegro’s domestic carbon pricing remains at approximately €24 per tonne of CO₂, while EU ETS benchmarks fluctuate between €70 and €80 per tonne. That gap removes any competitive buffer when exporting into the EU, leaving producers to absorb most of the carbon differential without transitional relief mechanisms.

Quarterly results may understate annual pressure

EPCG estimates that annual CBAM-related costs could reach up to €191 million under current parameters. Given that electricity accounts for more than 35% of Montenegro’s total exports, such an increase would materially affect the country’s external balance.

The first-quarter loss also comes despite supportive operating conditions: hydrology was favourable and generation rose to approximately 1,204 GWh in Q1—nearly 40% higher year-on-year. Even with increased output, EPCG recorded losses linked to CBAM pressures, underscoring that the problem is driven by pricing and cost structure rather than demand weakness alone.

Methodology uncertainty delays full settlement visibility

Regulatory uncertainty adds another layer of risk. The final CBAM calculation methodology for 2026 remains under refinement, and EPCG expects first actual financial settlements in 2027, retroactively covering 2026 exports. That means trading decisions during 2026 are being made without full visibility on final cost exposure.

No pass-through for now—tariff changes remain possible

EPCG says it has avoided passing these costs directly onto domestic consumers for now and explicitly states that electricity price increases are not currently under consideration. However, it does not rule out tariff adjustments if external shocks intensify—particularly if energy markets tighten due to geopolitical developments.

A transition test for coal-based baseload economics

The broader tension is increasingly clear: Montenegro’s legacy baseload anchored in coal provides stability but carries escalating carbon liabilities as European market rules increasingly price emissions at levels that undermine its economics. The €13 million Q1 loss does not yet capture the full magnitude of that transition; instead, it appears to mark an opening phase of realignment that will determine whether EPCG can maintain export relevance or whether Montenegro’s power sector must accelerate its shift toward renewables and EU-aligned carbon pricing to preserve competitiveness.