As the EU Carbon Border Adjustment Mechanism moves from design into operational reality, its first measurable effects in 2026 are emerging most clearly at the interface between EU and non-EU power systems. In South-East Europe, the mechanism has been widely interpreted as a straightforward carbon cost that would lift prices across the region. Instead, early evidence points to a more immediate outcome: a reconfiguration of cross-border electricity flows that changes where power moves, and when it is profitable to export.
CBAM creates an EU versus non-EU electricity split
Within South-East Europe, CBAM has produced a dual-market dynamic that distinguishes EU-integrated systems from non-EU jurisdictions. Markets such as Hungary and Romania are structurally linked to EU trading conditions, while countries including Serbia, Bosnia and Herzegovina, and Montenegro operate outside the EU framework. For electricity exported from these non-EU systems into the EU, CBAM functions as an implicit carbon cost tied to the exporting system’s generation mix.
This design matters for compliance and pricing mechanics at the border. Rather than acting like a uniform surcharge that automatically reprices all regional trades, CBAM introduces friction specifically on exports into the EU. The result is an “export fee” effect that can alter dispatch incentives and route selection even when broader supply-demand fundamentals remain unchanged.
Early 2026: price pressure concentrated in Q1
The strongest market divergence occurred at the start of 2026. During the first quarter, non-EU South-East European markets saw significant price suppression, while EU markets cleared at a relative premium. The gap was particularly visible in January and February, when non-EU prices fell below levels justified by underlying supply-demand conditions.
Analysts link this pattern largely to economically constrained export routes into the EU. When exports become less attractive under CBAM-related conditions, domestic prices in exporting systems can weaken even if generation availability remains high. At the same time, EU clearing prices do not necessarily rise by an equivalent magnitude, indicating that CBAM’s immediate influence is not simply a regional repricing.
Temporary implementation frictions amplified the effect
Two short-lived factors intensified the early-year distortions. First, administrative procedures needed to certify the origin of electricity flows under CBAM were not fully operational at the beginning of 2026. That created inefficiencies and uncertainty for traders and exporters, further discouraging cross-border sales into the EU during the initial months.
Second, exceptionally strong hydrological conditions across the Western Balkans generated surplus electricity at precisely the time export pathways were restricted. The combination of oversupply and reduced export flexibility deepened downward price pressure in non-EU systems. As conditions evolved into March and beyond, these constraints eased and hydrology moved toward average levels.
Why absolute price effects remained limited
Although EU markets registered higher prices relative to a no-CBAM scenario, the increase was modest. A key reason is structural: non-EU South-East European countries are rarely sustained exporters of electricity over an entire year. Export surpluses tend to appear mainly during periods of high hydro generation, which limits how much volume is exposed to CBAM on an annual basis.
This asymmetry suggests that CBAM’s ability to influence broader European price formation is constrained by trade volumes rather than by policy design alone. In practice, CBAM’s impact is strongest when surplus generation coincides with export bottlenecks—conditions that do not persist uniformly throughout the year.
Trading behaviour shifted toward alternative destinations
Where CBAM appears most consequential is in trading behaviour and physical flow patterns. As profitability of exports into the EU declined, market participants redirected electricity toward alternative destinations not subject to the same mechanism. In early 2026, a significant portion of surplus power from the Western Balkans was rerouted toward Ukraine and Moldova.
These flows often transited through Hungary and Romania, effectively creating a new eastward corridor for South-East European electricity. The shift partially neutralised CBAM’s intended effect on constraining exports outright by changing geography rather than eliminating surplus power from circulation. It also reduced reliance by Ukraine and Moldova on EU hubs such as HUPX and OPCOM, easing pressure on those trading venues.
Non-EU generation responses: lignite output deferred
CBAM-related price suppression within non-EU systems also influenced generation decisions during Q1 2026. Operators of lignite-fired plants—particularly in Serbia and Bosnia—reduced output rather than dispatching into a low-price environment. Estimates indicate reductions of several hundred megawatts relative to previous years during peak hydrological conditions.
However, this should not be treated as structural decarbonisation. The evidence indicates lignite generation was deferred rather than displaced: as hydrology normalised and prices recovered, stored fuel would be redeployed in later periods. In this sense, CBAM did not yet drive a sustained shift in generation mix across non-EU South-East Europe.
What changes after Q1: summer months expected to be less affected
The temporal pattern is central to interpreting CBAM’s role in electricity markets. The strongest effects were concentrated in Q1 2026 when high hydro output coincided with administrative inefficiencies and constrained export channels. As conditions moved into March and beyond—alongside resuming fossil generation—the price gap between EU and non-EU markets narrowed.
Looking forward, minimal impact is expected during summer months because non-EU South-East European countries are typically net importers then. With flows predominantly from EU markets into the Western Balkans during those periods, CBAM is not triggered in the same way. Even when exports occur outside summer peaks, improved administrative processes and established trading routes are likely to reduce early-year distortions.
Broader energy prices further moderated incentives
A separate factor also weakened CBAM’s influence on generation decisions: higher natural gas prices from March 2026 increased wholesale electricity prices across Europe. That restored profitability for lignite-fired generation in non-EU markets despite CBAM-related discounts tied to export conditions.
The combined effect is that incentives for curtailment became less compelling once wholesale prices rose. As a result, CBAM’s early impact on dispatch behaviour appears less likely to persist without supportive market conditions such as surplus hydro output meeting export constraints.
Analytical synthesis: flow reshaping over durable repricing
Taken together, these dynamics indicate that CBAM’s role in South-East European electricity markets is best understood as a short-term distortion layered onto an otherwise unchanged structural system. It introduces friction at the EU–non-EU interface, alters where power moves across borders, and temporarily suppresses prices in exporting systems during specific conditions.
For policy makers and industry participants tracking carbon pricing implementation under the broader Green Deal framework—including sectors covered by CBAM such as cement, steel, aluminium, fertilisers, electricity and hydrogen—the early electricity experience underscores a compliance-relevant lesson: immediate market effects can be driven as much by certification processes and trade routing as by long-run carbon cost transmission through prices.