The energy markets in Central and Southeast Europe experienced a notable shift on March 3, 2026, characterized by a significant price spike following a period of weekend compression. Prior to this spike, day-ahead markets across the region exhibited stable trading conditions, with many exchanges recording base prices below €60/MWh on Sunday. Factors such as moderate wind output and subdued solar generation contributed to this stability, resulting in low volatility and incremental adjustments in forward curves.
However, the landscape changed dramatically by Tuesday’s settlement. The Hungarian Power Exchange (HUPX) cleared at €114.99/MWh, while the Romanian OPCOM and Spanish IBEX both settled at €115.33/MWh. The Serbian SEEPEX recorded a clearance of €107.65/MWh, with the Bulgarian BSP at €109.53/MWh. This synchronized upward adjustment across multiple exchanges was indicative of a regional repricing influenced by gas market dynamics, particularly the surge in TTF gas prices.
The repricing can be understood through three key phases that highlight the market’s reaction to changing conditions. Initially, during late February, typical late-winter dynamics saw demand soften and solar generation create price troughs during midday hours. This resulted in base prices fluctuating between the high €50s and low €90s across several markets. The compression observed during this period led market participants to lower their risk appetite and expectations for intraday price movements.
As wind generation began to weaken leading into March 3, the market appeared balanced despite some thermal dispatch not being under stress. However, the sudden increase in gas prices shifted the marginal cost curve significantly before many traders could adjust their positions adequately.
When TTF prices surged toward €48/MWh, this recalibrated gas plant bids for day-ahead auctions across the region. Combined-cycle plants adjusted their offers based on increased fuel costs as well as carbon pricing and operational margins. This upward shift quickly propagated through clearing prices due to gas units frequently setting the marginal unit during evening demand ramps in Hungary and surrounding countries.
The most pronounced aspect of March 3 was the concentration of extreme prices during peak evening hours, where hourly rates exceeded €220/MWh in Hungary and Romania between H19–H20. The evening ramps are particularly vulnerable due to declining solar output combined with sustained demand levels, which necessitate increased reliance on thermal flexibility for supply.
Regional coupling played a significant role in this repricing event as Hungary serves as a liquidity hub connecting various neighboring markets including Austria, Slovakia, Romania, Croatia, and Serbia. Consequently, when HUPX cleared above €110/MWh, it set off similar movements across these interconnected markets with Romania and Bulgaria following closely behind.
Interestingly, despite the price surge, imports into Hungary from Austria and Slovakia decreased significantly to approximately 1,012 MW on that day. This reduction indicates that internal marginal cost escalations were primarily responsible for the repricing rather than a scarcity of imports from neighboring regions.
The overall market behavior reflects a transition from compression to expansion amid rising volatility expectations due to surging gas prices. Contracts for Week 11 across Germany, Italy, and Hungary saw double-digit percentage increases as traders anticipated prolonged elevated spot volatility beyond just one session.
As Europe entered March with gas storage levels around 30 percent full amidst critical LNG flows, any supply shocks from major exporters could reintroduce geopolitical premiums into the market dynamics of Southeast Europe. The events surrounding March 3 serve as an important reminder that beneath periods of compressed volatility lies a system still highly susceptible to fluctuations driven by gas input costs.
