Montenegro’s electricity connection to Italy, designed to capitalize on lower energy costs in the Western Balkans for sales into the higher-priced Italian market, faces new challenges due to the EU’s Carbon Border Adjustment Mechanism (CBAM). This mechanism introduces an emissions cost that can exceed the price differential between the two markets.
In the second quarter of 2026, the carbon factor for electricity imported from Montenegro was recorded at 0.979 tonnes of CO₂ equivalent per MWh. Given that CBAM certificates averaged €75.28 per tonne, this results in an implied carbon adjustment of approximately €73.70/MWh.
The average price of electricity in Italy was only about €27/MWh higher than in Montenegro during this period. Consequently, importers utilizing Montenegro’s default value faced a carbon cost nearly three times larger than the price advantage across the border.
Despite these challenges, exports from Montenegro to Italy saw a recovery of around 19% year-on-year in the second quarter. This increase suggests that traders are weighing factors beyond immediate price spreads, such as contract structures and potential regulatory changes, along with considerations regarding actual emissions.
The complexity of Montenegro’s energy generation mix exacerbates this situation. While hydropower and wind offer low operational emissions, reliance on the Pljevlja lignite-fired power plant remains significant. In the second quarter, Montenegro generated about 0.52 TWh, marking an 89% increase from a low base, primarily driven by Pljevlja’s operations after a previous shutdown.
The CBAM methodology does not favor renewable generators solely based on their zero direct emissions status. Importers must adhere to national default values unless they meet specific conditions for using actual emissions.
This requirement positions traceability as a critical commercial asset for renewable producers. Projects aiming for access to EU buyers must establish an auditable chain linking generation facilities, metered production, contractual delivery, cross-border nominations, and importing declarations.
A guarantee of origin alone is inadequate under CBAM; it necessitates a robust connection between generated and imported electricity. This includes physical power-purchase agreements and verified emissions documentation, which enhance the transaction’s credibility.
This distinction creates a difference between standard renewable electricity and that which qualifies under CBAM regulations. Generators with comprehensive evidence chains may achieve higher netbacks since EU importers can mitigate or avoid default carbon charges.
This issue is particularly pertinent for entities like EPCG, future private renewable developers, traders utilizing the Italian route, and industrial buyers looking for renewable energy with defensible emissions claims. The value proposition now hinges not just on volume but also on data integrity and contractual quality.
Regulatory uncertainty persists as EU institutions contemplate amendments to electricity methodologies. Proposed changes include calculating national default factors based on the entire electricity mix rather than just fossil fuels and possibly relaxing conditions for actual emissions usage.
If these amendments take effect retroactively from 1 January 2026, they could result in a lower default factor for Montenegro due to its significant hydropower and wind contributions. However, coal reliance would still expose it to carbon pricing risks.
Traders must account for dual regulatory scenarios: under current conditions, an implied cost nearing €74/MWh could limit conventional export opportunities; under revised factors or accepted actual emissions pathways, renewable electricity could maintain access to premium prices in Italy.
This uncertainty impacts power purchase agreements (PPAs) and project financing. Developers cannot assume that wholesale prices automatically translate into revenues; contracts must clarify responsibilities regarding CBAM costs and emissions data verification.
The same considerations apply when balancing replacement electricity needs. If a renewable producer falls short of forecasts and procures market power to settle imbalances, tracing these volumes back to qualified installations becomes crucial for consistent treatment alongside contracted renewable outputs.
The European Bank for Reconstruction and Development (EBRD) has identified CBAM exposure and alignment with the EU Emissions Trading System as key priorities in its strategy for Montenegro. Market coupling could enhance price formation and cross-border efficiency but will not resolve carbon-accounting issues without further alignment of Montenegro’s carbon-pricing framework.
The dynamics of the Italy cable are thus shifting from simple geographical arbitrage towards more complex carbon-adjusted trading arrangements. Its future effectiveness will hinge on various factors including wholesale price spreads, EU ETS pricing, national default factors, hydrological conditions, Pljevlja’s output levels, and renewable generators’ ability to substantiate their actual emissions.
If Montenegro can successfully differentiate verified renewable exports from its overall carbon intensity, it stands to gain significantly from this cable as a premium channel for clean electricity. Conversely, if it fails to do so, ongoing default charges approaching €74/MWh will likely transfer much of the pricing advantage back to EU carbon mechanisms rather than local exporters.
