Montenegro’s electricity exports to Italy face a growing carbon-cost calculation as domestic emissions payments and the EU’s carbon-border rules affect the economics of cross-border power trading. State utility Elektroprivreda Crne Gore (EPCG) has indicated a domestic carbon payment of approximately EUR 75 per tonne of CO₂, while electricity imported into the EU through the Adriatic interconnector remains subject to CBAM unless an exemption or more favourable emissions calculation applies.
The interconnector provides access to Italy’s larger electricity market, but a higher destination price does not necessarily translate into a profitable export. Carbon exposure, transmission charges and balancing costs all influence the final trading margin.
Coal generation shapes Montenegro’s electricity emissions profile
Montenegro’s power system combines hydropower, an expanding renewable portfolio and the coal-fired Pljevlja power plant. This generation mix supports domestic supply, but creates a more complex emissions profile for electricity traded internationally.
The Energy Community’s 2026 analysis identified a Montenegro electricity default emissions factor of 0.979 tonnes of CO₂ equivalent per megawatt-hour. Applying that factor to the EU’s third-quarter 2026 CBAM certificate price of EUR 82.32 per tonne produces an illustrative gross carbon reference of approximately EUR 80.59/MWh.
This figure relates to the specified quarterly price and assumed default factor. It should not be interpreted as a fixed charge applying to every future electricity shipment from Montenegro.
Carbon exposure changes the economics of Adriatic power trading
The potential carbon cost is large enough to alter the profitability of electricity trades between Montenegro and Italy. Traders comparing day-ahead prices must account for interconnector capacity rights, transmission losses, imbalance costs and any applicable CBAM liability.
Cross-border schedules may also include electricity originating outside Montenegro. Assuming that all power exported through the interconnector has the same generation origin can therefore produce an inaccurate emissions assessment.
A wholesale price spread that initially appears profitable may narrow considerably once carbon costs are included. The final result depends on the delivery hour, contractual arrangements and emissions calculation, although some trading periods and structures may remain commercially viable.
Domestic carbon payments and CBAM deductions require separate assessment
EPCG’s indicated EUR 75/tCO₂ payment, following an earlier lower minimum, would increase the cost of coal-fired generation while directing revenue towards domestic environmental purposes.
However, whether the payment can reduce an EU CBAM obligation depends on the relevant emissions base, evidence of the payment, applicable national relief and the EU rules governing deductions for carbon prices paid abroad.
A payment made by a utility does not automatically qualify as a credit for every trader exporting electricity from Montenegro. The relevant records must establish the connection between the payment and the emissions covered by the transaction.
Contracts and capacity rights determine who carries carbon risk
The allocation of cross-border capacity rights and contractual responsibilities is becoming increasingly important. A generator selling electricity at the Montenegrin border may transfer the EU-side compliance obligation to a trader. By contrast, a long-term power purchase agreement designed to support actual-emissions treatment may require a closer connection between the generating plant and the authorised EU declarant.
For banks financing wind projects, the power purchase agreement, nomination arrangements, curtailment provisions and emissions-verification budget need to be assessed together. A bankable trading margin cannot be established by comparing national average electricity prices alone.
Hourly Italian price premiums may offer attractive opportunities, but they must be evaluated against the actual delivery route and the relevant CBAM reference period. This is particularly important when a trader relies on a default emissions factor that may differ significantly from the generating plant’s own emissions profile.
Renewable electricity requires traceable physical evidence
For Montenegro’s renewable generators, the commercial value of low actual emissions depends on whether the electricity can qualify for actual-emissions treatment under the applicable CBAM requirements.
Hydropower and wind facilities may have favourable plant-level emissions performance, but the EU declarant must still satisfy the electricity-specific conditions. These include the eligible generating installation, a qualifying physical power purchase agreement, hourly matching of production and nominated capacity, transmission arrangements and accredited verification.
A guarantee of origin or financial power purchase agreement may serve other commercial purposes, but neither can automatically replace the prescribed physical evidence required for CBAM treatment.
ETS reform and investment decisions add uncertainty
Montenegro’s revised ETS framework and its EU accession trajectory introduce further uncertainty for medium-term investment and trading decisions.
If domestic carbon costs increase towards EU market levels while the country expands renewable generation, coal-fired electricity could lose part of its cost advantage. That would potentially change the generation mix and the economics of cross-border exports.
Financing decisions for new wind and solar capacity therefore need to include a route-to-market assessment covering both electricity trading arrangements and CBAM evidence requirements. Project economics based solely on expected Italian wholesale price premiums may not capture the full cost of exporting power.
The Montenegro–Italy interconnector remains a strategic link to the EU electricity market. Its commercial value will increasingly depend on the emissions profile and contractual traceability of the electricity moving through it, as well as the ability of exporters and importers to establish a defensible carbon cost for each transaction.
