The implementation of the Carbon Border Adjustment Mechanism (CBAM) marks a significant shift in the dynamics of electricity markets in Southeast Europe. Traditionally, the pricing of electricity in this region has been influenced predominantly by factors such as fuel costs, hydrological conditions, and demand variations. However, CBAM introduces a new variable: carbon cost differentials among neighboring electricity systems, reshaping market behaviors and price formations.
Since its inception in 2005, the EU Emissions Trading System (EU ETS) has played a pivotal role in altering the economics of electricity generation across Europe. Covering around 40% of EU greenhouse gas emissions, it has established itself as the largest carbon market worldwide. As carbon prices have risen over the past decade, they have become integral to wholesale electricity pricing, imposing substantial compliance costs on coal-fired plants while favoring renewable energy sources with zero emissions costs.
CBAM extends the reach of the EU ETS beyond its borders, requiring imports of certain carbon-intensive goods—including electricity—to reflect their carbon content when entering the EU market. This regulatory framework aims to mitigate carbon leakage by preventing production shifts to countries with less stringent environmental regulations. The implications for Southeast European power markets are profound, as they are interconnected through extensive transmission networks linking EU member states with Western Balkan nations.
Historically, electricity exports from Western Balkan countries flowed into EU markets driven by lower marginal costs from coal-based generation. However, with CBAM imposing implicit carbon costs on these exports, the economic landscape is changing. Electricity imported into the EU from non-carbon-priced countries must now account for embedded emissions, effectively increasing costs for carbon-intensive imports. For instance, coal-based electricity—typically emitting around one tonne of CO₂ per MWh—could face additional charges of €60 to €80 per MWh based on current EU ETS prices.
This shift could lead to a reversal in power flows within Southeast Europe. As coal-exporting countries grapple with rising costs due to CBAM adjustments, some may pivot towards importing lower-carbon electricity from within the EU. Sources such as nuclear and hydropower from Romania and Bulgaria are poised to play a crucial role in this transition. Additionally, expanding wind and solar capacities across the region offer further opportunities for low-carbon imports that avoid CBAM penalties.
The evolving landscape is also influencing industrial consumers who are increasingly seeking low-carbon electricity to enhance their product sustainability. Export-oriented industries may face significant carbon costs if reliant on high-emission electricity sources for production processes. This scenario creates strong incentives for long-term power purchase agreements (PPAs) focused on renewable energy procurement. Across Europe, large industrial players are already securing renewable PPAs lasting between 10 and 20 years to stabilize their energy costs while minimizing carbon footprints.
Over time, CBAM could facilitate a convergence between electricity prices and carbon intensity across Southeast Europe. Markets characterized by higher emissions may find themselves at a competitive disadvantage in cross-border trade compared to those with lower emissions profiles. Consequently, electricity pricing will increasingly reflect not only traditional factors like fuel costs but also the carbon characteristics inherent in generation portfolios.
This transformation is evident in current trading strategies where market participants are beginning to incorporate forecasts of carbon prices into their models. The value assigned to transmission capacities is also likely to evolve as new trading opportunities emerge due to differences in carbon pricing across regions.
The integration of carbon pricing into cross-border trade signifies a structural transformation for Southeast European energy markets. For decades dominated by engineering and fuel economics, market behavior is now being significantly influenced by climate policy considerations. As CBAM transitions toward full implementation later this decade, its impact on trading practices, investment strategies, and overall market structures will continue to intensify.
For stakeholders in the energy sector—including policymakers and utility companies—the developments underscore an urgent need to align regional electricity systems with Europe’s broader low-carbon energy transition goals.
