Italy’s preliminary agreement with the European Commission on measures to limit the effect of high gas costs on electricity prices could alter trading economics across Southeast Europe. The intervention may create a new source of basis risk for exporters, generators and lenders whose revenue assumptions rely on Italy maintaining a premium over neighbouring regional electricity markets. The measures are not yet in force: Italy must formally notify them under EU state-aid rules, and their technical implementation remains subject to regulatory decisions.
Italian measures target gas-driven power prices
Rome and Brussels reached the preliminary agreement on October 16. It covers temporary measures intended to reduce the impact of expensive gas on electricity prices for households and businesses. The mechanism is expected to compensate eligible gas-fired generators for part of their elevated fuel costs when gas prices exceed a defined threshold.
By reducing the marginal cost that would otherwise feed into wholesale electricity prices, the mechanism could affect price formation in Italy. Italy is one of Europe’s most gas-dependent large electricity markets, where expensive gas frequently sets the marginal power price. Historically, this has allowed Italian wholesale prices to trade at substantial premiums to markets elsewhere in Europe and Southeast Europe.
Electricity from Montenegro, Slovenia, Greece and the wider Balkan region can gain additional value when Italian prices rise far enough above domestic or regional prices to justify cross-border exports. An intervention intended to compress Italy’s gas-driven power prices could therefore change export economics beyond Italy. The immediate concern is not that electricity exports will disappear, but that the Italian premium may become less predictable.
Price spreads create new hedging exposure
A generator may forecast merchant revenues on the assumption that Italian prices will remain structurally above neighbouring markets because gas generation continues to set the marginal price. If the intervention narrows that premium during periods of expensive gas, the export value of the same MWh could fall. This matters particularly for projects that rely partly on merchant revenues after fixed-price contracts expire.
Cross-border traders also face exposure when holding positions between Italy and Southeast European markets. They must forecast prices in the exporting market and in Italy, as well as available cross-border capacity and the cost of securing it. A government measure affecting only the Italian side changes the relationship between these variables, creating what is effectively policy-driven basis risk.
A hedge could perform as specified in its contract yet no longer offset the physical position as intended. For example, a Southeast European generator may hedge part of its future revenue against an Italian electricity benchmark. If the mechanism suppresses Italian prices while the generator’s domestic market remains exposed to fuel, scarcity and balancing conditions, the historical correlation between the markets may weaken.
In that case, the hedge may protect the wrong price relationship. Cross-border transmission rights do not resolve this risk: they can protect or monetise elements of congestion exposure, but cannot guarantee that the spread remains economically attractive. Traders with positions established before the policy was known could also face mismatches between physical and financial exposure if Italian spot prices fall relative to earlier expectations.
Export links and project revenues
The issue has particular relevance for Montenegro, whose submarine link with Italy provides direct access to the Italian market. The cable has strengthened Montenegro’s strategic position as a transit and export market, and generators and traders can compare opportunities across domestic, regional and Italian prices. If Italian electricity prices are structurally reduced during high-gas periods, the economics of westward exports could change.
The same principle applies to Greece and Slovenia, which are both directly connected to Italy. Croatia and other Balkan markets may be affected indirectly because power flows respond to relative regional prices rather than national boundaries alone. A weaker pull from Italy could change where regional surplus generation ultimately goes.
The effects also reach project finance. Banks financing merchant or partly merchant renewable assets typically use long-term assumptions about power prices and market relationships. A Southeast European project may derive part of its expected value from the ability to export to higher-priced markets; if government intervention changes those relationships, lenders may place less weight on historical spreads.
Lenders may instead use more conservative assumptions for cross-border merchant revenues, increasing the value of fixed-price contracts, floor structures and other forms of revenue protection. The issue may also affect acquisitions: infrastructure investors often value operating renewable portfolios using forecasts that extend 20 years or more. Those valuations include assumptions about electricity-market coupling and price convergence.
Trading, generation and regulatory considerations
A major neighbouring market’s ability to temporarily alter the relationship between gas and electricity prices adds another variable to long-term models. Future due diligence may therefore need to include policy-adjusted power-price scenarios alongside conventional commodity forecasts. For traders, changes in cross-border spreads can become a liquidity concern as well as a pricing one.
Collateral requirements can amplify the effects of a hedge moving sharply against a trader. The position may require cash margin even if the physical electricity exposure ultimately generates offsetting value. Policy-driven spread changes can therefore create liquidity pressure before any offsetting physical value is realised.
The mechanism could also affect generation behaviour in Italy. Compensating gas-fired plants for part of their fuel costs may change their bidding economics and potentially make them more competitive than imports in certain periods. The precise effect will depend on the final design, including the activation threshold, eligible volumes, funding structure and safeguards against overcompensation.
Those details remain material, and Italy and the European Commission have stressed that the measure must preserve the EU internal market and minimise competitive distortions. The final mechanism cannot simply isolate Italy from neighbouring markets without consequences for European market rules, so the intervention remains an emerging risk rather than an established new price regime. For Southeast European exporters, traders and banks, Italian power prices can no longer be modelled solely as a mechanical function of gas, carbon and power-system fundamentals: policy is another variable in the spread.
The question is not only whether Italian electricity prices will remain higher than Balkan prices, but whether the premium will remain available to the market or governments will increasingly intervene when it becomes politically unacceptable. That distinction could reshape how Southeast European export revenues are hedged, financed and valued.