Montenegro’s electricity balance tightened sharply for delivery on 15 July 2026, as rising summer consumption coincided with weaker domestic generation. The BELEN day-ahead baseload price increased by €22.60/MWh to €126.59/MWh, its highest level in seven sessions, although the market remained €24.48/MWh below Hungary’s HUPX and €39.32/MWh below Italy.
Forecast national consumption rose from 409 MW to 442 MW, an increase of roughly 8 per cent in one day. Generation was expected to fall from 308 MW to 291 MW, widening Montenegro’s average import requirement from 101 MW to 151 MW. The resulting deficit was equivalent to approximately 34 per cent of demand, illustrating the country’s exposure to regional prices during periods of high tourism-related load and weaker hydro or wind production.
The most recent complete generation structure remained heavily dependent on the Pljevlja thermal power plant, which supplied an average 201 MW, or about 71 per cent of recorded domestic output. Hydropower contributed 49 MW, while wind generation from the Krnovo and Možura portfolios averaged 32 MW. Coal therefore continued to carry the system even as Montenegro prepared additional solar, wind and storage investments.
The daily price curve was unusually firm throughout the session. BELEN’s minimum hourly price reached €80/MWh at hour 12, compared with only €22.10/MWh a day earlier, while the evening maximum rose to €200/MWh at hour 22. Peakload averaged €110.20/MWh, but off-peak electricity was more expensive at €143/MWh because the off-peak block captured the late-evening scarcity period.
That profile weakens the economics of simple daytime solar exposure while strengthening the case for dispatchable hydro and batteries capable of delivering after sunset. A solar project selling unshaped production would remain exposed to the lowest part of the curve, whereas storage retaining sufficient grid capacity for the evening could target a price spread of as much as €120/MWh between the daily minimum and maximum.
Montenegro simultaneously retained its role as a transit market. Commercial schedules indicated average inflows of approximately 182 MW from Bosnia and Herzegovina, 72 MW from Serbia, 111 MW from Albania and 124 MW from Kosovo, while flows towards Italy averaged around 338 MW through the submarine interconnector. These gross positions are substantially larger than the national deficit because Montenegro imports from several Balkan markets while transmitting electricity westward to the higher-priced Italian system.
The August capacity picture reinforces the value of the country’s borders. Available transfer capacity included 200 MW from Bosnia and Herzegovina, 100 MW from Kosovo and 50 MW from Albania into Montenegro. In the opposite direction, 200 MW was available towards Bosnia and Herzegovina, 100 MW towards Kosovo and 51 MW towards Albania. July transmission rights from Serbia into Montenegro cleared near €6.51/MWh, while rights from Bosnia and Herzegovina were valued at €5.20/MWh.
For EPCG and private developers, the commercial lesson is more demanding than the headline BELEN increase suggests. Montenegro needs additional generation, but the value of each project depends on its production profile, balancing position and access to the Italian link. Wind can retain higher system value than solar because it has a greater capacity factor and can generate outside the midday period, although its output still requires separate curtailment and transmission analysis. Batteries can capture the evening premium, but only where the connection agreement preserves discharge capacity during the hours when regional flows and tourism demand are strongest.
