The introduction of the Carbon Border Adjustment Mechanism (CBAM) has begun to reshape electricity markets across South-East Europe (SEE), but not in the way policymakers initially anticipated. Rather than acting as a straightforward carbon pricing tool, CBAM has functioned as a short-term market distortion mechanism, altering price formation, redirecting trade flows, and temporarily suppressing conventional generation across non-EU systems.
What emerges from early 2026 market behavior is a system where CBAM’s influence is episodic, highly conditional, and rapidly arbitraged, rather than structurally transformative.
At its core, CBAM imposes a carbon-adjusted cost on electricity exports from non-EU countries into the European Union, directly affecting markets such as Serbia, Bosnia and Herzegovina, Montenegro, North Macedonia, and Albania. The cost is not determined by the physical origin of the electricity but by the entry point into the EU, meaning that the border through which power flows defines the carbon exposure.
This seemingly technical rule has profound implications. It effectively introduces a pricing wedge between EU and non-EU electricity markets, breaking the traditional arbitrage logic that had long governed cross-border flows in the region.
The most visible impact of CBAM unfolded during the first quarter of 2026, when an unusual convergence of factors amplified its effects. Exceptionally strong hydrological conditions across SEE, combined with unseasonably warm weather, led to a surge in low-cost hydro generation and subdued demand. At the same time, CBAM administrative systems—particularly those required to verify the carbon content and origin of electricity—were not fully operational.
The result was a sharp divergence in market outcomes. Non-EU SEE markets experienced significant price suppression, while EU markets registered marginally higher prices than would otherwise have been expected.
This divergence was not merely theoretical. It translated into persistent price discounts in markets such as Serbia and Bosnia, where electricity traded at levels materially below Hungarian or Romanian benchmarks, even when physical interconnection capacity remained available.
Crucially, the burden of CBAM has proven highly asymmetric. Non-EU systems, which rely on exports during periods of surplus, faced a direct loss of competitiveness. EU markets, by contrast, remained largely insulated due to their structural position as net importers or internally balanced systems. The result has been a downward pressure on non-EU prices without a commensurate tightening of EU supply, reinforcing the role of SEE as a price-taking periphery.
Yet this imbalance did not persist unchallenged. Market participants responded swiftly, identifying pathways to bypass CBAM exposure altogether. Electricity flows were increasingly redirected toward Ukraine and Moldova, markets that lie outside the CBAM regime. These transactions often transited through EU infrastructure—particularly Hungary and Romania—without triggering carbon costs, as long as the final destination remained outside the EU.
This rerouting had a dual effect. It allowed SEE exporters to recover part of their lost margin while simultaneously reducing demand on EU power exchanges, as Ukraine and Moldova sourced more electricity directly from SEE rather than from HUPX or OPCOM.
The intensity of CBAM’s impact has proven closely tied to hydrological conditions. During periods of high water inflows, SEE systems—traditionally hydro-heavy—shift into export mode, making them directly exposed to CBAM constraints. Under these conditions, prices in non-EU markets can collapse as surplus generation struggles to find competitive outlets.
When hydrology returns to normal or below-average levels, the situation reverses. SEE countries become net importers, drawing electricity from EU markets rather than exporting into them. In such scenarios, CBAM becomes effectively irrelevant, as there are no export flows subject to carbon adjustment.
This dynamic underscores a key structural limitation: CBAM only binds when SEE systems are long on energy. It does not influence the majority of operating hours, during which the region remains import-dependent.
One of the more immediate operational consequences of CBAM has been its impact on thermal generation, particularly lignite-fired plants. During the price depression of early 2026, operators across Serbia, Bosnia, and Montenegro faced a situation in which market prices fell below the marginal cost of lignite generation.
This triggered a temporary reduction in coal output, estimated at up to 500 MW during peak hydrological conditions.
However, this should not be mistaken for structural decarbonization. The reduction was driven purely by short-term economics. Lignite reserves were not depleted but rather conserved, with the expectation that they would be redeployed once market conditions improved. As hydrology normalized in March, coal generation recovered quickly, with output only 200–300 MW below historical averages, indicating that the CBAM effect on fuel switching is transient.
The interaction between CBAM and broader commodity markets further limits its long-term influence. Rising natural gas prices, observed from March 2026 onward, lifted wholesale electricity prices across the region. This increase restored the profitability of lignite plants even under discounted SEE pricing, effectively neutralizing CBAM’s suppressive effect on thermal generation.
In parallel, CBAM has begun to reshape trading behavior within SEE itself. As exports to the EU became less attractive, market participants increasingly turned inward, expanding cross-border trade among non-EU countries. This has the early characteristics of a regionalized SEE power market, partially decoupled from EU pricing dynamics during certain periods.
Despite its visible short-term impact, CBAM’s structural footprint remains limited. Historical data show that SEE countries are net exporters only in a minority of hours. In 2025, for example, exports exceeding 500 MW occurred in roughly 12% of total hours, underscoring the episodic nature of surplus conditions.
This means that CBAM affects marginal pricing periods rather than baseline system operation. Its role is to distort peak surplus conditions rather than redefine the overall market equilibrium.
Looking ahead through 2026 and into 2027, the influence of CBAM is expected to diminish further. As administrative frameworks mature and traders fully integrate CBAM costs into their strategies, the initial inefficiencies observed in early 2026 are likely to fade. At the same time, seasonal normalization of hydrology and sustained export channels toward Ukraine and Moldova will reduce the frequency of CBAM-constrained scenarios.
Under these conditions, CBAM becomes a situational constraint rather than a dominant pricing driver, shaping specific hours and flows but not the broader market trajectory.
The emerging picture is one of a mechanism that is economically significant but structurally bounded. CBAM introduces friction into cross-border electricity trade, redistributes value between EU and non-EU markets, and temporarily alters dispatch decisions. Yet it does not fundamentally change the region’s dependence on imports, nor does it enforce sustained decarbonization.
Instead, it reveals the adaptability of SEE electricity markets. Faced with new constraints, traders and utilities have demonstrated a capacity to reconfigure flows, preserve margins, and maintain system balance—often in ways that dilute the intended policy signal.
Elevated by cbam.engineer