Montenegro’s expanding solar and wind development pipeline is increasing pressure on transmission infrastructure, grid integration and balancing capacity, requiring investors to assess how new projects will fit into the wider electricity system.
The Montenegrin transmission system operator CGES reported approximately 7 GW of expressed interest in grid connections, with around 5 GW processed through connection studies and connection agreements signed for approximately 3 GW of projects, predominantly solar.
Montenegro’s 2026 energy balance, by comparison, envisaged total available generation capacity of approximately 1.32 GW by the end of the year, assuming planned projects were completed. The figures indicate that the development queue substantially exceeds the capacity of the existing national generation fleet. Converting the proposed projects into operating assets will require changes and investment across transmission infrastructure, balancing arrangements, electricity market integration and project financing.
Developers are consequently competing for more than suitable land and permits. Their projects also depend on available substation bays, grid-connection windows, transmission reinforcements, engineering, procurement and construction (EPC) capacity, financing, long-term offtake agreements and the electricity system’s ability to accommodate variable renewable generation.
Even projects with sound individual development cases can face delays if the relevant network infrastructure or other developments sharing the same transmission corridor are not ready. Montenegro is already strengthening its transmission network. The Trans-Balkan corridor connects the country more closely with Serbia, Bosnia and Herzegovina and the Italy interconnector.
Separately, work backed by the European Bank for Reconstruction and Development (EBRD) on the Trebinje–Perućica–Podgorica–Vau i Dejës corridor is intended to increase transmission capacity from approximately 300 MW to around 600 MW. These investments are intended to improve the network’s capacity, but individual projects will still require assessments of congestion risks, grid availability and the sequencing of commissioning activities.
Battery energy storage systems (BESS) can support integration by shifting electricity generation across time, providing balancing and ancillary services, and reducing certain peak injections into the network. However, their effectiveness in addressing transmission constraints depends on their location, control systems, access to electricity markets and applicable grid requirements.
Where a connection study identifies the need for network reinforcement, installing a battery does not automatically eliminate that requirement.
For lenders financing individual renewable developments, including a 100 MW solar plant, assessments will increasingly need to account for other projects expected to connect in the surrounding area, upstream infrastructure that CGES must complete and the effects of regional electricity flows on available transmission capacity. Project sponsors will need to demonstrate that their proposed developments can progress beyond signed grid documentation. This includes credible energisation schedules, coordinated interface management with CGES, tested curtailment assumptions, dispatch and electricity market scenarios, and storage systems designed around defined network functions and revenue models where applicable.
Montenegro’s renewable energy development potential remains substantial, but the volume of proposed capacity makes the relationship between project schedules and actual network availability increasingly important. Projects will need to be designed around the transmission system expected to be operational at the commercial operation date (COD), rather than relying on infrastructure that has yet to be delivered.
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