As Southeast Europe approaches 2026, the thermal power landscape is poised to evolve, driven by a complex interplay of hydropower availability, CO₂ pricing, coal mining capabilities, and cross-border trading dynamics. The region’s reliance on thermal generation, particularly during dry spells, underscores its critical role in maintaining energy security. However, the economic viability of these thermal units is increasingly contingent upon their operational flexibility and the performance of renewable resources.
Serbia stands out as a pivotal player in the region’s thermal generation landscape, with lignite-fired power plants contributing significantly to its electricity supply. The state-owned utility, Elektroprivreda Srbije (EPS), operates a lignite capacity of approximately 4,390 MW within a total installed capacity of around 7,662 MW. With hydroelectric generation capacity at 2,936 MW, Serbia’s energy strategy remains heavily reliant on thermal resources during periods of low hydropower output. The commissioning of the Kostolac B3 unit in late 2024, adding 350 MW to the grid, enhances the country’s baseload capacity and overall system reliability.
The relationship between hydroelectric output and thermal generation is crucial for forecasting future energy needs. Historical data indicates that fluctuations in hydropower production can lead to corresponding shifts in thermal dispatch and imports. A typical annual hydro variation of 2–3 TWh can significantly impact lignite consumption patterns—when hydropower falls short, thermal units must compensate by increasing output, thereby raising operational costs and maintenance requirements.
For 2026, projections suggest that Serbia’s thermal generation could range between 23–28 TWh depending on hydrological conditions and operational dynamics. In scenarios where hydro performance is strong, thermal output may decrease; conversely, weak hydrological conditions could necessitate higher thermal generation levels to ensure domestic supply adequacy. This creates a scenario where Serbia may need to balance its reliance on domestic lignite against the backdrop of fluctuating import costs.
Operational constraints related to coal mining present another layer of complexity. Serbia’s lignite production is predominantly sourced from local mines in the Kolubara and Kostolac basins. EPS’s lignite output is estimated at around 37 million tonnes annually; however, the actual deliverability from these mines will be critical in supporting increased thermal demand during dry years. Recent performance reports indicate that while Kolubara delivered approximately 22 million tonnes in 2023, Kostolac’s Drmno mine achieved record outputs nearing 10 million tonnes.
The efficiency of lignite plants further influences their operational viability. For instance, the newly commissioned Kostolac B3 unit boasts a net efficiency of about 37.3%, enhancing the overall economics of coal-to-power conversion. In a base scenario for 2026 with projected thermal generation of 24–27 TWh, Serbia could require between 30–37 million tonnes of lignite depending on various factors including plant dispatch patterns and coal quality.
Market finance indicators will also play a significant role in shaping Serbia’s energy landscape. The anticipated European CO₂ price floor for 2026 is projected at around €92 per tonne. This pricing structure impacts not only domestic coal costs but also influences regional trading dynamics as interconnected markets adjust to higher variable costs associated with CO₂ emissions. As such, Serbia may face increased pressure to maximize lignite output during dry periods to mitigate reliance on costly imports.
The balancing value of thermal plants will become increasingly important as the region integrates more variable renewable energy sources. In this context, thermal units will be essential for providing stability during peak demand periods when hydropower availability is compromised. However, this balancing act comes at a rising cost as older coal units face challenges related to flexibility compared to gas counterparts.
In broader regional terms, policy decisions and decommissioning timelines will influence the overall thermal landscape through 2026. Romania’s coal fleet faces phase-out pressures but has sought extensions due to delays in replacement projects. The implications for regional trading are significant; prolonged operation of coal capacity could stabilize prices while accelerated decommissioning may heighten import dependence and sensitivity to external market fluctuations.
In summary, Serbia’s thermal power outlook for 2026 hinges on several interrelated factors: anticipated lignite generation within a range of 24–27 TWh under normal conditions; robust coal mining performance; and effective management of CO₂ pricing impacts on both domestic operations and regional trading strategies. Successfully navigating these challenges will be essential for maintaining energy security while balancing environmental compliance and economic stability.
