Calendar week 13 highlighted a growing structural divergence within European electricity markets, with sharply falling prices in Western Europe—particularly the Iberian Peninsula—contrasting with the relatively stable and elevated pricing environment across South-East Europe.
Spain and Portugal recorded the most dramatic movements, with weekly average prices collapsing by nearly 50%, driven by exceptionally strong renewable generation, particularly wind and solar. These conditions pushed prices to unusually low levels and reinforced the Iberian Peninsula’s increasingly distinct market dynamics.
In contrast, SEE markets experienced only moderate declines, generally within the 1–5% range, underscoring their continued reliance on gas-fired marginal generation. While renewable output did increase across the region, it was neither sufficient nor consistent enough to decouple pricing from gas markets in the same way observed in Iberia.
Central European markets also posted notable declines, with Germany falling by 16.94%, the Netherlands by 13.86%, and Poland by 14.24%. These movements were similarly driven by strong wind generation and lower demand conditions. However, even within Central Europe, the extent of price reductions varied depending on local generation mix and interconnection capacity.
France emerged as a major outlier, with prices surging by 37.95%. The increase was widely attributed to nuclear availability constraints and tighter system margins, highlighting the continued sensitivity of the French market to changes in nuclear output.
The divergence between regions is increasingly structural rather than cyclical. Western European markets, particularly those with high renewable penetration, are experiencing growing periods of low or even negative prices during times of strong generation. Meanwhile, SEE markets remain anchored to fossil fuel costs, particularly gas, due to lower renewable penetration and more limited system flexibility.
Interconnection capacity plays a critical role in reinforcing this segmentation. Although cross-border flows between Central and South-East Europe have increased, they remain insufficient to fully arbitrage price differences. As a result, surplus renewable generation in Western Europe cannot be efficiently transmitted to SEE markets, leaving the latter exposed to higher marginal costs.
This dynamic creates both challenges and opportunities for market participants. On one hand, the lack of convergence limits efficiency and increases volatility. On the other hand, it opens up arbitrage opportunities for traders able to navigate cross-border capacity constraints and transmission pricing mechanisms.
Another important factor is the role of demand. While Western Europe benefited from relatively mild weather conditions and lower consumption, demand in parts of SEE remained more stable, further supporting prices.
The divergence also has implications for forward markets. While Western European contracts have shown greater sensitivity to renewable forecasts, SEE forward curves remain closely linked to gas price expectations. This reinforces the importance of gas market developments in shaping the outlook for the region.
In structural terms, the European electricity market is evolving into a multi-speed system. Regions with high renewable penetration and strong interconnections are increasingly driven by weather patterns, while those with lower flexibility remain tied to fossil fuel costs.
For SEE, this means that price convergence with Western Europe is likely to remain limited in the near term. Instead, the region will continue to operate within its own pricing framework, influenced primarily by gas markets, hydrological conditions, and regional demand patterns.
