CBAM to reshape SEE electricity trading into a carbon-adjusted market from 2026

From 2026 onward, the EU’s Carbon Border Adjustment Mechanism (CBAM) is set to change how electricity is traded between South East Europe and the European Union—turning cross-border power flows from a largely spread-and-capacity business into one where embedded emissions and carbon pricing matter. For investors and traders, the implication is straightforward: the “second price” attached to each MWh will increasingly determine whether exports remain profitable or become discounted.

CBAM adds an emissions layer to EU-bound power pricing

The core shift is that Western Balkans electricity destined for the EU will no longer be valued only on the basis of €/MWh, border capacity and hourly scarcity. Instead, its assessment will also incorporate embedded CO₂, national carbon pricing signals, generation mix and proof of low-carbon origin. In practice, this reframes cross-border optimisation around carbon-aware routing and documentation—not just market spreads.

Early evidence: EU–WB6 flows already down

The first market signal is already visible. Energy Community’s Q1 2026 CBAM monitoring found that commercial electricity flows between the EU and WB6 contracted by roughly 25% year on year. The monitoring also suggested that traders are showing preferences for routes less exposed to CBAM friction. That points to CBAM influencing decisions now—affecting interconnector utilisation and route selection rather than remaining a purely future compliance cost.

Five structural trends for SEE traders

The move toward carbon-adjusted trading creates five structural trends for South East Europe.

1) Coal-heavy baseload exports lose optionality. Thermal output in Serbia, Bosnia, Montenegro and North Macedonia can still be traded regionally, but EU-bound exports face a carbon discount. The traditional strategy of exporting surplus lignite generation into higher-priced EU hours becomes less effective because the carbon adjustment erodes the spread. Serbia’s export economics are described as especially exposed because CBAM arrived alongside SEEPEX introducing negative prices from 5 May 2026—day-ahead prices allowed down to -€500/MWh and intraday prices down to -€9,999/MWh.

2) Low-carbon generation gains value beyond energy price alone. Hydro, wind and solar are positioned to earn more when their output can be tied to compliance-sensitive buyers or industrial offtake arrangements that need cleaner supply chains. This helps explain why hydro-linked flows involving Albania and Greece became more relevant in Q1 2026, while corridors outside CBAM friction became more attractive.

3) Power purchase agreements become instruments for managing carbon risk. For industrial exporters in sectors such as steel, aluminium, fertilizers, cement and processing, PPAs are no longer only hedges against wholesale price swings. They can also function as documentable hedges against carbon exposure if they are supported by metering, physical delivery logic, hourly matching and reliable emissions accounting. The article links this development to stronger bankability prospects for wind, solar, battery energy storage systems (BESS) and hybrid projects across Serbia, Montenegro, Bosnia and North Macedonia.

4) Domestic carbon pricing turns into a variable inside trading economics. Montenegro is highlighted as an example of how CBAM costs can translate into material annual exposure. EPCG has warned that CBAM-related costs could reach about €191 million annually, while reports cited an impact of around €13 million in Q1 2026. The exposure is described as concentrated because electricity represents a very large share of exports and TE Pljevlja remains central to generation.

5) Negative prices plus CBAM increase the payoff for flexibility. Negative prices penalise inflexible generation during oversupply hours; CBAM penalises high-carbon exports during EU-bound hours. Together they raise the value proposition for battery storage, hydro flexibility, demand response, intraday optimisation and balancing services—shifting earnings away from simple baseload exports toward hourly positioning and imbalance management with carbon-aware routing.

A two-price world for SEE power

The strategic takeaway is that SEE electricity moves into a two-price framework. One price is the visible wholesale level; the second is the embedded carbon value or penalty attached to each MWh. From 2026 onward, traders, utilities and banks that ignore this embedded-carbon component risk misreading spreads—overvaluing coal-backed exports while underestimating the bankability premium attached to clean electricity with traceable origin.

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