The energy landscape in Southeast Europe is undergoing significant transformation as solar generation increasingly influences power market dynamics, even during the winter months. In February 2026, solar output faced limitations due to seasonal irradiation patterns, yet its effects on pricing and trading behaviors have become more pronounced. This shift marks a critical evolution in how solar energy is integrated into the region’s energy transition.
Data from February indicates a notable decrease in solar-driven renewable generation, particularly in Greece, where output declined by -12.87% to an average of 76 GWh/day. This reduction not only reflects meteorological conditions but has also led to a shift in price formation within the market. Typically, solar generation helps suppress midday prices; however, its decreased availability resulted in elevated price floors during daylight hours, compelling greater reliance on alternative sources of flexible generation. Hydro generation surged by +69.07% during this period to compensate for the shortfall.
The uneven performance of solar across the region is evident when comparing Italy and Greece. Italy experienced a +17.98% increase in renewable output, driven by both solar and wind contributions. Despite this growth, Italian spot prices only fell by -13.76% to €114.41/MWh, demonstrating the system’s capacity to absorb fluctuations without significant price disruptions, unlike the more volatile Balkan markets.
This variability underscores a critical aspect of solar’s economic role: its impact is not solely based on total output but rather its position within the merit order of generation resources. In Serbia, for instance, where solar constitutes just 6.88% of total renewables, an increase in combined solar and wind production of +23.10% led to a dramatic -41.92% drop in spot prices to €68.61/MWh. Here, solar acts as a marginal disruptor that can displace more expensive lignite and imports during limited daylight hours.
The seasonal trading profile emerging from these dynamics indicates that while solar does not dominate baseload price formation in February, it plays a crucial role in shaping intraday market structures. The compression of midday prices remains evident but is less pronounced than during summer months, resulting in narrower spreads between peak and off-peak hours—effectively flattening the traditional “duck curve” associated with high levels of solar integration.
The decline in strong solar output has also shifted the responsibility for system balancing across markets. In Greece, hydro resources filled the gap left by reduced solar production; conversely, countries with limited flexible capacity resorted to increased imports to maintain balance. Italy’s net imports rose significantly by 3,803.32 GWh (+36.89%), reflecting how larger systems leverage cross-border energy flows to manage renewable variability effectively.
From an economic standpoint, February highlighted ongoing challenges related to solar capture prices. Even during lower output periods, solar generation aligns with lower-priced hours—a trend that intensifies as more capacity enters the market across Southeast Europe (SEE). This situation creates dual pressures for producers: diminished volumes during winter months coupled with compressed pricing during operational hours leads to a widening gap between average market prices and actual revenues from solar production.
This evolving landscape is prompting changes in investment strategies among industrial consumers throughout SEE who are increasingly aligning their procurement processes with anticipated solar production patterns to benefit from lower midday pricing through structured agreements. Simultaneously, developers are investigating hybrid solutions that combine solar with battery storage systems to optimize output timing for higher-value evening demand periods—a necessary adaptation given the increasing revenue volatility faced by standalone solar assets.
Grid integration remains a pressing challenge as well; while February did not see widespread curtailment of generated power, signs indicate potential future constraints as installed capacity grows—particularly in Romania, Bulgaria, and Greece—leading to heightened risks of midday congestion. Current systems can accommodate existing output without severe reductions; however, summer conditions may exacerbate these issues due to insufficient storage capabilities and grid infrastructure expansion.
As Southeast Europe’s energy markets continue their transition towards integrating more renewable sources like solar into their frameworks, it becomes clear that the role of this technology will evolve beyond mere energy provision into critical components of price formation processes throughout all seasons—even those traditionally dominated by other forms of generation.
