The EU’s Carbon Border Adjustment Mechanism is starting to change trade economics for energy-intensive producers well before the compliance regime fully matures. For Serbia, the early impact is showing up first in electricity flows, where coal-dominated generation faces a direct carbon cost penalty tied to EU emissions trading benchmarks. The knock-on effects are now being tracked across export-oriented heavy industry, with implications for contract pricing, demand and competitiveness.
Electricity exports hit first as CBAM-linked carbon costs price out Serbian power
Implementation of the EU Carbon Border Adjustment Mechanism at the start of 2026 is already affecting the economics of Serbia’s export model, with the electricity sector among the most exposed. In the case of Elektroprivreda Srbije (EPS), electricity exports to the EU have effectively stopped since January. Since 1 January 2026, EPS has not exported electricity to the European Union.
At prevailing carbon price levels of roughly €75–90 per tonne of CO₂ and with Serbia’s coal-heavy generation emitting around 1.0–1.1 tCO₂/MWh, the additional CBAM burden is estimated at approximately €70–80 per MWh of exported electricity. The resulting effect is described as a doubling of marginal costs for coal-based power entering EU markets, eliminating arbitrage margins even during peak price periods. Exports that historically helped balance output and support profitability are therefore reduced to zero.
EPS exposure: export margin losses now, ETS-aligned costs later
The immediate loss of export capability is framed as more than a short-term trading disruption because it strikes at the financial core of Serbia’s power system. Electricity exports account for less than 10% of total output, yet they have historically contributed disproportionately to EPS profitability by monetising surplus generation during off-peak periods. With exports curtailed, the revenue model that supported flexibility and earnings is under pressure.
Estimates from Serbia’s Fiscal Council point to roughly €200–300 million in annual CBAM-related cost exposure for 2026–2030, alongside potential profit erosion of about €200 million per year linked to lost export margins. The longer-term risk escalates under full alignment with the EU Emissions Trading System by 2030, when carbon costs for the power sector could reach up to €3 billion annually. This sets up a strategic dilemma between absorbing border penalties or internalising carbon pricing domestically at higher system-wide cost.
Industrial spillover: steel, aluminium, cement and fertilisers see EU export compression
CBAM pressure is not confined to electricity markets, and early data suggest a rapid transmission into Serbia’s broader industrial base. Energy-intensive sectors including steel, aluminium, cement and fertilisers are already experiencing a decline in exports to the EU in early 2026. The reported magnitude is approximately a 27–30% reduction in EU-bound exports.
Although CBAM is formally paid by EU importers, the economic mechanism is described as being passed back through lower contract prices, reduced demand and loss of market share. For exporters outside the EU carbon pricing system, this compresses competitiveness across supply chains that rely on high-emissions inputs. The result is an adjustment pressure that reaches beyond compliance paperwork into pricing and sales performance.
Carbon intensity gap becomes a pricing mechanism through ETS-indexed adjustments
The central driver is structural carbon intensity rather than short-term market conditions. Serbia’s reliance on lignite means emission intensities remain significantly above EU benchmarks, with some cases described as producing electricity with three to four times higher CO₂ intensity than EU averages. Under CBAM-linked pricing, this gap is monetised when products enter the EU market.
Exported electricity under the new regime is characterised as having a two-part price structure: a base electricity price plus a carbon adjustment indexed to EU ETS benchmarks. This changes how Serbian power competes relative to producers already operating under EU emissions constraints. It also increases sensitivity for importers managing procurement choices across supply sources with different carbon footprints.
Risk of “energy island” dynamics and rising balancing costs
Economists and policymakers have highlighted a strategic concern that Serbia could become an “energy island” within the European system if current dynamics persist. The scenario described includes structurally blocked electricity exports to the EU and reduced economic viability for cross-border trading. It also points to less effective market coupling with EU power exchanges.
If isolation takes hold, system flexibility would be reduced and balancing costs would increase, ultimately feeding into higher domestic electricity prices. In this framing, CBAM does not only affect trade volumes; it can alter how cross-border power markets function operationally and financially for neighbouring systems that depend on coupling mechanisms.
Transition constraints: slow renewables build-out, delayed coal phase-out and limited funding access
The speed at which CBAM-linked impacts are appearing highlights a gap between Serbia’s current energy structure and EU regulatory alignment needs. Constraints identified include slow deployment of renewable capacity and delayed coal phase-out strategy. The absence of a domestic carbon pricing system further limits internal incentives to reduce emissions intensity ahead of border-linked penalties.
Limited access to EU decarbonisation funds is also cited as a barrier to faster transition planning and investment mobilisation. Without accelerated reform, Serbia faces a dual burden: short-term export losses under CBAM alongside long-term systemic costs under ETS integration after 2030. For industry stakeholders watching compliance pathways in Europe’s Green Deal framework, this underscores how decarbonisation investment timing can determine whether border measures translate into manageable adjustments or persistent cost shocks.
Domestic price risks: household impacts discussed alongside decarbonisation funding trade-offs
Analysts expect that lost export revenues and rising compliance-related costs could feed back into Serbia’s domestic market outcomes. Scenarios discussed include electricity price increases for households of up to about 50% under CBAM-adjustment scenarios. Another scenario points to potential doubling of prices if full ETS cost internalisation occurs post-2030.
This creates a politically sensitive trade-off between maintaining artificially low domestic tariffs and funding decarbonisation and system modernisation. For importers and exporters connected to European value chains, the compliance challenge therefore extends beyond documentation into procurement strategies and risk management around price formation under ETS-linked carbon adjustments.
Broader compliance implications across heavy industry and energy supply chains
CBAM is effectively forcing a redefinition of Serbia’s position in the European energy market by shifting it from a price-driven electricity exporter toward a carbon-constrained system requiring structural transformation. In the near term, export capability losses are already visible; in the medium term, industrial competitiveness increasingly depends on access to low-carbon electricity inputs. Long-term outcomes hinge on accelerating renewable deployment, introducing carbon pricing mechanisms, integrating with EU electricity markets and attracting capital into grid and generation modernisation.
Across cement, steel, aluminium and fertilisers—alongside electricity—the early evidence points to compressed EU export volumes through lower contract prices and demand shifts rather than solely formal border payments. Within Europe’s wider emissions regulation landscape under the Green Deal framework, these developments illustrate how ETS-indexed carbon adjustments can reshape procurement decisions for importers while increasing decarbonisation urgency for exporters seeking continued market access.