Montenegro’s electricity link to Italy provides physical access to an EU market for renewable developers, but Carbon Border Adjustment Mechanism (CBAM) costs can affect whether cross-border sales remain profitable. Developers are increasingly expected to review contractual structures and supporting evidence before relying on Italian offtake agreements as export revenue. The value of the undersea connection depends on how imported electricity is treated under CBAM, not only on price differences between Montenegro and Italy.
The Energy Community Secretariat reported an average electricity price spread of approximately €43/MWh between Montenegro and southern Italy in a first-quarter 2026 market illustration. In the same comparison, an indicative CBAM carbon cost was calculated at €73.78/MWh, using the relevant reference price and Montenegro’s applicable default emissions factor at the time. The indicative carbon cost exceeded the wholesale price spread in that illustration.
The Secretariat’s figures were tied to the reporting period and specific assumptions used in the comparison. They were described as not a forecast for every future trading hour. The comparison also did not establish actual emissions for any individual generating installation.
Carbon costs versus wholesale spreads in CBAM calculations
The comparison highlighted that day-ahead market arbitrage may not be sufficient to generate export margins when carbon costs rise above the wholesale advantage. It also indicated that the relationship between spreads and CBAM-related costs depends on the inputs used in the calculation. The reported outcome was specific to the assumptions applied for that period.
For project developers, this creates a need to assess how CBAM treatment would apply to exported volumes rather than relying solely on market price differentials. The source material frames this as a shift toward evaluating contractual arrangements and documentary support before treating Italian offtake as dependable export income. The undersea interconnector’s physical access is presented as necessary but not determinative for CBAM-related outcomes.
Default emissions factors and eligibility based on actual emissions
For EPCG and independent Montenegro hydropower, wind and solar developers, the difference between default emissions treatment and eligibility based on actual emissions can affect project economics. A low-carbon generating installation could have an advantage over the national default emissions factor if it meets applicable requirements. Securing that treatment requires documentation connecting the generating plant, contracts, deliveries, and the importing entity.
The evidence chain described includes a qualifying power purchase agreement (PPA) with the correct EU declarant, plant-specific emissions and metering records, physical-network evidence, firm hourly nominations, and independent verification. The source also notes that a direct physical PPA with the Italian importing entity is a straightforward contractual starting point. It adds that a regional trader could separately provide dispatch and balancing services.
Where an intermediary must participate in the commodity agreement, a qualifying single tripartite contract may be considered. The source material also states that 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. This is presented as relevant to maintaining eligibility rather than changing eligibility criteria itself.
CGES–Terna interface requirements for delivery documentation
The operational evidence chain runs through the CGES–Terna transmission interface. Export schedules must be reconciled with the generating installation’s dispatch records and with documentation held by the Italian importer. Developers are also expected to determine whether physical-network conditions along the transmission route are satisfied.
The existence of the undersea cable alone is described as insufficient to demonstrate compliance with every applicable criterion. Metering at a substation is also stated to be insufficient by itself for establishing final quantities imported and attributable to a particular PPA. The evidence must link plant-recorded output with nominated and delivered volumes claimed under the relevant contractual arrangement.
Portfolio qualification challenges under Montenegro’s generation mix
Montenegro’s electricity mix introduces additional challenges when exporters market power from broader portfolios into Italy. Hydropower generation varies with rainfall and reservoir conditions, while thermal generation and electricity purchases also contribute to the national balance. As a result, high hydropower output in a given month does not automatically qualify an unspecified EPCG portfolio sale as electricity from a particular low-carbon installation.
The source material says supporting records must identify individual plants and allocate eligible volumes without double counting. It also highlights that this distinction becomes important when suppliers combine generation from multiple sources or use market purchases to meet contractual delivery obligations. Volumes eligible for actual-emissions treatment must be supported by plant-specific evidence within this allocation approach.
Financing scenarios for wind and solar exports into Italy
For wind and solar developers, potential carbon benefits from an Italian export PPA can influence investment decisions and financing assumptions. The source material notes that this anticipated benefit may be reduced if intermediary contracts, hourly nominations, or documentation procedures cannot substantiate projected eligible electricity volumes. This affects how developers model expected revenues tied to CBAM-related treatment.
Lenders are described as assessing 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 along with different collateral requirements and operating costs. Treating full renewable output as eligible for a CBAM-related premium before establishing the evidence chain is described as potentially overstating expected export revenues.
Status of proposed EU changes as of October 2026
The source material states that proposed EU reforms could eventually facilitate qualifying electricity trade by changing elements of electricity methodology and intermediary treatment. However, it specifies that as of October 2026 those proposals had not become law. Until rule changes occur, it describes clearly documented volumes linked to specific generating plants as the most defensible export opportunity for Montenegrin renewable developers.
The commercial value of the Montenegro–Italy interconnector is therefore presented as depending not only on market prices and physical transmission access but also on whether individual transactions meet contractual, operational, and verification requirements for claimed CBAM treatment.