The retrofit can cut sulphur, nitrogen and dust. It cannot turn a 225MW lignite plant into a low-carbon asset, or answer who replaces its winter electricity and northern jobs.
A cleaner coal plant is still a coal plant
Montenegro’s Pljevlja thermal power plant is both indispensable and increasingly incompatible with the country’s European destination. The 225MW lignite unit supplied roughly 40 per cent of domestic generation in 2024. When it is unavailable, Elektroprivreda Crne Gore must buy electricity from a volatile regional market. When it runs, the plant and its mine carry the country’s largest concentrated air-pollution and carbon burden.
EPCG’s ecological reconstruction addresses the first problem. The programme includes flue-gas desulphurisation, nitrogen-oxide and particulate controls, wastewater systems, boiler work and a link to district heating. Cost figures in public debate range from about €58mn for the core environmental contract to roughly €86mn including a wider package and value added tax. They describe different scopes and should not be treated as rival estimates of one invoice.
Initial testing of the desulphurisation system in February 2026 reportedly reduced sulphur dioxide concentration to about 61 milligrams per cubic metre, compared with 4,544 milligrams per cubic metre in a March 2025 measurement. That is a material local-health improvement if sustained under normal operation. It does not reduce the carbon dioxide embedded in every megawatt-hour or remove the mine’s long-term liability.
Pljevlja can become much less dirty without becoming compatible with Europe’s destination.
The Commission is judging the investment against closure
The European Commission’s 2025 report was blunt: ecological reconstruction was proceeding without resolving the core issue, and Montenegro still needed a permanent closure pathway and just transition for the coal region. The message reflects two separate regimes. Industrial-emissions rules govern sulphur dioxide, nitrogen oxides and dust. Climate policy, electricity-market integration and an eventual carbon price govern the economics of lignite itself.
Montenegro adopted its National Energy and Climate Plan in December 2025, creating a formal route for power-sector reform. The difficult decisions remain temporal. Closing before replacement generation, storage and transmission are available would increase imports and security risk. Running indefinitely would expose EPCG and industrial customers to rising carbon and compliance costs and weaken the credibility of accession.
The 2025 reconstruction outage showed the cost of poor sequencing. EPCG said it had contracted 788GWh of imports for €81.7mn to help cover the gap. Hydro output and market prices can improve or worsen that result, but the balance-sheet lesson is stable: the replacement portfolio must be ready before the coal unit stops being an energy hedge.
The asset transition is larger than one power station
EPCG needs firm energy, not merely installed renewable megawatts. The Gvozd wind farm, additional solar and wind projects, upgraded hydropower, batteries and prospective pumped storage can replace annual generation over time. They do not automatically replace a dispatchable unit during a dark, dry winter evening. Interconnection with Serbia, Bosnia and Herzegovina and Italy provides another source of flexibility, but imports carry price and availability risk.
The town needs a parallel transition. The mine and plant support wages, suppliers and municipal revenue in a part of Montenegro that already develops more slowly than the coast. District heating can turn some of the reconstruction into a durable public asset, but it cannot employ a mining workforce. Remediation, grid works, renewable construction, forestry, industrial services and retraining require funded projects, not a national promise of green jobs.
This is where EU grants and development lenders should take more risk than a commercial bank. They can finance networks, district heat, remediation and worker transition whose social return exceeds the direct cash yield. EPCG should finance commercially viable replacement generation. The state should identify and budget the non-commercial obligations rather than leaving them inside the utility’s accounts.
The retrofit buys time only if Montenegro uses it
A sensible operating plan would set transparent annual limits for emissions, hours, mine costs and outage reliability, alongside dated milestones for replacement capacity. It would stress-test EPCG under low hydrology, high import prices and a carbon charge. The closure date could contain defined security conditions, but it should not be a rolling political horizon.
The company must also disclose reconstruction performance and full costs consistently. A system that looks compliant only during a test has little value. Independent continuous-emissions data, coal quality, availability and maintenance spending should determine whether another year of operation creates more system value than liability.
EPCG was rational to reduce Pljevlja’s local pollution if the plant had to operate through a transition. The mistake would be to interpret sunk retrofit capital as a reason to extend coal indefinitely. Brussels is demanding an endpoint because the investment does not supply one. Montenegro’s task is to turn the cleaner interval into replacement power and a funded future for Pljevlja before the interval closes.
