As the Western Balkans approach 2030, the region’s electricity systems are poised to play a pivotal role in the broader South-East European power market. The dynamics of flexibility, supply, and price volatility will be crucial as these countries transition from traditional energy sources to a more integrated and variable renewable energy landscape. Current modeling indicates that the future stability of the region will hinge on the interplay between aging coal assets, hydropower’s climate vulnerability, and the integration of variable renewables, rather than merely on increasing capacity.
The power systems in Serbia, Bosnia and Herzegovina, Kosovo*, and parts of North Macedonia are heavily reliant on lignite-fired generation established decades ago. In contrast, Albania and Montenegro depend significantly on hydropower. This historical reliance has provided a measure of energy adequacy under stable demand and predictable hydrological conditions. However, as the influence of climate variability grows and renewable energy sources become more prevalent, this legacy system faces increasing fragility.
Forecasts suggest that existing thermal capacities will not collapse dramatically by 2030; instead, they will operate under altered circumstances. Lignite and coal plants are expected to see reduced utilization rates due to competition from wind and solar power in neighboring countries like Romania, Bulgaria, and Greece. These thermal plants may still be called upon during peak demand periods but will struggle economically due to diminished run hours during high-renewable periods.
Serbia emerges as a critical node in this evolving landscape. As the largest load center in the Western Balkans and a key transit point for electricity flows between Central Europe and the southern Balkans, Serbia’s lignite resources are vital for regional supply security during peak stress hours. However, economic pressures from carbon regulations and declining capacity factors threaten the viability of these resources. Dispatch simulations indicate that Serbia’s power system will experience significant intraday fluctuations between surplus exports during midday and scarcity during evening hours.
Hydropower’s role in the region is also undergoing scrutiny. While it remains a stable energy source annually, its reliability is increasingly compromised by climate variability, leading to more frequent dry spells that impact flexibility when it is most needed. Countries like Albania and Montenegro are particularly susceptible to these hydrological risks, while Bosnia and Herzegovina’s mixed generation profile offers some mitigation but is not immune to such challenges.
The assumption that the Western Balkans can act as a net exporter of flexibility is being reevaluated. In years with abundant hydro resources, surplus exports may occur; however, during droughts or heatwaves, the region could face shortages requiring imports from neighboring countries such as Romania, Hungary, Bulgaria, and Greece. This shift highlights a bidirectional dependency that will shape future pricing dynamics across the region.
Renewable deployment is set to accelerate in this context, particularly for wind and solar energy. Serbia and Bosnia and Herzegovina are expected to lead in wind installations, while solar capacity will expand across North Macedonia, Albania, and Kosovo*. However, wind generation in this area may show greater short-term volatility compared to Western Europe due to less geographic diversity in wind patterns. This volatility necessitates enhanced regional balancing mechanisms rather than relying solely on national solutions.
The introduction of solar power presents distinct challenges as well. High midday generation can suppress market prices while creating scarcity during evening hours when demand peaks but solar output declines sharply. Without substantial storage solutions or demand-side flexibility measures in place, these patterns could lead to systemic stress across South-East Europe.
Gas-fired generation is projected to play an increasingly important role by 2030. Although it does not dominate the overall energy mix, gas plants are expected to serve as primary fast-ramping resources during periods when solar output diminishes or wind generation falters. Utilization rates for gas facilities are anticipated to rise significantly compared to earlier years.
Despite its potential value in balancing supply and demand dynamics, storage capacity and demand-side response mechanisms remain underdeveloped in the region due to lagging policy frameworks and market designs. Consequently, hydropower resources alongside cross-border trading will bear most of the balancing responsibilities—heightening systemic risks during critical stress events similar to those experienced in recent years.
Network constraints further complicate these challenges as key flow corridors within the Western Balkans often face binding limitations under stress conditions. This results in local markets becoming isolated even when there is surplus capacity available regionally. The distinction between installed capacity and deliverable capacity becomes crucial; while aggregate reserve margins may appear adequate by 2030, actual accessibility and flexibility of that capacity are far more significant factors influencing market stability.
The increasing penetration of renewables suggests that volatility will become a structural feature rather than an exception within the Western Balkans’ energy landscape. As prices begin reflecting system tightness rather than just fuel costs, market coupling across borders will facilitate both relief and stress transmission throughout the region. Thus, integration efforts may not eliminate volatility but rather redefine its nature.
Ultimately, the Western Balkans stand at a crossroads as they navigate their energy transition amidst significant structural challenges. The interplay between their hydro assets, thermal legacy systems, and geographic positioning grants them substantial influence over regional balancing efforts while simultaneously exposing them to heightened risks if investments in flexibility and network enhancements do not keep pace with evolving demands. Without addressing these critical areas by 2030, electricity prices may increasingly reflect scarcity premiums rather than production costs—impacting industrial competitiveness and social policy throughout the region.
