SEE power market snaps back after weaker Monday as wind dips and imports ease, but intraday swings stay the key risk

South-East Europe’s power market staged a clear rebound on April 7, with day-ahead prices moving back toward the mid-to-high €80s and low €90s per megawatt-hour after a weak Monday session. The move matters for investors because it shows how quickly the region reprices when renewable support fades and cross-border flows weaken—even though the overall picture still does not resemble a structurally tight, scarcity-driven market.

Prices converge across SEE, with Italy still setting the premium

Across the SEE complex, prices returned to the €85–96/MWh range. Hungary traded at €91.29/MWh, Romania at €87.93/MWh, Bulgaria at €84.58/MWh, Greece at €85.32/MWh, Slovenia at €89.92/MWh, Croatia at €90.31/MWh, Serbia at €90.42/MWh, Albania at €84.69/MWh and Montenegro at €95.84/MWh.

Italy remained the clear outlier at €127.92/MWh, continuing to act as the premium destination market for the broader SEE system. Within SEE itself, differentials versus Hungary narrowed almost everywhere—Romania was €3.35/MWh below HUPX, Bulgaria €6.71/MWh below, Greece €5.97/MWh below, Slovenia €1.37/MWh below, Croatia €0.97/MWh below and Serbia €0.87/MWh below.

This clustering suggests traders are dealing with an interconnected regional block rather than a set of disconnected national markets. For strategy design, that reduces the payoff from simple neighboring day-ahead arbitrage and shifts attention toward external edges of the system—especially Italy’s premium and the core import corridor into SEE.

Repricing driven by load recovery, cooler weather—and weaker imports

The rebound had a straightforward physical driver: forecast consumption rose to 29,759 MW on April 7, up 1,015 MW day on day, while average temperature fell to 10°C from 12.5°C (down 2.5°C). At the same time, total net imports into the SEE+Hungary system dropped to 1,002 MW—a decline of 1,545 MW—while core inflows from Austria and Slovakia eased to 2,627 MW (down 559 MW).

With import support weaker and demand higher, generation had to do more work domestically within the region. Total generation increased to 26,197 MW (up 776 MW), supported by hydro at 6,859 MW and nuclear at 5,807 MW alongside coal (4,843 MW), gas (2,502 MW) and solar (3,927 MW). The key shortfall came from wind: output fell to 1,892 MW (down 299 MW).

In trading terms, that combination removed part of the low-marginal-cost cushion just as load recovered—enough to reprice the whole complex higher.

Not a scarcity market: shoulder-season dynamics with renewable sensitivity

Despite higher prices versus Monday’s profile, April 7 does not look like a scarcity regime driven by persistent fuel shortages or sustained outage stress. Instead it resembles a shoulder-season environment where relatively small changes in renewable output and cross-border flows can swing prices sharply from one day to the next.

The power balance signals this clearly: imports stayed positive but at a much lower level than previously recorded sessions were able to support; internal generation stepped up accordingly.

Intraday volatility remains dominant despite calmer daily averages

The most important signal for risk management is not the daily average but the hourly shape of prices. In Hungary’s profile on April 7 there was still a minimum hourly price of -€12.5/MWh even as the daily baseload average recovered to €91.3/MWh and intraday maximum reached €181.1/MWh.

Similar swing patterns appear in Slovenia and Romania’s hourly charts as well. The implication is that SEE remains fundamentally split between weaker solar-heavy periods and more expensive evening ramp hours.

In this regime, flexibility becomes more valuable than flat baseload exposure: flexible hydro operations and portfolios with strong intraday execution—alongside batteries and peakers—are positioned to outperform strategies that assume stable spreads across hours.

Italy’s premium keeps transmission economics attractive

Italy continues to provide an external anchor for regional pricing discipline even when internal spreads compress. With Italy at €127.92/MWh on April 7—€36.64/MWh above Hungary—the Italian premium also widened versus Bulgaria (€?), Greece (€?), and Albania (as referenced in the source). That persistent pull supports southbound export economics from SEE toward Italy and helps sustain value for transmission capacity linking the region with its premium neighbor.

The practical takeaway is that upward repricing can occur quickly without any domestic supply shock because price formation reflects both local load/renewables conditions and continued strength in adjacent premium markets.

Forward indicators point to high costs without panic

Forward curves suggest an expensive but not crisis-like environment for thermal support inputs in coming weeks and months. Hungarian benchmark forwards were quoted at €99.50/MWh for Week 15 and €114.50/MWh for Week 16; May-26 traded at €97.50/MWh; Cal-26 was quoted at €113.50/MWh.

Gas prices cited include CEGH at €52.06/MWh and Greek gas at €51.5/MWh; EUA carbon was listed at €71.06/t. Coal forwards were $119/t for May-26 and $124.5/t for Q3-26.

Together with April’s observed hourly behavior—particularly during evening periods when renewables are weaker—the cost stack is high enough to keep thermal price support active without necessarily implying an emergency scarcity regime.

An integrated corridor market shifts opportunity toward balancing trades

The commercial flow information reinforces how integrated SEE has become operationally: flows across the Balkan corridor remain active in both base and peak structure rather than behaving like isolated national pools.

This matters for investors because it changes where directional bets are likely to be less efficient than corridor-based approaches focused on balancing exposure and monetizing flexibility across transmission-linked systems such as Serbia, Croatia, Slovenia, Bulgaria and Romania—where price formation increasingly reflects regional balancing conditions rather than purely domestic fundamentals.

What comes next: wind recovery versus continued import restraint

The near-term driver will be whether wind output recovers and whether inflows from Austria and Slovakia re-expand through subsequent sessions.

If both improve together, prices could soften back toward an indicated €75–85/MWh area fairly quickly—particularly during off-peak periods where renewable contribution typically matters most for marginal pricing dynamics.

If wind remains weak while reliance on internal thermal and hydro balancing increases further due to limited imports returning promptly, then today’s higher cluster around €85–95/MWh may prove sustainable.

Either way, April 7 highlights that SEE is best understood not as a one-directional high-price market but as a highly tradable volatility market where hourly profiles, interconnector access and flexibility deliver more reliable signals than outright baseload conviction alone.