Montenegro’s electricity connection with Italy offers renewable developers access to a major EU market, but Carbon Border Adjustment Mechanism (CBAM) costs can outweigh the wholesale price advantage that traditionally supported cross-border sales. Developers are increasingly required to assess contractual structures and supporting evidence before treating Italian offtake agreements as a dependable source of export revenue.
The undersea interconnector provides physical access to Italy, but the commercial value of that access depends increasingly on how imported electricity is treated under CBAM, rather than solely on the difference between Montenegrin and Italian power prices.
Carbon costs can exceed the wholesale price advantage
In a first-quarter 2026 market illustration, the Energy Community Secretariat reported an average electricity price spread of approximately €43/MWh between Montenegro and southern Italy. Its comparison calculated an indicative CBAM carbon cost of €73.78/MWh, using the relevant reference price and Montenegro’s applicable default emissions factor at the time.
The indicative carbon cost was therefore higher than the reported wholesale price spread, illustrating the limits of relying exclusively on day-ahead market arbitrage to generate export margins.
These figures relate to the reporting period and the assumptions used in that comparison. They are not a forecast for every future trading hour and do not establish the actual emissions of any individual generating installation.
Actual-emissions eligibility could change project economics
For EPCG and independent Montenegrin hydropower, wind and solar developers, the distinction between default emissions treatment and eligibility based on actual emissions can be commercially significant.
A low-carbon generating installation could have an advantage over the national default emissions factor if it satisfies the applicable requirements. Securing that treatment, however, requires a documented chain connecting the generating plant, contractual arrangements, electricity deliveries and importing entity.
The relevant evidence includes a qualifying power purchase agreement (PPA) involving the correct EU declarant, plant-specific emissions and metering records, applicable physical-network evidence, firm hourly nominations and independent verification.
A direct physical PPA with the Italian importing entity provides a straightforward contractual starting point. A regional trader could separately provide dispatch and balancing services. Where an intermediary needs to participate in the commodity agreement, the parties may also consider a qualifying single tripartite contract.
Developers should obtain legal advice before assuming that sequential resales through a Balkan trading company and an Italian counterparty will preserve eligibility for actual-emissions treatment.
CGES–Terna coordination is central to delivery evidence
The operational chain runs through the CGES–Terna transmission interface. Export schedules must be reconciled with the generating installation’s dispatch records and the Italian importer’s documentation.
Developers must also establish whether the relevant physical-network conditions are satisfied along the transmission route. The existence of the undersea cable alone does not demonstrate compliance with every applicable criterion.
Metering at a substation is likewise insufficient on its own to establish the final quantity imported and attributable to a particular PPA. The evidence must connect the plant’s recorded output with the nominated and delivered volumes claimed under the relevant contractual arrangement.
Montenegro’s generation mix complicates portfolio qualification
Montenegro’s electricity mix introduces additional challenges for exporters marketing power from a wider portfolio. Hydropower generation varies with rainfall and reservoir conditions, while thermal generation and electricity purchases also contribute to the national balance.
Consequently, a month with high hydropower output does not automatically qualify an unspecified EPCG portfolio sale as electricity from a particular low-carbon installation. Supporting records must identify individual plants and allocate eligible volumes without double counting.
This distinction is particularly important when a supplier combines generation from several sources or uses market purchases to fulfil contractual delivery obligations. The volumes eligible for actual-emissions treatment must be supported by the required plant-specific evidence.
Financing models must distinguish between export scenarios
For wind and solar developers, the potential carbon benefit of an Italian export PPA can influence investment decisions and financing assumptions. That anticipated benefit may be reduced if intermediary contracts, hourly nominations or documentation procedures cannot substantiate all the projected eligible electricity volumes.
Lenders should therefore assess three separate cases: a domestic merchant-sales scenario, an ordinary Italian electricity-import scenario incorporating applicable carbon costs, and a verified actual-emissions scenario.
Each case can produce different revenue margins and entail different collateral requirements and operating costs. Treating the full output of a renewable project as eligible for a CBAM-related premium before the evidence chain is established could overstate expected export revenues.
Proposed EU changes have not yet altered the current requirements
Proposed EU reforms could eventually facilitate qualifying electricity trade by changing elements of the electricity methodology and the treatment of intermediaries. However, as of October 2026, those proposals have not become law.
Until the rules change, the most defensible export opportunity for Montenegrin renewable developers is a clearly documented volume of electricity linked to specific generating plants, rather than an assumption that all renewable output will automatically receive favourable treatment when imported into Italy.
The commercial value of the Montenegro–Italy interconnector will therefore depend not only on market prices and physical transmission access, but also on whether individual transactions can satisfy the contractual, operational and verification requirements for the claimed CBAM treatment.
