Montenegro’s direct electricity link to Italy is carried via a high-voltage direct-current interconnector operated through the transmission-system arrangements of CGES and Italy’s Terna. Terna lists the connection at 445 kilometres in length and 600 MW capacity in its end-2025 geographical overview. The link is relevant for Montenegro’s electricity system, which includes hydropower, wind and coal-fired generation. Technical capacity does not ensure that commercial transmission capacity will be available in every hour.
Electricity imported into the EU falls under the Carbon Border Adjustment Mechanism (CBAM) unless a legal exception applies. The European Commission published a Q3 2026 CBAM certificate price of €82.32 per tonne of CO₂ equivalent. For electricity, liability depends on official default emissions expressed in tonnes of CO₂ equivalent per megawatt-hour or on verified actual emissions under narrowly defined conditions.
Evidence needed for CBAM-qualified electricity from non-EU generation
An exporter claiming that electricity originated from a Montenegrin wind farm must provide documentation including the required power purchase agreement (PPA), grid and transmission evidence, and hourly matching and verification. The generation technology alone is not sufficient for CBAM purposes. The contractual chain used for electricity delivery also needs to align with the carbon-accounting route applied under CBAM.
A wind or solar project can sell electricity to a domestic buyer, a regional trading company or a retailer that subsequently delivers power towards Italy. While such arrangements can be commercially viable under ordinary electricity-market rules, CBAM provisions for actual emissions add further requirements. These include a qualifying contractual relationship between the EU authorised declarant and an identified non-EU generator.
The additional evidence requirements also cover cross-border capacity nominations. Accepted nominations must correspond to electricity generation over intervals of no longer than one hour. The European Commission’s COM(2025)989 proposal would allow certain intermediary PPA arrangements where the contractual chain can be verified and would revise other elements of the electricity methodology. The proposal has not been adopted.
Business plans assuming that all sleeved or exchange-traded electricity can receive actual-emissions treatment in 2026 face regulatory and financial uncertainty. This affects how developers and traders assess whether exported megawatt-hours can qualify for lower carbon-accounting treatment under EU law. It also affects how those exports translate into revenue under power-market conditions.
Generation mix, dispatch conditions and interconnector constraints
Montenegro’s generation portfolio influences both export opportunities and operational risks tied to delivering power towards Italy. Additional wind and solar capacity could increase the volume of potentially low-emission electricity available for export. Hydropower output depends on rainfall and reservoir conditions, meaning drought can alter domestic dispatch patterns.
Drought can change the balance between exports and imports, while transmission constraints, day-ahead price differentials, balancing exposure and interconnector outages influence export earnings. The direction of flows also matters for commercial value because Montenegro may export when regional renewable output is strong and Italian prices support deliveries. Conversely, Montenegro may need to import when hydropower reservoirs are depleted or domestic thermal units are unavailable.
CBAM treatment for electricity entering the EU affects the economics of exports from Montenegro to Italy. It should not automatically be applied in the same way to electricity flowing in the opposite direction from Italy into Montenegro. A project model should therefore use separate seasonal and hourly import-export scenarios, including line maintenance and restrictions on allocated capacity.
Illustrative CBAM cost exposure for hourly emissions assumptions
An illustrative export tranche of 50,000 MWh assigned chargeable emissions of 0.4 tCO₂e/MWh would correspond to 20,000 tonnes of CO₂ equivalent. At a Q3 2026 certificate price of €82.32 per tonne, gross certificate exposure would total €1.646 million, before any legally applicable adjustments. The calculation is an illustration rather than an official emissions factor for Montenegro.
The example does not establish liability for any specific transaction. It is intended to show how reliance on a relatively narrow Italian market-price premium could become uneconomic if an importer must apply high default emissions values instead of verified actual emissions.
For lenders assessing new Montenegrin renewable projects, financial models should separate ordinary domestic and regional electricity sales from exports represented as CBAM-qualified. Relevant materials include the acquiring trader, authorised EU declarant, PPA provisions, metering systems, TSO nomination files, settlement adjustments and independent verifier data requirements.
A project may remain bankable on conventional electricity-market revenues even if additional CBAM benefits are too uncertain to support financing decisions. Carbon-market reform also does not guarantee eligibility for CBAM-qualified electricity exports under actual-emissions treatment rules.
Carbon market changes versus interconnector access requirements
The EU agreement on Oct. 20 increases the market stability reserve’s allowance invalidation threshold to 700 million. This could influence longer-term carbon-price scenarios but does not change Montenegro’s interconnector capacity or automatically make exported electricity eligible for actual-emissions treatment.
Carbon prices, electricity-market spreads and the technical evidence required for CBAM claims must be modelled as separate risk factors in project assessments. Interconnector value also depends on flow direction because export economics differ from import economics under varying generation availability and market conditions.
Ownership of generation does not guarantee access to transmission capacity across the interconnector route. Project developers need to distinguish their contractual rights from those held by electricity traders and transmission-system operators. Owning a wind farm in Montenegro does not provide unrestricted access to interconnector capacity.
Physical scheduling, transmission-capacity procurement and customs-related declarations may involve multiple independent entities. Before lenders recognise an assumed CBAM benefit in valuation, they are expected to examine executed agreements and the operational process used to collect and reconcile evidence supporting claims.
A premium dependent on potential regulatory reform is described as less bankable than one supported by a documented and tested export chain operating under rules already in force. For Montenegro, developing an export product requires linking electricity to an identified generating installation, establishing a credible physical and contractual delivery route, and producing an audit-ready allocation for every claimed megawatt-hour.
The underwater interconnector provides access to Italy at 600 MW, while whether that access supports sustained low-carbon trading advantages depends on the quality of the contractual structure and verification chain used for CBAM-related claims.