Southeast Europe’s electricity markets entered the first week of June with a clear split between tightening southern markets and softer Central SEE pricing, underlining how fragmented the region remains even when demand and fuel risks are moving in the same direction.
In Week 23, covering 1–7 June 2026, wholesale electricity prices rose most visibly in Bulgaria, where the weekly day-ahead average increased 7.8% week on week to €100.83/MWh. Italy remained the region’s premium market, rising 3.7% to €128.09/MWh, while Greece increased 2.9% to €89.25/MWh. The southern SEE price complex was therefore firmer, supported by higher regional demand, weaker variable renewables and tighter evening balancing conditions.
The opposite trend appeared in parts of Central and Western SEE. Serbia posted the sharpest decline, with the weekly average falling 5.8% to €99.63/MWh. Hungary slipped 2.0% to €103.15/MWh, Croatia declined 1.6% to €99.29/MWh, and Romania eased 1.2% to €102.23/MWh. These movements suggest that local supply conditions, hydro availability, cross-border import options and thermal dispatch patterns mattered more than any single regional price driver.
The regional ranking remained important for trading desks. Italy at €128.09/MWh stood well above the rest of the SEE pack, maintaining its structural premium because of its demand profile, import dependence and gas-linked marginal pricing. Hungary at €103.15/MWh, Romania at €102.23/MWh and Bulgaria at €100.83/MWh formed the middle price cluster. Serbia and Croatia traded just below the €100/MWh mark, while Greece at €89.25/MWh remained cheaper than most neighbouring markets.
The outlier was Türkiye, where the weekly average jumped from €4.03/MWh to €22.53/MWh, a percentage increase of 459%. But the move should not be read as price convergence. Turkish prices remained far below SEE levels and the weekly increase mainly reflected a rebound from an exceptionally low base in the previous week. Türkiye therefore stayed structurally disconnected from the rest of the regional price stack, even as its demand surged.
The daily pattern showed most SEE markets peaking on Monday, 1 June, while the lowest prices were generally recorded on Sunday, 7 June. That profile fits the usual combination of stronger weekday industrial and commercial load, weaker weekend demand and a more favourable renewable balance during lower-load periods. The hourly structure also showed the now familiar summer shape: lower midday prices where solar generation depresses residual demand, followed by a steep evening ramp when solar output fades and thermal or hydro units become more decisive.
For traders, the main lesson from Week 23 is that SEE price signals cannot be read only through demand or gas prices. Demand rose sharply at the regional level, but Serbia still softened. Gas prices remained elevated, but Italy’s premium was much stronger than Greece’s. Renewables fell across the region, but hydro recovery moderated prices in selected markets. This creates a trading environment where country-level fundamentals remain decisive.
The Italy–Greece spread is particularly relevant. Italy’s €128.09/MWh weekly average compared with Greece’s €89.25/MWh created a wide southern Europe differential, even though both markets recorded weekly price increases. This type of spread supports cross-border attention, hedging interest and regional arbitrage logic, especially where interconnection constraints determine whether lower-priced Balkan power can influence higher-priced Italian or Central European markets.
Serbia’s decline is also important because it came despite the broader regional demand increase. The Serbian market appears to have benefited from looser local marginal conditions, supported by improved hydro generation and higher domestic thermal availability. That made Serbia less exposed to the wider SEE bullish mix of demand growth and renewable weakness.
The Week 23 picture is therefore not one of a uniformly tighter region. It is a market map of divergence. Southern SEE strengthened, Italy remained expensive, Bulgaria moved above €100/MWh, Greece stayed relatively moderate, Türkiye remained structurally cheap, and Serbia weakened despite the regional rise in consumption. For market participants, that means location, interconnector access, hydro conditions and hourly profile remain more important than headline regional averages.
