Italy’s proposed measures to curb the effect of high gas costs on electricity prices could change cross-border trading economics in Southeast Europe, adding basis risk for exporters, generators and lenders. Their revenue assumptions may depend on Italy maintaining a premium over neighbouring electricity markets.
Rome and Brussels reached a preliminary agreement on October 16 on temporary measures intended to limit the impact of expensive gas on electricity bills for households and businesses. The mechanism is expected to compensate eligible gas-fired generators for part of their higher fuel costs when gas prices exceed a defined threshold. This would reduce the marginal cost otherwise reflected in wholesale electricity prices.
Italy must formally notify the measures under EU state-aid rules, and regulatory decisions are still needed on the technical implementation. The final arrangements have therefore not been settled. Even so, the proposed direction is commercially significant.
Italy is one of Europe’s large electricity markets most dependent on gas, which frequently sets its marginal power price. As a result, Italian wholesale prices have historically traded at substantial premiums to markets elsewhere in Europe and Southeast Europe. Electricity from Montenegro, Slovenia, Greece and the wider Balkan region can become more valuable when Italian prices are high enough to justify cross-border exports.
Price spreads and export revenues
Measures aimed specifically at compressing Italy’s gas-driven power prices could change the economics for exporters across the border. The immediate concern is not that electricity exports will stop, but that the Italian premium may become less predictable. A generator’s merchant-revenue forecast may assume that Italian prices remain structurally higher because gas generation continues to set the marginal price.
If the intervention reduces that premium during periods of high gas prices, the export value of the same MWh could fall. This is particularly relevant to projects that rely partly on merchant revenues after fixed-price contracts expire. Traders with positions linking Italy and Southeast European markets could also be affected.
Cross-border trades involve several exposures: the price in the exporting market, the Italian price, available transmission capacity and the cost of securing it. An intervention affecting only the Italian side changes the relationship between those variables. It creates a form of policy-driven basis risk, in which a hedge can perform according to its contract but no longer offset the physical position as intended.
For example, a Southeast European generator could hedge part of its future revenue against an Italian electricity benchmark. If policy subsequently suppresses Italian prices while the generator’s domestic market remains exposed to fuel costs, scarcity and balancing conditions, the markets’ historical correlation may weaken. The hedge could then protect against the wrong price relationship.
Transmission links and financing assumptions
Cross-border transmission rights do not remove this risk. They can protect or monetise aspects of congestion exposure, but cannot guarantee that the price spread remains economically attractive. For Montenegro, the issue is especially relevant because its 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, allowing generators and traders to compare opportunities across domestic, regional and Italian prices. If Italian power prices are structurally lower during high-gas periods, the economics of westward exports could change. Greece and Slovenia, which are also directly connected to Italy, face the same principle.
The effect can reach Croatia and other Balkan markets indirectly because power flows respond to relative regional prices, not national boundaries alone. Weaker Italian demand for imports could influence where regional surplus generation ultimately goes. The implications also extend to project finance.
Banks financing merchant or partly merchant renewable assets generally use long-term assumptions about power prices and market relationships. A Southeast European project may derive some expected value from exporting to higher-priced markets. If government intervention alters those relationships, lenders may rely less on historical spreads and require more conservative assumptions for cross-border merchant revenues.
That could increase the value of fixed-price contracts, floor structures and other forms of revenue protection. The issue may also affect acquisitions, as infrastructure investors often value operating renewable portfolios using forecasts covering 20 years or more. Those valuations include assumptions about electricity-market coupling and price convergence.
A policy that allows a major neighbouring market to temporarily change the link between gas and electricity prices adds another variable to valuation models. Future due diligence may therefore need to include policy-adjusted power-price scenarios alongside conventional commodity forecasts.
Trading exposure and the final mechanism
Electricity traders face a more immediate challenge. If Italian spot prices fall below earlier expectations after forward positions were established, portfolios could develop mismatches between physical and financial exposure. Collateral requirements can magnify the impact, as a hedge moving sharply against a trader may require cash margin even when the physical position ultimately generates offsetting value.
Changes in cross-border spreads driven by policy can therefore create a liquidity issue as well as a pricing risk. The mechanism could also influence generation behaviour within Italy. Partial compensation for gas-fired plants’ fuel costs may alter their bidding economics and make them more competitive with imports during some periods.
The precise impact will depend on the final design, including the activation threshold, eligible volumes, funding structure and safeguards against overcompensation. Italy and the European Commission have stressed that the measure must preserve the EU internal market and minimise competitive distortions. It cannot simply isolate Italy from neighbouring markets without implications for European market rules.
The intervention should therefore be treated as an emerging risk, not as an established new price regime. For Southeast Europe, the proposed measures underline that Italian electricity prices cannot be modelled solely as a mechanical result of gas, carbon and power-system fundamentals. Policy has become another variable in the spread.
For exporters, traders and banks, the question is not only whether Italian prices will remain above Balkan prices, but whether the market will continue to capture that premium. Governments may intervene when it becomes politically unacceptable. That distinction could reshape how Southeast European export revenues are hedged, financed and valued.
