North Macedonia’s day-ahead electricity trading activity showed a modest rise in February 2026, according to market operator data. The volume traded on the country’s day-ahead exchange reached 115,796 MWh, up 1% versus 114,665 MWh in the same month a year earlier. At the same time, the month’s traded volume was 24.3% lower than in January, indicating a weaker near-term trading tempo.
For developers and grid stakeholders tracking market signals that can influence offtake planning, the February shift is notable but not decisive. The market-clearing price averaged 70.76 euros/MWh, down 42.3% compared with the previous month. The daily average trading volume stood at 4,135.6 MWh, while the highest price recorded during the month reached 74.1 euros/MWh.
Market operator MEMO reports February price and liquidity changes
The reported average market-clearing price of 70.76 euros/MWh places February’s pricing environment materially below the prior month’s level. A decline of 42.3% suggests that short-term power value weakened even as volumes ticked up year-on-year. Liquidity also remained active, with daily average trading at 4,135.6 MWh supporting continuous day-ahead scheduling.
For participants preparing commercial arrangements—such as traders supporting renewable integration or utilities managing balancing needs—these figures help frame revenue expectations under current market conditions. The peak price of 74.1 euros/MWh provides a ceiling reference for volatility during the month, which can matter for risk management and contract structuring.
Exchange established in May 2023
The North Macedonian electricity exchange was established in May 2023, providing a formal platform for day-ahead transactions. This operational context is relevant for understanding how market participants evaluate liquidity trends over time. With February showing a small year-on-year improvement but a sharper month-on-month decline, the latest data points to shifting demand and scheduling patterns rather than sustained acceleration.
Broader implications for power system planning
While the figures relate specifically to day-ahead trading performance, they carry practical implications for broader energy investment planning and grid modernization discussions. Lower average prices can affect how stakeholders assess near-term economics for generation portfolios and storage-linked dispatch strategies. At the same time, steady daily volumes indicate continued market participation that can support planning for future renewable additions and operational flexibility requirements.
Overall, February 2026 combined slightly higher traded volumes versus last year with substantially lower average prices versus January, underscoring a market that remains liquid but less valuable on average. For utilities, contractors supporting grid and generation projects, and investors monitoring power-market fundamentals, the data offers a snapshot of current conditions that can inform procurement readiness and CAPEX timing decisions.