CBAM and EU ETS volatility are reshaping cross-border power trading in Southeast Europe

Integrating CBAM into Southeast Europe’s electricity markets has changed more than the cost of moving power across borders. It has effectively connected regional power pricing to the European carbon market, accelerating the financialisation of electricity trade by embedding EU ETS price volatility into day-to-day trading and hedging decisions.

CBAM turns EU ETS moves into an import cost benchmark

In Q1 2026, the linkage became operational reality: the cost of electricity imports into the European Union was directly tied to the EU Emissions Trading System. For electricity imports, CBAM certificate costs are calculated using the quarterly weighted average price of EU ETS allowances. In Q1 2026, that benchmark was €75.36 per tonne of CO₂, creating a clear and quantifiable reference point for carbon costs applied at the border.

This design means that changes in EU ETS immediately flow through to cross-border electricity trade costs. Carbon price dynamics—previously a factor for EU member states—are now transmitted directly to non-EU market transactions involving exports into the EU.

From physical drivers to hybrid power–carbon pricing

The shift alters what drives electricity prices in Southeast Europe. Historically, regional power markets were shaped mainly by physical variables such as fuel costs, hydrology, demand patterns and network constraints. With CBAM making carbon costs a direct component of cross-border transactions, imports from systems with different emission intensities are priced not only on generation costs but also on exporting-system carbon intensity and prevailing EU ETS prices.

As a result, market participants are no longer trading electricity alone; they are implicitly trading carbon exposure. A coal-heavy exporting system carries a carbon liability that must be priced and managed through CBAM certificates—creating a tighter connection between power trading desks and carbon risk management.

Q1 2026 highlights how carbon volatility can disrupt trading economics

The implications were visible in Q1 2026 when EU ETS prices declined notably between mid-January and the end of March. The article attributes this decline partly to political discussions around potential reforms to the emissions trading system. Whatever the underlying drivers, that volatility translated into fluctuations in CBAM-related costs on a near real-time basis.

For traders and utilities, this introduces a new layer of uncertainty. Strategies that previously relied on relatively stable relationships between fuel costs and electricity prices now have to incorporate the inherently volatile nature of carbon markets.

Hedging, forward markets and arbitrage start to change

The financialisation shows up in multiple ways. First, it increases the importance of hedging strategies that account for both electricity price risk and expected EU ETS price movements between trade execution and certificate surrender. The article suggests this could encourage more sophisticated structures—such as combined power-carbon derivatives or structured products—to manage exposures together.

Second, it can affect forward contracting behaviour. Uncertainty linked to carbon price volatility may reduce willingness to commit to long-term contracts; in Q1 2026 this was reflected in lower forward capacity auction prices on key interconnectors as traders priced in the possibility that future arbitrage opportunities could be eroded by changes in CBAM costs. The knock-on effect is weaker forward market liquidity, which can impair price discovery and long-term hedging.

Third, while traditional arbitrage between electricity markets may be constrained by CBAM costs, a new form of arbitrage can emerge between power and carbon markets. Traders with strong capabilities across both domains may seek value from timing cross-border transactions or purchasing CBAM certificates based on anticipated EU ETS movements.

Asset valuation diverges between high- and low-carbon generation

The CBAM–EU ETS linkage also feeds into how generation assets are valued. In a carbon-linked environment, profitability depends not only on operating cost and output but also on emission intensity relative to prevailing carbon prices. Coal-fired plants exporting from parts of Southeast Europe face disadvantages because their output carries higher CBAM-related cost under border rules—reducing revenue potential while increasing earnings volatility as both electricity and carbon prices fluctuate.

By contrast, low-carbon assets such as hydro, wind and solar benefit from reduced exposure to CBAM costs when exported into the EU. Their revenues are described as less directly exposed to carbon price volatility, supporting a more stable income profile relative to higher-emitting generation.

Regulatory coordination becomes central to market design

The integration raises questions about market design and regulatory alignment. While extending carbon pricing aims to create a level playing field, it also adds complexity for electricity-market functioning. Differences between EU carbon pricing regimes and those in neighbouring countries can lead to distortions in trade and investment—as reflected during Q1 2026 in the article’s discussion of observed effects.

The piece argues that aligning regimes—either through adopting carbon pricing in Western Balkans countries or through adjustments to CBAM—could help mitigate these distortions and support more efficient market integration.

A transition still underway

From a system perspective, financialisation brings both benefits and risks: it strengthens decarbonisation incentives by ensuring carbon costs show up in market outcomes, but it also increases complexity and volatility for participants who must manage additional layers of uncertainty.

The experience described for Q1 2026 suggests integration is still early. Market participants are adapting by developing strategies to manage carbon exposure and incorporating EU ETS dynamics into trading decisions; over time this could lead to deeper integration between power and carbon platforms, new financial instruments and greater involvement from financial institutions.

For Southeast Europe, the transformation is simultaneously a challenge—requiring navigation through a more complex and volatile environment—and an opportunity to align incentives with decarbonisation goals while attracting investment in low-carbon technologies as CBAM continues to evolve alongside fluctuating EU ETS prices.