The electricity landscape in South-East Europe (SEE) is experiencing a significant transformation, shifting from a focus on energy adequacy to grappling with a flexibility deficit. Historically, the region’s power sector concentrated on ensuring enough generation capacity to meet demand. However, with a dramatic increase in installed capacity—especially from solar energy—this challenge is evolving. As of early April 2026, total demand reached 29,759 MW while generation was at 26,197 MW, leading to reliance on imports to fill the gap.
On this particular day, the system displayed a complex dynamic: periods of excess generation led to negative pricing, while scarcity drove prices above €200/MWh. This juxtaposition illustrates the emerging issue of flexibility constraints within the system. The rapid growth of renewable sources, particularly solar—which contributed approximately 3,927 MW—has created supply peaks that are not easily managed without adequate storage or flexible resources.
Hydropower remains crucial in balancing this variability, providing around 6,859 MW of output. However, its effectiveness is limited by hydrological conditions and environmental factors. As river flow variability increases due to climate impacts, hydropower may contribute to uncertainty rather than stability. Thermal generation from coal and gas continues to play a vital role as well, transitioning from baseload providers to more flexible assets necessary for maintaining system stability.
The concept of a flexibility deficit highlights the disconnect between supply and demand in real-time operations. Although installed capacity appears sufficient overall, the inability to align generation with consumption leads to price volatility and increased import reliance. On the observed day in April 2026, net imports of about 1,002 MW were necessary to balance the system; however, these flows are increasingly hindered by transmission constraints and synchronized renewable patterns across Europe.
Grid infrastructure has become a critical bottleneck in this evolving context. Originally designed for centralized power plants, the current grid must adapt to accommodate distributed and variable renewable generation. Existing limitations lead to congestion and curtailment issues that diminish overall efficiency and complicate project economics.
Battery storage technology emerges as a key solution to address the flexibility deficit by allowing energy temporally shifting capabilities. The economic rationale for storage investments is strengthening due to substantial intraday price variations and diverse revenue opportunities such as arbitrage and balancing services. Projects across Romania and neighboring markets indicate a broader investment trend towards enhancing storage capabilities.
Demand-side management also represents an underutilized resource that could help mitigate peak demands by adjusting industrial processes or heating systems in response to high renewable output periods. However, realizing this potential necessitates regulatory support and technological integration while fostering changes in consumer behavior.
This transition is likely to have profound financial implications as investment priorities shift towards flexibility-enhancing assets rather than solely generation capacity. While solar and wind projects continue attracting capital investment, assets capable of responding dynamically to market signals are becoming increasingly desirable.
A realistic capital expenditure (CAPEX) forecast indicates that while renewable generation will still require significant funding over the next decade, investments in grid expansion and storage solutions will take on greater importance. Multi-billion-euro initiatives will be essential for upgrading transmission networks as storage capabilities evolve from pilot projects into critical infrastructure for system reliability.
The changing risk landscape also necessitates a more sophisticated approach from investors; generation projects face heightened exposure to price fluctuations while flexibility assets hinge on stable market conditions and supportive regulatory frameworks.
Policy frameworks are beginning to align with these developments by shifting focus from mere capacity targets toward comprehensive system integration encompassing grid planning and market design improvements. Nonetheless, disparities in policy adaptation rates across different countries remain a challenge.
As SEE transitions from an energy deficit toward addressing flexibility deficits, broader economic implications arise concerning electricity pricing that influences both industrial competitiveness and consumer affordability. Managing these complexities requires careful coordination between market signals and policy interventions.
Looking ahead towards 2026–2030, addressing the flexibility deficit will be pivotal for shaping the trajectory of SEE’s power market. Various scenarios could unfold: gradual improvements through incremental grid enhancements might stabilize operations while maintaining thermal generation’s relevance; alternatively, delayed investments could exacerbate volatility and reliance on imports.
Ultimately, how effectively stakeholders navigate this transition will depend on investment flows, policy decisions, and technological advancements within the region’s evolving energy landscape. A renewed focus on delivering electricity at optimal times will be essential as South-East Europe moves toward a more flexible power paradigm.
