Italian day-ahead prices and regional spreads
In the week to 20 September, Italy remained Southeast Europe’s highest-priced power market. Italian day-ahead power averaged €215.82/MWh, up 2.51% on the week. The level was about €60/MWh above Greece and €34/MWh above Hungary.
Alongside the price premium, Italy’s position as a net importer persisted in the markets covered. Net imports were recorded at 926.37 GWh, even though import volumes fell by 17.77%. This combination kept Italy’s price signal relevant for cross-border trading.
Demand decline and changes in thermal output
Electricity demand in Italy dropped by 9.21% to 5,391.13 GWh. The report cited this as the largest absolute reduction among the countries included. Italian gas-fired generation also fell by 10.86%.
The decline in gas generation contributed to an 8.87% drop in total thermal output. With consumption lower and imports reduced, the weekly pattern still reflected a sustained gap between Italian pricing and neighbouring markets.
Import incentives and the role of physical delivery conditions
The interaction between high prices and lower import volumes was linked to how regional comparisons translate into physical flows. A neighbouring producer may see an attractive Italian price, but deliverable volumes depend on interconnector availability and hourly market conditions.
For each hour, delivery also reflects the producer’s domestic needs, which can affect how much power is available for export despite price spreads.
Trading margins at the border and hour of delivery
Italy’s premium remained substantial through a period of weaker demand. For Southeast European exporters, access to the Italian market was described as commercially valuable under these conditions.
The realised trading margin is settled at the border and hour of delivery, aligning commercial outcomes with physical scheduling constraints . By Virtu.Energy
