The 24 April trading session across SEE developed into a textbook example of structural fragmentation inside a physically connected market: headline convergence through interconnections continues, but real pricing power is increasingly dictated by intraday generation mix, cross-border constraints, and flexibility scarcity.
Starting with the price layer, Hungary again anchored the region at €98.21/MWh, gaining +€5.1/MWh day on day, while the rest of SEE diverged materially. Romania followed at €89.66/MWh (+€1.3), Slovenia at €80.44/MWh (+€5.8) and Croatia at €83.04/MWh (+€5.7), confirming the Central European coupling effect. By contrast, Bulgaria (€77.63/MWh, −€10.1), Greece (€76.59/MWh, −€11.5), Serbia (€65.39/MWh, −€0.6), Montenegro (€64.77/MWh, −€9.0), Albania (€61.28/MWh, −€9.7) and North Macedonia (€65.19/MWh, −€4.4) all corrected sharply downward, widening spreads to Hungary into the €30–35/MWh range.
This divergence is not demand-driven. Regional consumption rose only modestly to 29,828 MW (+334 MW), which is insufficient to justify such a spread. The real driver sits in the supply stack and system balance.
Wind generation surged to 3,127 MW (+1,217 MW), one of the strongest day-on-day increases in recent sessions. Solar remained elevated at 3,776 MW, only slightly down (−151 MW), still exerting downward pressure during daylight hours. At the same time, hydro output dropped sharply to 6,291 MW (−839 MW), while gas-fired generation fell to 2,829 MW (−710 MW). Coal remained broadly stable at ~4,940 MW, and nuclear steady at ~5,724 MW.
What emerges is a classic spring profile: strong intermittent generation suppressing prices in the periphery, while reduced hydro and gas tighten flexibility in core markets. This is why Hungary holds premium pricing—its system is balancing imported power, reduced dispatchable flexibility, and still relatively firm residual demand.
Cross-border flows reinforce this picture. Total net imports into the region reached 1,423 MW (+54 MW), while “core” imports (Austria + Slovakia toward Hungary/SEE) stood at 2,575 MW (+20 MW). The HU-DE spread narrowed to €22.1/MWh, but remains structurally wide enough to keep flows directed into Hungary.
However, internal SEE flows tell a different story. According to the commercial flow matrix (page 7), strong north-to-south and east-to-west exchanges persist, but they are not sufficient to equalize prices. Structural bottlenecks—particularly on Serbia–Bosnia, Montenegro–Albania and Bulgaria–Greece corridors—continue to isolate surplus RES zones. This creates localized price depression despite regional import dependency.
Intraday dynamics confirm the same pattern. The hourly price curves (page 4 and 14) show deep midday price compression across all SEE markets, with negative or near-zero prices appearing in several hubs during solar peaks (Hungary minimum at −€36.4/MWh, Slovenia −€30/MWh, Greece −€14.5/MWh). Evening hours then spike sharply, with peak-hour prices reaching €277–280/MWh in Hungary and €180–200/MWh across SEE.
This volatility is now the dominant feature of the market. Baseload averages hide the real value shift, which is moving decisively toward flexibility products.
On the forward side, energy commodities remain supportive. Gas at CEGH traded at €46.33/MWh (+€1.4), coal around €105.5/t for May-26 (+€2.0), and EUA carbon at roughly €70–80/t equivalent trajectory, all trending upward. Power forwards for Hungary moved to €101.5/MWh (WK19) and €103.5/MWh (May-26), indicating that the market is pricing continued tightness despite current renewable-driven softness.
The structural takeaway is that the SEE market is no longer a single price zone with minor deviations—it is evolving into a layered system. Hungary acts as a pricing hub tied to Central Europe. Romania operates as a semi-core balancing market. The Western Balkans—Serbia, Montenegro, Albania, North Macedonia—form a structurally discounted zone, where high renewable penetration, weaker interconnection capacity, and limited storage suppress prices.
For traders and asset owners, the implication is that value extraction is shifting away from simple baseload arbitrage. The margin now sits in capturing spreads—both cross-border and intraday. Battery storage, pumped hydro (notably projects like Bistrica in Serbia), and flexible gas or hybrid RES assets become critical. Without flexibility, producers are increasingly exposed to midday price collapse.
At the same time, the persistence of €30+/MWh spreads within a coupled region signals that transmission infrastructure—especially 400 kV corridors such as the Trans-Balkan route—remains the single most powerful value unlock in the system. Until those constraints ease, SEE will continue to trade as two markets: a premium core and a discounted periphery, connected physically but not yet economically aligned.
