In Southeast Europe’s Week 22, Türkiye stood out as the dominant outlier as average day-ahead electricity prices fell by more than 73% to €4.03/MWh. Other markets in the regional sample did not show comparable declines. Greece averaged €86.77/MWh, Bulgaria €93.50/MWh, Serbia €105.71/MWh, and Italy €123.58/MWh. The Turkish price level therefore did not function as a normal regional price signal.
The week’s pricing pattern was linked to Türkiye operating under conditions described as fundamentally different from the rest of the region. As reported by Electricity.trade, Türkiye’s ultra-low price week highlighted the limits of SEE market convergence. Cheap electricity in one large market does not automatically transmit across the region .
Demand drop and thermal output contraction in Türkiye
The price collapse coincided with a sharp fall in demand in Türkiye. Turkish electricity consumption declined by 21.7%, equivalent to 1.38 TWh. This reduction exceeded the entire net decrease in SEE demand during the same period. Thermal generation fell by 41.4%, including a 70.6% drop in gas-fired output.
Alongside weaker domestic demand, Türkiye increased exports substantially. Its export position nearly tripled to 95 GWh. The combination of surplus low-cost supply and reduced need for expensive thermal dispatch was reflected in the observed pricing outcomes .
Regional price effects constrained by interconnection and market rules
The commercial question raised by the data is why Türkiye’s low prices did not pull other SEE markets down more aggressively. The explanation provided is that physical and institutional limits of market integration restrict transmission of a single low-price zone across borders. These limits include interconnection capacity, scheduling rules, domestic market arrangements and congestion.
Even with Türkiye clearing near €4.03/MWh, other markets still cleared at much higher levels. Italy continued to clear at €123.58/MWh. Serbia rose to €105.71/MWh, while Bulgaria softened materially but remained above €90/MWh. The Turkish low-price signal was therefore described as powerful but geographically contained.
Trading implications for spreads and capacity availability
For traders, the juxtaposition of Türkiye’s €4.03/MWh price against markets above €90/MWh implies large theoretical spreads. However, converting those spreads into revenue depends on whether capacity is physically available and commercially tradable. Regional power trading is therefore constrained not only by price levels but also by infrastructure and market access .
Investor risk considerations tied to demand and export depth
The Week 22 pricing outcome also points to risks for investors in systems with high renewable penetration or low demand when export depth or flexible demand is insufficient. Ultra-low prices may benefit consumers, but they can weaken merchant revenue for generators during periods when supply conditions shift sharply.
In markets with growing renewables, price collapses can become more frequent unless storage, demand response, interconnection and flexible industrial load expand fast enough . Within this context, Türkiye’s Week 22 day-ahead price of €4.03/MWh was presented as a marker of fragmented convergence rather than a simple anomaly.
Southeast Europe may share more data, flows and trading links than before, but the region still contains price islands according to the reported assessment . When one island clears near zero while neighbours remain above €100/MWh, the commercial value of interconnection becomes difficult to realize.
