Serbia is changing the economics of its carbon tax for electricity producers by allowing part of their liability to be offset through qualifying decarbonisation investment. Parliament adopted the amendments on August 31, with the changes scheduled to take effect on September 8. Under the new rules, an electricity producer generating at least 80% of total revenue from power generation can claim a tax credit equal to 20% of eligible investment expenditure on measures that reduce carbon-dioxide-equivalent emissions. The credit is classified as state aid and is capped at 80% of the producer’s carbon-tax liability.
Carbon tax becomes linked to investment
Serbia introduced its domestic carbon tax at the beginning of 2026 at €4 per tonne of CO₂ equivalent, covering electricity generation and several energy-intensive industries. The amendment means the levy can now serve not only as an additional cost for carbon-intensive generation but also as a mechanism to support qualifying investment.
The change is particularly relevant for Elektroprivreda Srbije (EPS), whose generation portfolio remains heavily reliant on lignite while the utility faces the need to finance renewables, storage, grid flexibility and other emissions-reduction measures. The carbon tax remains payable, as producers must make qualifying investments and cannot offset more than 80% of their liability. However, the mechanism allows part of the tax burden to be redirected toward capital expenditure. That comes as Serbia’s power-sector transition becomes increasingly capital intensive, with independent estimates putting required energy-sector investment through 2030 at €15 billion-€20 billion.
EU carbon rules increase pressure on generation
The policy change comes as the European Union’s Carbon Border Adjustment Mechanism (CBAM) entered its definitive phase on January 1, 2026. For Serbia, the impact extends beyond direct electricity exports to the EU. Carbon costs increasingly affect generation competitiveness, trading strategies, forward pricing and the economics of new power-sector investment.
The amended tax framework represents a domestic response to that external commercial pressure by giving major electricity producers an incentive to direct part of their carbon-related costs toward eligible decarbonisation projects. The eventual scope of the measure will depend heavily on the government rulebook defining which investments qualify. A narrow definition focused on direct emissions reductions at existing plants would limit the benefit. A broader approach covering renewable generation, storage, efficiency upgrades, electrification, grid-support technology and other measures associated with lower emissions intensity could make the mechanism substantially more significant.
Eligibility rules will determine EPS impact
For EPS, the issue extends beyond reducing emissions from individual lignite units. The utility must also gradually replace some of the functions currently provided by coal, requiring investment in renewable capacity, flexible generation, storage and transmission and distribution infrastructure.
Some of those assets may not directly reduce emissions at an existing coal facility but could lower the carbon intensity of the wider generation portfolio. The treatment of such projects under the forthcoming rulebook will therefore be important. The amendments also change the timing of compliance. The filing period for the first 2026 emissions-tax returns has been moved to April 1-May 31, 2027. The additional time gives companies more scope to establish emissions accounting, verification and internal tax procedures during the first year of the regime. It does not, however, remove the underlying liability.
Companies will still need reliable 2026 emissions data and documentation demonstrating that claimed investments meet the legal requirements. For EPS, projects seeking tax-credit treatment will need evidence covering investment costs, commissioning, technical performance and their impact on emissions.
Credit creates sector-specific tax relief
The 80% revenue threshold distinguishes electricity producers from other industries subject to Serbia’s carbon tax. The provision effectively targets companies whose principal activity is power generation, while steel, cement, aluminium and fertiliser producers do not automatically receive the same route to tax relief. Electricity has a broader role in decarbonisation because lower-carbon power can also reduce the embedded emissions of industrial products. A cleaner electricity mix could reduce the carbon footprint of Serbian manufacturers using grid power and strengthen their position under CBAM when exporting to the EU.
Effectiveness depends on additionality
The scale of the tax relief also creates a risk that companies could receive substantial benefits for investments that would have been made regardless of the credit. Because the credit can cover up to 80% of carbon-tax liability, the government will need to distinguish genuine emissions-reduction investment from ordinary maintenance expenditure.
The framework will also need to address potential double counting where projects receive other forms of state aid or concessional financing. Since the tax credit itself is classified as state aid, its interaction with Serbia’s wider subsidy framework will be significant.
€4 carbon price limits immediate impact
Serbia’s initial carbon price of €4 per tonne remains far below typical carbon prices under the EU Emissions Trading System. The investment credit further reduces the effective burden for qualifying electricity producers, meaning the levy is currently more of a transitional policy instrument than a carbon price capable on its own of substantially changing generation dispatch.
Its importance lies in connecting carbon taxation, investment support and electricity-market reform. For EPS, the mechanism could affect the sequencing of investment if projects offering both commercial returns and recognised emissions benefits become more attractive. The credit cannot meet the utility’s wider transition needs. The scale of required investment is considerably larger than the value generated by a €4-per-tonne carbon tax. EPS will still require external financing, predictable electricity-market revenues and a long-term strategy for replacing ageing coal capacity.
