Montenegro’s state-owned power utility Elektroprivreda Crne Gore has entered a more debt-intensive phase, after relying on bank financing to absorb the cost of electricity imports, investment spending and the political commitment to avoid sharp increases in household power prices. The company’s latest credit exposure, reported at €88.5mn, is not simply a balance-sheet item. It is a signal that Montenegro’s electricity model is being stretched between social affordability, security of supply and the capital requirements of the energy transition.
The core problem is structural. EPCG must supply the domestic market at politically sensitive prices while also navigating volatile wholesale markets, weaker hydrology, coal-plant outages and rising investment needs. In a wet year, Montenegro’s hydro system can reduce import dependence and protect cash flow. In a dry year, or when Thermal Power Plant Pljevlja is constrained by overhaul, environmental reconstruction or operational limits, the utility is forced into the regional power market at prices that can be materially higher than the average regulated or politically tolerated domestic tariff.
That mismatch is now visible in the financing data. EPCG reportedly took dedicated loans for electricity imports, with several facilities carrying fixed rates in the 2.99%–3.9% range and one facility priced at 1.6% plus Euribor. The largest reported import-related facility was a €50mn loan from Erste Group, with repayment extending to July 2029. In practical terms, the company borrowed to buy power that was then supplied to domestic consumers at prices below the cost of replacement energy on the market.
This is the hidden subsidy inside Montenegro’s electricity system. It does not always appear as a direct budget transfer. Instead, it appears as pressure on EPCG’s liquidity, reduced accumulated profit, higher bank borrowing and delayed tariff adjustment. Consumers are shielded in the short term, while the utility absorbs the difference through its balance sheet. That approach can work for a limited period if the company has strong reserves. It becomes more difficult when import costs, capital expenditure and debt maturities all rise at the same time.
EPCG’s financial position was hit by several simultaneous pressures. The company faced an electricity import bill reported at around €142mn, while spending approximately €86.8mn on investments. That investment figure was about €34mn higher than in the previous year, showing that EPCG was not only financing current supply, but also pushing forward with capital projects. The largest investment items included the environmental reconstruction of TPP Pljevlja, with spending of around €32.6mn, and roughly €27.5mn directed toward new renewable-energy assets and project preparation, including Gvozd wind farm, solar projects at Slano, Krupac and Željezara, as well as preparatory work for HPP Kruševo, HPP Otilovići and a new unit at HPP Perućica.
That is the strategic contradiction facing EPCG. The company needs to invest faster in domestic generation if Montenegro is to reduce import exposure, meet environmental requirements and create a more resilient power system. But the same import exposure is weakening the company’s ability to finance that investment from internal cash flow. The transition requires capital; the current supply model consumes it.
The reported operating loss of around €92mn underlines the scale of the problem. EPCG had previously indicated that it would avoid raising electricity prices and cover the expected losses caused by the long interruption at TPP Pljevlja from accumulated profit and its own resources. That strategy softened the immediate political and social impact on consumers, but it also transferred the burden to the company’s reserves and lenders. Accumulated profit of around €70mn was used, while new borrowing increased.
By the end of the reporting period, EPCG’s total drawn credit obligations were reported at approximately €179.3mn, compared with €111.7mn at the end of the previous year. Long-term loans accounted for about €141mn, while short-term loans stood near €28mn. Around €38mn of those obligations are due for repayment during the current year. That maturity profile matters because EPCG is not a normal commercial borrower operating in a fully liberalised market. It is a strategic state utility whose cash flow depends on hydrology, coal availability, regulatory decisions, wholesale prices and government tolerance for tariff increases.
For Montenegro’s power sector, this is a warning signal rather than an immediate solvency crisis. EPCG still owns critical generation assets, has a central role in domestic supply and remains one of the most important corporate entities in the country. But the financial model is becoming more fragile. A utility cannot indefinitely buy expensive market electricity, sell it below cost, finance investment, absorb coal-plant disruption and maintain balance-sheet strength without either tariff reform, state support, improved generation availability or a major acceleration of new domestic supply.
The hydrology factor is especially important. EPCG’s hydro plants, particularly Perućica and Piva, are central to Montenegro’s power balance. In the reported period, weaker hydrology meant production from these plants reached only about 74% of plan. That shortfall forced greater reliance on imports and exposed the company to market prices. This is not a one-off risk. Climate volatility is making hydrological output less predictable across South-East Europe. For hydro-dependent systems, the financial value of water has become a balance-sheet variable.
TPP Pljevlja adds a second layer of risk. The plant remains essential for baseload supply, yet its environmental reconstruction and long-term compliance costs are unavoidable. Montenegro cannot treat the plant as both a permanent reliability anchor and a low-cost legacy asset without recognising the investment required to keep it operating within environmental limits. The €32.6mn spent on ecological reconstruction is therefore not optional expenditure. It is the price of keeping domestic generation available while the country builds the next layer of renewable and flexible capacity.
The investment programme in renewables is strategically necessary, but it will not remove import risk overnight. Wind and solar projects can reduce annual energy deficits, but they also introduce intermittency. Montenegro will need grid reinforcement, balancing capacity, storage, better forecasting and regional trading discipline. The Gvozd wind project and new solar assets are important steps, but the next phase must be designed around system value rather than headline megawatts. A megawatt that produces during surplus hours is not worth the same as capacity that reduces imports during winter peaks or dry hydro periods.
That is why EPCG’s borrowing should be seen as a market-design issue, not only a corporate-finance issue. Montenegro needs a clearer framework for allocating the cost of security of supply. At present, much of that cost appears to be absorbed by EPCG. The alternatives are politically difficult: higher tariffs, targeted subsidies for vulnerable consumers, direct state support, market-based procurement, accelerated renewables, storage investment, or a combination of all five. The weakest option is to postpone the decision and let debt carry the system quietly.
From an investor perspective, the numbers also matter for Montenegro’s wider energy-transition credibility. EPCG is expected to be an investment vehicle, a public supplier, a renewable developer, a coal-transition manager and a stabiliser of consumer prices. Those roles can conflict. Lenders and partners will look closely at whether the company’s tariff environment allows it to recover costs, whether state policy is predictable, whether investment projects are commercially structured, and whether debt is being used for productive assets or simply to cover operating losses from underpriced supply.
The social dimension cannot be dismissed. Electricity price increases are politically sensitive in Montenegro, where household budgets are already exposed to higher food, housing and service costs. A sudden tariff shock would carry real consequences. But shielding consumers through utility debt is not a permanent solution. A more durable model would separate social protection from electricity pricing: vulnerable households should be supported directly, while the utility should be allowed to maintain financial discipline and invest in system resilience.
The same logic applies to industry. Montenegro’s industrial base, including aluminium-related activity, metals, tourism infrastructure, cold-chain logistics and construction materials, depends on reliable and competitively priced power. But competitiveness cannot be built on opaque losses inside the state utility. Industrial users need predictable tariffs, credible supply and increasingly, in the context of EU carbon rules and CBAM exposure, cleaner electricity documentation. EPCG’s investment in renewables and hydro modernisation can become a strategic advantage, but only if the company’s finances remain strong enough to deliver the projects.
The reported credit exposure therefore marks a turning point. EPCG is no longer only managing annual production and supply. It is managing the financial consequences of a delayed transition. Coal reliability is becoming more expensive. Hydro output is more volatile. Imports are costly when regional markets tighten. Renewable investment is necessary but capital-intensive. Tariffs remain politically constrained. Each of these pressures can be managed individually. Together, they define the new economics of Montenegro’s electricity system.
The policy conclusion is clear even without formal announcement. Montenegro will need a more transparent energy compact between the state, EPCG, consumers, banks and investors. That compact must decide who pays for import risk, who finances the transition, how vulnerable consumers are protected, and how quickly domestic generation can be strengthened. Borrowing can bridge a difficult year, but it cannot replace a market structure.
EPCG’s €88.5mn borrowing is therefore not merely evidence of financial pressure. It is the price of keeping the lights on while avoiding the full political cost of electricity repricing. The next stage will depend on whether Montenegro uses that borrowed time to accelerate domestic generation, improve tariff targeting, strengthen liquidity planning and turn investment spending into lower import exposure. Without that shift, the utility’s balance sheet will continue to carry risks that properly belong to the country’s energy policy.
