Italy’s position as the largest net importer of electricity in Europe remained a defining feature of the South-East European (SEE) power market in Week 16, reinforcing its role as the primary price-setting anchor for the region.
With net imports exceeding 1,055 GWh during the week, Italy once again drew substantial volumes of electricity from neighbouring markets, maintaining a structural deficit that has persisted for years. This sustained demand for imported power exerts upward pressure on prices not only within Italy but across interconnected systems, effectively exporting its marginal cost structure into the broader SEE region.
Italian day-ahead prices averaged €123.19/MWh, the highest among all analysed markets, despite only a modest week-on-week increase. This stability at elevated levels reflects a market that is structurally tight, with limited flexibility to absorb shocks without significant price adjustments.
The roots of Italy’s import dependence lie in its generation mix. While the country has made significant investments in renewable energy, particularly solar, it remains heavily reliant on thermal generation—primarily gas-fired plants—to meet marginal demand. These plants, with higher operating costs compared to renewables, frequently set the clearing price in the market.
At the same time, Italy’s domestic generation capacity is insufficient to meet peak demand, particularly during periods of low renewable output. This creates a persistent need for imports, which are sourced primarily from neighbouring countries via a network of interconnectors linking Italy to France, Switzerland, Austria and Slovenia.
In Week 16, this dynamic was clearly visible. As demand increased—driven in part by a 6.35% week-on-week rise in consumption—Italy relied more heavily on imports to balance the system. This increased demand for cross-border power contributed to tightening conditions in neighbouring markets, as electricity was redirected toward higher-priced Italian zones.
The impact of Italy’s import demand extends beyond immediate neighbours. Through a chain of interconnected markets, price signals propagate across the region, influencing trading behaviour and generation decisions in SEE countries. For example, increased exports to Italy can reduce available supply in the Balkans, pushing up local prices even in markets that are not directly connected to Italy.
This phenomenon is particularly evident in the alignment of prices across Central Europe. As Italian demand pulls power westward, markets in Austria, Germany and beyond experience tighter conditions, which in turn affect SEE markets through further interconnections. The result is a highly integrated pricing structure, where local conditions are increasingly influenced by regional dynamics.
From a structural perspective, Italy’s role as a price anchor is unlikely to change in the near term. While renewable capacity is expected to continue growing, particularly in solar, the variability of these sources means that thermal generation will remain essential for system stability. Unless significant investments are made in storage or flexible capacity, Italy will continue to rely on imports to meet demand during critical periods.
This has important implications for SEE markets. Countries with surplus generation capacity—particularly those with strong renewable output—stand to benefit from exporting power to Italy at premium prices. However, this also exposes them to greater volatility, as domestic prices become linked to Italian market conditions.
For Serbia, the implications are particularly significant. As a system traditionally reliant on lignite generation, Serbia has relatively stable baseload capacity. However, during periods of high demand or reduced output, it may be forced to import power at elevated prices, particularly if regional supply is being drawn toward Italy.
Similarly, Bulgaria and Romania, which have more diversified generation mixes, must balance the opportunity to export with the need to maintain domestic supply security. In Week 16, both countries experienced increased price levels, partly reflecting their role in supplying power to higher-priced markets.
The role of interconnectors is again critical. Italy’s ability to import large volumes of electricity depends on the availability of transmission capacity. Congestion on these interconnectors can limit imports, leading to even higher domestic prices. Conversely, when capacity is available, it enables price convergence across regions.
From a trading perspective, Italy represents both an opportunity and a risk. The persistent price premium creates arbitrage opportunities, particularly for traders with access to cross-border capacity. However, the high level of integration also means that shocks in the Italian market can quickly propagate across the region, increasing overall volatility.
Looking ahead, several factors will influence Italy’s role in the regional market. The pace of renewable deployment, particularly offshore wind and large-scale solar, will determine how quickly the country can reduce its reliance on imports. At the same time, developments in energy storage—both batteries and pumped hydro—could enhance system flexibility, reducing the need for imports during peak periods.
Geopolitical factors will also play a role. Changes in gas supply dynamics, for example, could affect the cost structure of thermal generation, influencing price levels. Similarly, regulatory developments at the European level, including market design reforms, could alter the way prices are formed and transmitted across borders.
For now, however, the structural reality remains unchanged. Italy’s import dependence continues to anchor SEE power prices, shaping market dynamics across the region and reinforcing the importance of cross-border integration in determining electricity prices.
Week 16 provides a clear illustration of this dynamic in action. Despite falling gas prices and relatively modest demand growth, electricity prices remained elevated, driven in large part by Italy’s sustained import demand. This underscores the central role of structural factors in shaping market outcomes, and highlights the need for a regional perspective when analysing power markets in South-East Europe.