On March 31, 2026, power prices across South-East Europe saw a dramatic rise, reflecting a robust response to tightening system fundamentals and increased gas input costs. The surge in day-ahead prices marks one of the strongest coordinated increases observed in recent weeks, driven by heightened demand and shifting market dynamics.
Serbia’s SEEPEX exchange reported a notable increase in day-ahead baseload prices, clearing at €157.8/MWh, which represents an increase of €51.8 day-on-day. Hungary’s HUPX followed suit with prices climbing to €148.4/MWh (+€9.7). Romania and Bulgaria saw their prices converge around ~€141.2/MWh, each gaining between €6–8/MWh. Greece’s market rose to €133.8/MWh (+€15.8), while Albania recorded the highest price in the region at €188.1/MWh (+€45.8). Montenegro, despite being the lowest-priced market at €119.9/MWh, still experienced a significant daily increase of €18.2/MWh.
This price rally indicates a synchronized tightening across the South-East European market rather than isolated national trends, with cross-border flows and market coupling increasingly influencing price formation.
The latest data highlights a clear shift in regional consumption patterns, which reached 35.7 GW, rising by +584 MW day-on-day. Additionally, net imports increased to 2,009 MW (+408 MW), showcasing an enhanced reliance on external supply sources. Key inflows from Central European countries like Austria and Slovakia amounted to 4,133 MW, emphasizing their role in stabilizing demand within the SEE region.
The generation mix reveals ongoing cost pressures within the market. Gas-fired generation grew by +558 MW, solidifying its position as the marginal price-setting technology. Hydro output also increased by +670 MW, providing some relief but insufficient to counteract overall tightening conditions. Meanwhile, solar generation expanded by +459 MW; however, it failed to alleviate evening peak prices significantly. Coal production fell by -521 MW, reflecting both economic challenges and structural shifts amid high carbon pricing.
The intraday price profiles indicate pronounced evening peaks where hourly prices surpassed €230–270/MWh. Minimum price levels remained elevated above €100/MWh, suggesting that the system is operating under sustained stress rather than experiencing temporary volatility. This widening intraday spread underscores the increasing importance of flexible generation and energy storage solutions.
Cros-border flow data points towards a tightening regional dependency on imports, with strong inflows from Central Europe underpinning local prices. The spread between Hungary and Germany narrowed sharply to €30.6/MWh, decreasing by about €50/MWh day-on-day, indicating rapid convergence with core European markets.
This compression of spreads reduces arbitrage opportunities and suggests that SEE markets are becoming more integrated into larger continental pricing frameworks. However, such rapid convergence often precedes renewed volatility if underlying fundamentals diverge once again.
The bullish sentiment in fuel markets further supports this trend; Austrian CEGH gas prices hovered around €56.9/MWh, with EU carbon allowances continuing on an upward trajectory. While coal prices remain under pressure, the combined influence of gas and carbon costs continues to shape the marginal cost stack throughout the region.
Looking ahead, forward curves present a more complex picture as week-ahead power contracts indicated declines of nearly -10% in Hungary and around -20% in Germany. Gas forwards also softened by approximately 6–8%, suggesting that current spot strength may not translate into sustained forward pricing stability.
A significant regulatory development is on the horizon as Serbia’s SEEPEX exchange prepares for the introduction of negative pricing from May 2026, establishing a day-ahead floor of -€500/MWh and intraday limits reaching up to -€9,999/MWh. This move aligns Serbia with broader European market standards and is anticipated to heighten price volatility during periods characterized by high renewable output.
This transition introduces new complexities for market participants regarding risk management and trading strategies as negative pricing regimes typically enhance the value of flexible assets capable of rapid response, including battery storage and demand-side management initiatives.
The immediate future appears shaped by demand recovery alongside constrained baseload flexibility and elevated marginal costs tied to gas inputs. Although hydro conditions show improvement, they remain inadequate to alleviate systemic pressures significantly; variability in renewable output continues to exacerbate intraday volatility.
The current market phase is defined by an interplay between tightening spot fundamentals and softer forward expectations, where real-time system stress increasingly dictates price movements instead of long-term scarcity signals—resulting in sharp daily fluctuations and narrowing spreads sensitive to weather changes and cross-border flows.
The ongoing integration process with European markets and structural shifts such as negative pricing signal that South-East Europe’s power markets are entering a more intricate phase characterized by heightened volatility, flexibility demands, and strategic cross-border positioning essential for effective price formation.
