On April 2, day-ahead electricity markets across Southeast Europe and Hungary experienced a significant correction, reversing gains from the previous session. This decline was influenced by improved cross-border electricity flows, enhanced renewable energy output, and softer gas prices, which collectively alleviated immediate system pressures. The reductions were widespread, with nearly all major markets showing double-digit price declines. Despite this temporary easing, the underlying market fundamentals indicate a continued structural tightness rather than a long-term bearish trend.
In Hungary, the HUPX market cleared at €135.80/MWh, reflecting a decrease of €18.5/MWh from the previous day. Romania’s OPCOM, Bulgaria’s IBEX, and Greece’s HENEX all settled at €136.58/MWh, each dropping approximately €18–20/MWh. Slovenia’s BSP fell to €133.91/MWh, Croatia’s CROPEX to €134.25/MWh, and Serbia’s SEEPEX recorded the steepest decline in the region at €132.32/MWh, down by €26.2/MWh. In contrast, Albania remained decoupled from the downward trend at €110.41/MWh, while Montenegro traded at a premium of €141.29/MWh due to local constraints.
The simultaneous nature of these price corrections suggests that they were driven by common regional factors rather than isolated market-specific events. A notable increase in net imports into the broader Southeast European system surged to 1,972 MW, up by 903 MW from the previous day. Additionally, core inflows into the Hungary-linked system rose to 3,442 MW, an increase of 770 MW. This influx of external supply diminished reliance on marginal thermal generation and facilitated a retracement of prices from previously elevated levels.
Renewable energy generation also saw improvements, particularly in wind power output which increased to 3,482 MW—up 227 MW day-on-day—while solar generation remained stable at 3,249 MW. Hydro generation rose slightly to 8,200 MW, contributing to the availability of non-thermal generation sources. Consequently, gas-fired plant output decreased to 5,416 MW—down 437 MW—while coal generation remained steady at 6,253 MW, providing essential baseload support.
Despite the observed price declines, the overall system did not achieve surplus status; total generation was recorded at 33,978 MW against consumption of 35,334 MW. This left a structural gap that continues to be filled by imports—a critical factor in understanding regional pricing behavior where even price corrections occur within a context of dependency on external supply.
Fuel markets contributed further downward pressure on power prices as Austrian CEGH gas traded at €50.76/MWh—down €4.5/MWh for the day—and forward gas contracts showed slight softening across the curve. Hungarian power forwards for Week 15 were assessed at €74.64/MWh with April 2026 contracts at €110.50/MWh and Cal-2026 at €112.50/MWh—all reflecting minor decreases compared to prior sessions.
Despite these corrections in prices and fuel costs, forward curves remain elevated compared to historical averages due to ongoing structural risks in the market environment. Geopolitical uncertainties—especially tensions in the Middle East—continue to impact gas pricing and subsequently affect power markets throughout Europe. The increase in Russian gas flows via TurkStream highlights Southeast Europe’s vulnerability to external supply shocks.
Intraday pricing data indicates that volatility persists within the market; peak-hour pricing across HUPX, BSP, and OPCOM exceeded €170–230/MWh during evening hours while midday prices softened due to increased solar generation output. This variability underscores a system increasingly influenced by renewable intermittency coupled with thermal constraints.
Serbia’s SEEPEX price of €132.32/MWh positioned it slightly below regional averages but still within a high-price range indicative of competitive conditions for the day. March trading volumes on SEEPEX reached 447,933 MWh with an average base price of €94.67/MWh—an increase of 38% month-on-month—highlighting that current price levels remain elevated despite daily fluctuations.
From a structural perspective, three key characteristics define the regional electricity system: import dependency with cross-border flows crucial for price formation; gas as the marginal price setter amid rising renewable capacity; and localized price divergences due to congestion and limited interconnection capacity—most notably seen in Montenegro’s premium pricing and Albania’s discounts.
The widening spread between Hungary and Germany prices (€21.76/MWh) emphasizes that Central Eastern Europe remains somewhat disconnected from Western European pricing dynamics due to transmission constraints and differing supply structures.
Looking forward, whether this recent price correction holds will depend on continued strong renewable output and stable import availability; however, any tightening in gas markets or reduction in cross-border flows could quickly reverse these trends.
The current market situation is best characterized as temporarily rebalanced within a structurally tight framework where volatility remains prevalent and price movements are primarily driven by short-term fluctuations in imports and fuel prices rather than an oversupply scenario.
