SEE power prices jump as weekday demand returns; gas stays steady while spreads widen

The SEE power market reset higher at the start of the week—not because fuel costs suddenly ran away, but because system tightness and cross-border pricing links reasserted themselves. Gas remained comparatively stable, yet it continued to matter for marginal price formation through wider spark spreads as imports filled the gap.

The regional power market opened the week with a sharp upward reset, but the underlying drivers point less to structural tightening and more to a coordinated shift in demand, cross-border flows, and short-term system balance, with gas remaining stable but strategically decisive in marginal price formation.

Prices climb across day-ahead hubs; fragmentation persists

On 30 March, day-ahead electricity prices surged across SEE and Hungary. Hungarian HUPX cleared at €138.72/MWh, up €50.5/MWh day on day. Romania’s OPCOM reached €133.13/MWh, while Bulgaria’s IBEX settled at €134.57/MWh.

Slovenia and Croatia moved closely together at around €127/MWh, whereas Greece printed lower levels at €118.01/MWh. Serbia and Montenegro stayed structurally discounted: SEEPEX was at €105.95/MWh and BELEN at €101.77/MWh, underscoring persistent regional segmentation.

Italy again posted the premium benchmark at €151.03/MWh, reinforcing its role as the price ceiling for Central-South Europe.

Tighter balance lifts imports—especially north-to-south flows into Hungary

The immediate catalyst was a rebound in demand paired with a tighter physical balance. Regional consumption increased to 34,648 MW, up 2,285 MW, while total generation fell to 30,758 MW. That combination pushed the region toward greater reliance on external supply.

Net imports stood at 1,584 MW. Core flows into the region—Austria plus Slovakia into Hungary and Slovenia—rose to 3,890 MW, signaling strong dependency on north-to-south transfers when domestic output softens.

Spark-spread logic: gas is steady, margins widen where interconnection matters most

A key element behind how prices formed was the expansion of the HU-DE spread. It widened to €80.28/MWh, up €58/MWh day on day. In practical terms, this spread effectively priced the marginal cost of importing electricity into Hungary from Western Europe—setting direction for much of the SEE corridor.

Once Hungary cleared at elevated levels, downstream markets such as Romania, Bulgaria and Slovenia followed. By contrast, systems like Serbia and Montenegro lagged due to local generation buffers and weaker interconnection liquidity.

The generation mix supported that import-and-flexibility narrative. Hydro output dropped by 416 MW, coal by 494 MW, and gas generation by 710 MW, removing balancing capacity from the system even as wind increased by 624 MW. Solar was comparatively flat. Nuclear held steady at 5,913 MW, providing baseline stability without driving marginal pricing higher on its own.

Gas anchors thermal marginal costs even during non-surge fuel conditions

While gas was not described as the primary trigger for the daily spike in itself, it remained critical for setting marginal economics within thermal units. Austrian CEGH gas traded at