Electricity-intensive manufacturers exporting to the European Union are being urged to treat their next round of power and efficiency investments as a multi-year compliance and risk exercise, not a direct bet on future Carbon Border Adjustment Mechanism outcomes. The European Commission’s ongoing work on indirect emissions signals that the commercial value of renewable electricity and energy-efficiency measures could shift if future rules expand what is counted. However, any prospective regulatory changes remain separate from obligations currently in force under CBAM.
In June 2026, the European Commission published a technical study focused on how indirect-emissions factors could be developed, including conditions for using actual emissions data and whether additional sectors could be brought into scope. The review roadmap also points to further assessment of indirect emissions for iron and steel, aluminium and hydrogen. While these assessments are part of the policy development process, they do not by themselves alter the existing treatment of those goods.
For industrial exporters, the immediate operational priority is to strengthen electricity monitoring and preserve production records without tying investment returns to regulatory outcomes that have not yet been enacted. Improved metering, electricity efficiency measures and systematic record retention can support day-to-day operations while also generating information that may be needed if future reporting requirements are introduced. This approach aims to keep current compliance grounded in adopted rules while preparing for potential evidence demands later.
The relevance of indirect emissions is particularly visible in aluminium, where electricity can represent a substantial share of the sector’s wider production footprint even though current CBAM treatment for covered aluminium goods focuses on direct emissions. Under a scenario where indirect emissions were brought into scope in future rules, electricity sourcing could take on a different role in producers’ CBAM calculations and investment assessments. The magnitude would depend on the methodology chosen, eligibility conditions for any electricity-related claims and the timetable for implementation.
An illustrative production process consumes 2 MWh of electricity per tonne of goods. In a hypothetical future case, reducing an eligible electricity emissions factor from 0.70 to 0.10 tonnes of CO2 per MWh would cut the electricity-related emissions component by 1.20 tonnes of CO2 per tonne of goods. Using an assumed carbon price of €80 per tonne of CO2, the resulting unadjusted financial sensitivity would be €96 per tonne of goods.
That sensitivity figure is explicitly positioned as a policy stress test rather than a current CBAM charge for steel or aluminium goods whose own indirect emissions are excluded under existing treatment. It assumes future coverage and eligibility conditions that would need to be established through subsequent rules, while acknowledging that different methodologies and adjustments could produce different results. For exporters, the key takeaway is that future indirect-emissions design choices could change how electricity-related investments translate into CBAM-relevant economics.
Long-lived industrial assets add another layer to the decision-making challenge because they can lock companies into power arrangements for decades. A factory built around a specific electricity supply structure can remain exposed to those choices well beyond the period in which policy details are still evolving. This makes flexibility in procurement, access to data and contract renewal options relevant alongside current electricity prices.
Companies are therefore being encouraged to separate spending with immediate operational benefits from investments whose returns would rely on potential certificate savings tied to hypothetical future CBAM developments. A meter that identifies avoidable electricity consumption has an immediate purpose in managing costs and performance. By contrast, a long-term premium for renewable electricity justified only by prospective CBAM savings requires a separate assessment of regulatory risk.
Policy discussions also involve two distinct regulatory questions that exporters need to keep separate: expanding indirect-emissions coverage versus bringing additional downstream products within CBAM’s scope. Expanding indirect-emissions coverage would change which emissions are counted for relevant goods, while expanding product coverage would change which goods are covered at all. Even if both directions could have related commercial effects, they concern different elements of the regulatory framework.
For manufacturers in Southeast Europe preparing for possible changes, early preparation can start with a documented electricity balance and mapping of production processes. Such records can help companies evaluate alternative regulatory scenarios without having to reconstruct their electricity consumption and production boundaries from scratch if new legislation is adopted later. The focus remains on building usable evidence structures rather than forecasting which future rule design will ultimately apply.
Readiness is also shaped by market demand and financing structures before any new CBAM obligation becomes binding. EU customers may request more detailed electricity information through procurement policies ahead of mandatory requirements under CBAM, pushing exporters to assess whether such requests create measurable commercial opportunities rather than assuming every questionnaire will lead to a price premium. At the same time, banks financing long-term industrial assets are advised to maintain base-case assumptions built around current rules and contracted benefits.
Alternative scenarios used in financing models can then test broader assumptions such as expanded indirect-emissions coverage, higher electricity costs and more demanding evidence requirements without treating prospective regulatory changes as secured revenue. Contract design can further preserve flexibility as frameworks develop by including data-access rights, periodic reviews of calculation methodologies and workable change-in-law provisions when requirements shift.
Investment committees are also being urged 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 therefore concentrate on adopted legal texts, application dates and the calculation methods that ultimately apply under any future CBAM revisions.
Across Southeast Europe and beyond, the practical implication is straightforward: reliable consumption data combined with adaptable procurement arrangements provide a basis for responding to regulatory change without pre-committing investment returns to uncertain future coverage design. Taken together with the Commission’s June 2026 study and its roadmap assessments for iron and steel, aluminium and hydrogen, the message for exporters is that near-term operational improvements can support present compliance while keeping options open if indirect-emissions rules evolve.