Electricity-intensive manufacturers exporting to the European Union face investment decisions that extend beyond the current Carbon Border Adjustment Mechanism (CBAM) framework. Possible changes to indirect-emissions coverage could affect the commercial value of renewable electricity and energy-efficiency projects. Prospective regulatory changes are described as separate from obligations currently in force.
The European Commission published a technical study in June 2026 on indirect-emissions factors. The study also covers conditions for using actual emissions data and the possible inclusion of additional sectors. The Commission’s review roadmap further envisages assessment of indirect emissions for iron and steel, aluminium and hydrogen.
The assessments referenced in the roadmap are stated not to change the existing treatment of those goods. For industrial exporters, the immediate focus is improving electricity monitoring and preserving production data. The aim is to avoid basing investment returns on regulatory changes that have not been enacted.
Commission work on indirect emissions and sector coverage
The June 2026 technical study examines how indirect-emissions factors could be handled under potential CBAM updates. It addresses conditions for using actual emissions data and whether additional sectors could be included. The roadmap also points to further assessment for iron and steel, aluminium and hydrogen.
These future assessments are presented as not altering current treatment for the listed goods. In parallel, exporters are advised to strengthen metering and record retention practices tied to current operations. Better electricity efficiency measures and systematic documentation are described as supporting present needs while enabling information collection for potential future reporting requirements.
Illustrative aluminium exposure from eligible electricity factors
Aluminium is used to illustrate how possible changes to indirect-emissions coverage could matter for electricity-intensive industries. Electricity can represent a substantial share of the sector’s wider production footprint. Under current CBAM treatment for covered aluminium goods, attention is placed on direct emissions.
If indirect emissions were brought into scope under future rules, electricity sourcing could play a different role in producers’ CBAM calculations and investment assessments. The financial impact would depend on the methodology used, the conditions for eligible electricity claims, and the implementation timetable.
An illustrative production process consumes 2 MWh of electricity per tonne of goods. In a hypothetical scenario, reducing the eligible electricity emissions factor from 0.70 to 0.10 tonnes of CO₂ per MWh would lower the electricity-related emissions component by 1.20 tonnes of CO₂ per tonne of goods.
At an assumed carbon price of €80 per tonne of CO₂, the unadjusted financial sensitivity would be €96 per tonne of goods. The calculation is described as a policy stress test rather than a current CBAM charge for steel or aluminium goods whose own indirect emissions are excluded. It assumes future coverage and eligibility conditions that would need to be defined by subsequent rules.
Planning long-lived assets under current rules versus future scenarios
The source material emphasizes that long-lived industrial assets require assessment across multiple regulatory outcomes. A factory built around a specific electricity supply arrangement can remain exposed to that decision for decades. Flexibility, data access, and contract renewal options are described as relevant alongside current electricity price considerations.
Manufacturers are advised to separate spending that supports immediate operational benefits from investments whose returns depend on possible future certificate savings. A meter identifying avoidable electricity consumption is described as having an immediate operational purpose. In contrast, a long-term renewable electricity premium justified only by hypothetical future CBAM savings requires separate assessment of regulatory risk.
The material also distinguishes two regulatory questions: expanding indirect-emissions coverage and bringing additional downstream products within CBAM scope. Expanding indirect-emissions coverage would change which emissions are counted for relevant goods. Bringing additional downstream products within scope would change which goods are covered.
Preparation steps in Southeast Europe and information requests
For Southeast European manufacturers, preparation can start with a documented electricity balance and a map of production processes. These records would allow companies to assess alternative regulatory scenarios without reconstructing electricity consumption and production boundaries from the beginning if new legislation is adopted.
The source also notes that EU customers may request more detailed electricity information through procurement policies before such information becomes mandatory under CBAM. Exporters would need to determine whether these requests create measurable commercial opportunities rather than assume every questionnaire leads to a price premium.
Financing, contract design, and monitoring based on enacted texts
Banks financing long-term industrial assets should maintain a base case built around current rules and contracted benefits. Alternative scenarios can then assess broader indirect-emissions coverage, higher electricity costs, and more demanding evidence requirements without treating prospective regulatory changes as secured revenue.
Contract design is described as a way to preserve flexibility as the regulatory framework develops. Data-access rights, periodic reviews of calculation methodologies, and workable change-in-law provisions can help parties adjust arrangements if requirements change. This approach is contrasted with relying on renegotiating rigid agreements later.
Investment committees are advised to distinguish between enacted legislation and policy developments that have not created legal obligations. Technical studies, reports, and negotiating positions may influence expectations but do not independently establish new compliance duties. Monitoring should focus on adopted legal texts, application dates, and the calculation methods that ultimately apply.
For exporters planning electricity investments over an extended period, reliable consumption data and adaptable procurement arrangements provide a basis for responding to regulatory changes without assuming in advance which measures will be adopted.