As South-East Europe accelerates renewable integration, the region’s conventional generation mix is showing a clear pivot from growth to contraction. Coal-fired output remains important for system stability, but its operating pattern is increasingly shaped by structural decline rather than a return to higher utilisation. For grid planners and investors, this trend matters because it influences how much firm capacity is actually available during stress periods and how quickly flexibility gaps may emerge.
Week 16 output stays near mid-2025 lows
In week 16, coal generation reached 4,477 MW, a modest week-on-week rise that still sits close to the lowest levels recorded since mid-2025. While short-term revenues improved, supported by higher power prices and relatively stable fuel costs, plant utilisation remains subdued. This combination signals that coal is being dispatched more selectively rather than running as a consistently full baseload resource.
Serbia leads, but regional declines persist
Serbia continues to be the largest contributor to coal generation, providing roughly 38–40% of regional output. During the week, Serbian coal generation increased by 292 MW, partially offsetting weaker performance elsewhere. However, declines in other markets, including Slovenia and Montenegro, counterbalanced these gains and kept overall regional output constrained.
Year-on-year drop reflects renewables and constraints
Comparisons with the same period in 2025 reinforce the downward trajectory, with coal generation across the region 673 MW lower year-on-year. The reduction aligns with increased renewable penetration and environmental constraints that continue to shape dispatch decisions. Evolving market dynamics are also contributing to lower coal running hours, affecting how developers and operators model future capacity availability.
Carbon costs and “managed decline” reshape planning assumptions
Even as coal plants provide essential baseload support—particularly when renewable output is low—their role is increasingly limited to specific operating windows. Rising carbon costs are adding pressure on competitiveness, with EUA prices reaching €74.9/t. In response, operators are placing greater emphasis on “managed decline,” aiming to maximise remaining value while preparing for eventual phase-out through measures such as optimising maintenance schedules and reducing operating hours.
For policymakers and system operators, the central challenge is balancing reliability needs against environmental targets while ensuring adequate flexibility. If flexible capacity remains insufficient, coal units are likely to stay in the system longer than originally anticipated, though with declining utilisation. For developers of wind, solar and battery energy storage systems—and for utilities preparing EPC-ready grid modernization packages—these dynamics underline the importance of aligning technical studies and procurement timelines with realistic dispatch conditions across the region.
Overall, the shift toward managed decline in South-East Europe’s coal fleet highlights a transitional reliability landscape: conventional plants remain relevant for stability, but their reduced running profile strengthens the case for faster build-out of flexible resources and transmission upgrades. Investors and contractors preparing engineering studies and procurement frameworks will need to treat utilisation trends as a key input into CAPEX planning and execution readiness for next-generation power system assets.