The current energy shock is not unfolding evenly across Europe. In Southeast Europe, it is exposing a structural reality that had been partially masked during the post-2022 stabilization phase: the region remains deeply tied to imported hydrocarbons, constrained by uneven infrastructure, and now increasingly exposed to carbon-border pricing just as electricity market integration with the European Union accelerates.
The latest data shows the external trigger clearly. Brent crude surged to $118–119 per barrel, marking a 63% increase within March alone, while refined products such as diesel and jet fuel effectively doubled from the start of the year. At the same time, European gas prices have risen by more than 60% since the escalation of the Iran conflict, pushing retail fuel prices above €2 per litre in several markets.
For Southeast Europe, these numbers translate into something more acute than inflation. They feed directly into physical vulnerability. The region’s energy system still carries a high dependence on oil for transport and, in several countries, for residential heating. Public transport alternatives remain limited outside major urban centres, and electrification of heating is incomplete. The report explicitly highlights that Southeast Europe is structurally less able to absorb fuel shocks, with demand-side substitution significantly weaker than in Western Europe.
What follows is not simply a price adjustment. It is a compression of the entire regional energy system, forcing governments, utilities and traders to shift from optimisation to preservation.
Across the region, policy responses have already moved into emergency territory. Serbia has extended export restrictions on oil and petroleum products. Slovenia has prohibited diesel exports and temporarily suspended an emissions tax. North Macedonia has declared a 30-day energy emergencywhile cutting fuel VAT to 10% from 18%. Albania has reduced excise duties on petrol and diesel by 20%, while Greece has introduced a €300 million support package targeting households and agriculture. Romania is examining price caps and tax reductions.
These measures share a common logic. Governments are attempting to retain molecules within national systems, soften the transmission of global prices into domestic markets, and prevent social destabilisation. But they also reveal a deeper shift. Southeast Europe is no longer operating under a liberalised, price-clearing paradigm. It is moving into a constrained, security-driven operating mode where physical availability matters more than marginal pricing efficiency.
The gas market reinforces this shift. While the shock has originated in oil, its most persistent structural effect is likely to emerge through gas supply chains. The report highlights the strategic importance of the newly coordinated Vertical Corridor, linking Greece, Bulgaria, Romania, Moldova and Ukraine through the Trans-Balkan pipeline system. From the 2026–2027 gas year, this corridor will offer capacity products across multiple tenors with a unified tariff framework, effectively transforming it into a competitive and flexible supply route for Southeast and Central Europe.
This development carries significant implications. It marks a transition from static, contract-bound gas flows toward a more dynamic, market-responsive system. For Southeast Europe, diversification is no longer a long-term policy ambition but a short-term operational necessity. The countries that can access corridor flexibility and LNG-linked supply through Greece will be able to arbitrage disruptions more effectively. Those that remain dependent on rigid or politically exposed supply routes will face structurally higher volatility and cost.
Yet even as infrastructure improves, demand-side realities are moving in the opposite direction. High gas prices are already triggering substitution into coal across global markets, particularly in Asia, where coal maintains a 40–50% share of the generation mix and even higher levels in countries such as India. This global shift matters directly for Southeast Europe, not because the region is a primary coal consumer at Asian scale, but because it reinforces the persistence of coal as a marginal stabilising fuel in stressed systems.
Within Southeast Europe itself, coal has never fully exited the system. Lignite remains embedded in the generation mix of Serbia, Bosnia and Herzegovina, and North Macedonia. Under normal conditions, this creates tension with EU decarbonisation policy. Under crisis conditions, it becomes a strategic asset. The temporary suspension of emissions-related instruments in parts of the region, such as Slovenia’s emissions tax, signals a clear hierarchy shift: energy security is overriding carbon discipline in the short term.
At the European level, this tension is also visible. Policymakers are considering adjustments to emissions trading dynamics to reduce volatility, including mechanisms that allow excess allowances to accumulate and later return to the market. While framed as stability tools, such interventions carry the implicit risk of delaying emissions reductions.
This is where the Southeast European electricity market enters a new phase of complexity. The region is no longer isolated. Market integration with the EU is advancing, and with it, price formation, balancing rules and cross-border flows are increasingly aligned with the European internal electricity market.
The report notes that Serbia’s SEEPEX exchange is introducing negative pricing, with the floor moving to –€500/MWh, a technical change that reflects deeper structural alignment with EU markets.
At first glance, this is a sign of maturity. In reality, it is also a signal of exposure.
Because as Southeast Europe integrates into the EU electricity market, it simultaneously becomes subject to one of its most consequential new mechanisms: the Carbon Border Adjustment Mechanism.
The interaction between the current energy shock and CBAM is not linear. It creates a dual pressure on Southeast European electricity exports.
On one side, higher oil and gas prices lift wholesale electricity prices across Europe. This increases the nominal value of exportable power from the Western Balkans into neighbouring EU markets such as Hungary, Romania, Italy and Greece. Under purely economic logic, this should strengthen export incentives.
On the other side, CBAM introduces a carbon cost filter on those exports. Electricity generated from carbon-intensive sources—particularly lignite—faces an implicit or explicit carbon adjustment when entering the EU market. This compresses margins precisely at the moment when price signals would otherwise favour exports.
The result is a segmentation of the regional generation fleet.
Hydropower assets, which dominate in Albania and play a significant role in Montenegro and parts of Bosnia and Herzegovina, are structurally advantaged. They carry low carbon intensity and therefore minimal CBAM exposure. In a high-price environment, they can capture elevated revenues without incurring significant carbon costs.
Mixed systems, such as those combining hydro with thermal generation, face a more complex optimisation problem. Operators must decide when to dispatch carbon-intensive units for export and when to reserve cleaner capacity for cross-border flows.
Coal-heavy systems face the sharpest constraint. While they may have available generation capacity, their ability to monetise it in EU markets is increasingly limited by carbon pricing dynamics. The higher the share of lignite in the marginal megawatt-hour, the narrower the export margin becomes.
For Serbia, this dynamic is particularly important. The country is moving toward deeper market integration, as evidenced by exchange reforms and cross-border coupling ambitions. At the same time, its generation base still includes a significant lignite component. This creates a structural tension between market access and carbon exposure.
The consequence is that CBAM is no longer a distant regulatory issue. It is becoming embedded in dispatch decisions, trading strategies and forward hedging.
For traders, the implication is a shift from simple cross-border arbitrage to carbon-adjusted arbitrage. Power flows are no longer determined solely by price differentials but by the interaction between price, carbon intensity and regulatory treatment.
For utilities, the implication is capital allocation pressure. Investment in renewables, storage and flexible assets is no longer driven only by decarbonisation targets but by market access economics. The ability to export competitively into the EU increasingly depends on the carbon profile of the generation fleet.
For governments, the implication is strategic positioning. Southeast Europe’s role as a potential low-cost electricity exporter to the EU is being redefined. It is no longer sufficient to have surplus generation. That generation must also meet carbon constraints to remain commercially viable.
Overlaying all of this is the macroeconomic dimension. The energy shock is feeding directly into inflation, fiscal balances and sovereign risk. Eurozone borrowing costs have already risen sharply, with Italian 10-year yields reaching 4.14% and French yields approaching 3.9%, reflecting market concerns about the fiscal impact of energy support measures.
Southeast European economies, with more limited fiscal space, face an even tighter constraint. Subsidising energy consumption, supporting industry and maintaining social stability all require public spending at a time when borrowing costs are rising. This creates a feedback loop between energy markets and sovereign risk that is likely to remain a defining feature of the region over the coming quarters.
Taken together, the data points to a structural shift rather than a temporary disruption.
Southeast Europe is entering a phase where three forces intersect simultaneously. The first is a renewed dependence on hydrocarbons under constrained global supply conditions. The second is an accelerating integration into the EU electricity market. The third is the introduction of carbon-border pricing as a determinant of trade flows.
Individually, each of these forces is manageable. Combined, they reshape the region’s energy economics.
The countries and systems that can align low-carbon generation with flexible infrastructure and EU market access will capture disproportionate value. Those that remain reliant on carbon-intensive assets without adaptation will face narrowing margins and increasing policy pressure.
What began as a geopolitical oil and gas shock is therefore evolving into a deeper structural reordering of Southeast Europe’s energy system—one in which security, integration and carbon constraints are no longer separate variables, but parts of the same equation.
