Montenegro’s transmission grid is becoming one of the country’s most important investment assets as renewable-energy development accelerates. New wind and solar projects require sufficient connection capacity, but the network’s commercial value increasingly extends beyond electricity delivery to include curtailment management, balancing, cross-border trade and the evidence needed to support low-carbon electricity claims in the EU.
The government has indicated that Montenegro is moving from identifying its renewable potential towards a more intensive implementation phase. The first 54.6 MW phase of the Gvozd wind farm has entered operation, a further 21 MW phase is being advanced, and the 2026 Energy Balance projected installed solar capacity of approximately 215 MW if planned projects are delivered. Larger developments, including the 400 MW Montechevo solar project, would significantly increase the demands placed on the country’s transmission infrastructure.
Grid investment is increasingly following the expansion of generation capacity. In July, the French Development Agency (AFD) and Montenegro’s transmission system operator, CGES, signed a EUR 25 million sovereign-guaranteed loan to modernise the Perućica and Pljevlja 2 substations. The financing plan also includes a proposed EUR 8.5 million EU grant through the Western Balkans Investment Framework. The Energy Ministry has additionally highlighted progress on the Trans-Balkan corridor section towards Pljevlja.
These investments are generally presented as measures to strengthen security of supply and integrate new generation. For renewable-energy investors, however, they also have a direct impact on project economics. A stronger transmission network can reduce connection bottlenecks, improve reliability and increase the number of hours in which electricity can reach buyers. It can also improve the availability and quality of operational records needed for contracts, settlement and independent verification.
Under the EU’s Carbon Border Adjustment Mechanism (CBAM), the quality of transmission-related data has become particularly important. A capacity allocation or interconnector booking does not, by itself, prove that a named generating installation produced a particular quantity of electricity or that all requirements for actual-emissions treatment have been satisfied. Traders need accepted nominations, route identifiers and, under the current rules, evidence relevant to the applicable network condition. Generators must maintain settlement-meter data for the corresponding periods, while the EU declarant needs an allocation that reconciles with the customs import.
Data access and governance should therefore be designed alongside grid connection rights. Long-term power purchase agreements (PPAs) and lender direct agreements should specify who can access source records, how corrections are managed, how long information must be retained and what happens if a trader or service provider withdraws from the transaction. A renewable project can be physically connected to the grid yet still lack the reliable evidence chain required to support financing and regulatory claims.
Battery energy storage systems are adding another dimension to grid planning. Montenegro has launched a process to select a strategic partner for battery storage development, reflecting the growing importance of flexibility as wind and solar generation expand. At system level, storage can support balancing, congestion management, electricity-price arbitrage and reserve capacity. It can also make export profiles more commercially attractive by shifting electricity delivery towards higher-priced hours.
However, these benefits should be distinguished from any assumed CBAM qualification for renewable electricity discharged from storage at a later time. Under the current electricity rules, production and nominations must be linked within the same period. Careful metering may help preserve physical traceability, but technical traceability alone does not determine the legal treatment of electricity discharged at a later hour. A prudent financing model should value arbitrage and balancing revenues first and avoid assigning an unproven carbon premium until the applicable methodology is clear.
The 600 MW Montenegro–Italy high-voltage direct-current interconnector further increases the strategic importance of the domestic transmission network. New generation in northern or central Montenegro must reach the relevant grid nodes, navigate internal network constraints and be scheduled for delivery through the cross-border connection. Consequently, a project’s export potential depends partly on the transmission capacity between its generating site and Lastva, rather than simply on the availability of the submarine cable.
This explains why grid investment can improve renewable-project valuations even without increasing wholesale electricity prices. Lower curtailment, greater network availability, stronger evidence systems and more predictable export access can increase the share of generation that earns its contracted price or qualifies for an applicable premium. These improvements can strengthen debt-service coverage more reliably than optimistic assumptions about future merchant electricity prices.
Montenegro’s next renewable investment cycle will test whether transmission planning can keep pace with the expansion of the project pipeline. The infrastructure required is no longer limited to transmission lines, substations and interconnectors. It increasingly combines physical capacity, operational control and auditable data, enabling new renewable generation to become a reliable, commercially valuable and bankable market product.