During the week of March 23-29, 2023, electricity prices across Southeast Europe exhibited a slight decline, reflecting ongoing market volatility rather than a fundamental shift. The regional pricing environment remains tight, with various factors influencing the dynamics of supply and demand.
In this period, day-ahead baseload prices showed modest reductions. Greece’s average price fell to €96.75/MWh, marking a decrease of 3.55% week-on-week. Bulgaria experienced a similar trend with a 2.33% drop, while Serbia saw a more significant correction, dropping to €93.02/MWh, which represents a 4.83% decrease. Italy, maintaining its role as the premium market in Southern Europe, recorded a notable decline of 7.22%, settling at €138.28/MWh, still considerably higher than its SEE neighbors.
The primary factor contributing to this week’s price adjustments was the fluctuation in European gas markets. Front-month futures for TTF gas decreased from levels above €56/MWh to the range of €52–54/MWh, which subsequently lowered marginal costs for gas-fired electricity generation. Given that gas prices significantly influence the marginal cost structure across much of SEE, even minor changes in TTF pricing can have swift repercussions on electricity prices.
Despite these reductions, the overall decrease in power prices remained limited. Market participants identified persistent geopolitical risks as a capping factor, particularly related to tensions between the United States and Iran. Even though there were signs of potential de-escalation, the market continues to account for possible supply disruptions that could affect LNG flows through critical maritime routes such as the Strait of Hormuz.
This situation has led traders to characterize the current market as a “compressed downside environment.” While short-term factors like reduced gas prices or improved renewable energy output may lead to some price easing, corrections are generally constrained in both scale and duration. Forward price curves indicate this asymmetry, remaining elevated and relatively stable for Q2 delivery periods.
In contrast to regional trends, Türkiye experienced an uptick in electricity prices by 9.52%, driven largely by increased domestic demand for electricity. This divergence highlights how local market fundamentals can significantly influence pricing dynamics, even within broader regional contexts.
The overall pricing landscape in SEE remains firmly elevated, with most markets trading within a range of €90–120/MWh, notably above historical averages for late March. This indicates that while volatility persists, the market operates at a higher equilibrium level compared to pre-crisis years.
A notable aspect of the current market is the ongoing convergence pressures among interconnected systems. Although price spreads between countries have narrowed slightly, full convergence is hampered by grid bottlenecks and differences in generation mixes along with varying import dependencies.
The developments observed during calendar week 13 illustrate that Southeast European electricity markets are influenced by multiple interrelated factors rather than being driven by a single dominant element. The interplay between gas prices, renewable energy output, hydrological conditions, and geopolitical events shapes the current landscape. While gas continues to serve as a foundational element in pricing dynamics, its impact is increasingly moderated by system flexibility and cross-border energy flows.
Looking forward, traders anticipate continued volatility without clear directional trends. Although short-term corrections are likely to persist due to fluctuating conditions, the structural tightness of the market—coupled with external risk factors—suggests that prices will remain supported during times of heightened demand or diminished renewable energy generation.
