Serbia and Montenegro face different electricity export challenges
For Serbia, CBAM creates a distinction between electricity assessed using the applicable default emissions factor and electricity that satisfies the conditions for using installation-specific actual emissions. The commercial opportunity is not simply to produce renewable electricity, but to organise a transaction in which the EU importer can substantiate the associated emissions claim.
Elektroprivreda Srbije (EPS) has been expanding its generation portfolio beyond conventional assets. Its adopted 2026–2028 business plan identifies additional renewable investment, including the planned development of self-balanced solar capacity. These investments create potential sources of lower-emission supply, although investment in a renewable asset does not itself establish the CBAM treatment of its electricity exports.
For an independent producer, the practical question is whether its chosen route to market preserves the evidence needed by the importing counterparty. Selling electricity into an intermediary’s general portfolio may produce a commercially satisfactory power contract without necessarily establishing an eligible installation-specific CBAM claim.
An important contractual distinction already exists in the implementing methodology. Where a PPA involves an intermediary, the evidence must demonstrate a single contract between the three contracting parties. That is different from assuming that any sequence of separate, back-to-back trading contracts satisfies the requirement.
For Montenegro, an export arrangement serving an Italian buyer should be assessed in the same way: which generating installation supports the claim, which entity is the authorised declarant, and can the contractual and physical-delivery records be reconciled?
A contract involving EPCG, an independent generator or a trader should not rely solely on the seller’s renewable portfolio or an annual electricity balance. Its commercial value should be tested against the evidence available for the specific claimed deliveries.
This has a direct implication for export pricing. Any premium attributed to lower CBAM exposure should depend on demonstrated eligibility, rather than being treated as guaranteed income from the outset.
The strongest structure would distinguish qualifying deliveries from replacement electricity and specify the consequences of generation shortfalls, missing records or failed eligibility conditions. Otherwise, a producer may believe it has sold electricity at a fixed price while retaining an uncertain carbon-related liability through a broadly drafted indemnity.
Steel exporters face a production-route and precursor test
For metals, the principal challenge moves from hourly electricity delivery to the production process and its upstream material inputs.
The CBAM methodology for complex goods includes relevant precursor emissions. It permits actual values for some precursors and defaults for others, while prescribing how inputs from different installations are treated. A reliable calculation therefore requires more than the final manufacturer’s fuel and electricity invoices.
For a Serbian processor purchasing imported steel feedstock, the practical questions include which installation produced it, which emissions information accompanies it and how the material is allocated to the finished goods exported to the EU.
A low-emission finishing operation cannot automatically remove the emissions associated with its feedstock.
The financing implication is that procurement decisions can alter future carbon exposure even when the selling price and physical specification of the finished product remain unchanged. A cheaper precursor may become less attractive once its documented emissions and the resulting certificate requirements are considered.
For integrated producers, operational improvements may offer a more direct route to reducing exposure. HBIS Serbia, for example, reported in November 2024 that a blast-furnace coke-saving project reduced coke consumption by 2.26 kilograms per tonne of iron and cut annual CO₂ emissions by approximately 5,000 tonnes compared with the previous year. These were company-reported operational results, not an independently established CBAM saving.
That distinction matters. An engineering improvement must be reflected in the applicable product-level calculation before its commercial effect can be assessed. Buyers should not equate a corporate emissions-reduction announcement with a verified reduction in the liability associated with their particular imports.
Aluminium buyers must distinguish green power from chargeable emissions
Aluminium highlights a potential source of confusion in commercial negotiations: the difference between a product’s wider carbon footprint and the emissions currently included in its CBAM calculation.
Under Article 7 and Annex II of the CBAM Regulation, the listed iron, steel and aluminium goods are assessed on direct emissions only. Consequently, purchasing renewable electricity does not automatically reduce the current CBAM liability for those products. Product classification and the applicable methodology remain decisive.
Renewable power can still support energy-price management, customer decarbonisation objectives and broader product-footprint strategies. Those benefits should be presented separately from any claimed reduction in certificate expenditure.
For an aluminium processor, the more immediate CBAM questions concern relevant direct emissions, the treatment of qualifying precursors and the reliability of upstream information.
A purchasing agreement described as “low-carbon aluminium” should therefore identify precisely what the description means. It could refer to a broader lifecycle footprint, an electricity-sourcing attribute, a contractual production standard or verified emissions calculated under CBAM. These are not interchangeable claims.
The commercial risk is clearest where a buyer pays a premium expecting lower CBAM costs but receives documentation that supports only a different environmental attribute.
A stronger contract would distinguish the product’s physical specification, its environmental claims and the emissions information usable for the EU declaration.
Emissions uncertainty can outweigh a carbon-price movement
A hypothetical future-period metals contract illustrates why technical evidence should precede the final hedging decision.
Assume an EU buyer imports 20,000 tonnes of covered goods and forecasts a net certificate exposure equivalent to 0.8 tonnes of CO₂e per tonne of product, after applicable adjustments. At an illustrative carbon price of €80/tCO₂e, the forecast expenditure is €1.28 million.
A price increase to €100/tCO₂e, with the exposure unchanged, raises the cost by €320,000.
But suppose the final net exposure is 1.2 tonnes of CO₂e per tonne of product, rather than 0.8. Even with the price unchanged at €80, expenditure rises to €1.92 million—an increase of €640,000.
These are sensitivity assumptions, not official sector benchmarks or estimates for a named producer.
The example demonstrates two different risks. An appropriately structured carbon-price hedge may offset part of the price movement. It does not automatically compensate for an additional certificate requirement arising from revised emissions information.
The reverse also matters. Hedging an uncertain, overstated exposure can leave a company holding a derivative position larger than its eventual compliance-related need.
For exporters accepting carbon-cost guarantees, the critical contractual question is therefore whether they are guaranteeing an emissions value, a certificate quantity, a carbon price or a combined financial outcome. Those commitments should not be bundled together without explicit limits.
Carbon clauses should allocate causes, not just costs
The authorised declarant retains its statutory CBAM responsibility. A supply agreement can redistribute the economic consequences between buyer and seller, but it does not substitute the supplier for the declarant under the regulation.
Commercial drafting should begin by separating the causes of additional expenditure.
An increase resulting from inaccurate supplier data is different from one caused by the buyer’s certificate-purchasing decision. Both differ from a change in law or a failure by a trading intermediary to provide the agreed delivery records.
A balanced contract should connect each risk to the party best placed to control it.
The supplier could undertake to provide complete production and precursor records, notify material changes and correct identified errors. The buyer could remain responsible for its declaration, procurement decisions and the financial consequences of delays within its control. Shared dependencies should have a defined escalation and reconciliation process.
The pricing clause should specify the reference used. The Commission’s official CBAM price is based on weighted ETS auction prices, with quarterly pricing for 2026 imports and weekly publication from 2027. A generic reference to an “EUA market price” can therefore create a mismatch between the contractual charge and actual certificate expenditure.
Contracts should also address any claim for a carbon price paid in a third country. The regulation requires evidence of effective payment and consideration of available rebates or compensation; a contractual assertion that domestic carbon costs exist is not sufficient.
The resulting agreement should permit a transparent reconciliation once the relevant emissions and adjustments are established. It should avoid charging the buyer twice for the same carbon exposure through both a product-price premium and a separate reimbursement mechanism.
Banks should test the fallback case before financing the premium
For lenders, the relevant issue is whether the borrower’s projected cash flow survives an adverse carbon outcome.
An export-oriented renewable project may assume stronger electricity revenues because its deliveries are expected to support lower CBAM exposure. A metals exporter may assume that verified emissions will protect its margin against competing suppliers.
In either case, the financing model should show what happens when that assumption fails.
For a power project, the downside case should include non-qualifying deliveries, replacement electricity and the allocation of resulting costs. For a metals supplier, it should include changes in precursor sourcing, revised emissions values and the potential loss of a buyer-agreed premium.
The lender should distinguish those risks from carbon-price volatility.
ICE Endex EUA futures are physically deliverable contracts representing 1,000 allowances per lot. Their operational requirements are separate from CBAM certificate compliance, and exchange margin requirements create an additional financing consideration.
A borrower can therefore need liquidity for the physical commodity, the eventual certificate expenditure and the hedge itself.
Financing the derivative without understanding the underlying exposure can create a false impression of protection. Financing the production asset without testing the contractual carbon assumptions can be equally misleading.
A useful credit assessment would connect the production model, emissions evidence, supply agreement and treasury position. Any revenue attributed to verified lower emissions should be supported by an enforceable buyer commitment rather than an assumed market premium.
Local engineering support can reduce uncertainty without replacing verification
For producers and importers, much of the preparatory work occurs before an accredited verifier reaches a conclusion.
A local engineering team can help organise production records, reconcile material balances, review metering arrangements, document process boundaries and coordinate information from precursor suppliers. In electricity transactions, it can help reconcile installation records with the commercial and delivery evidence assembled by the other parties.
This work should be understood as preparation and technical support, not a guarantee of acceptance.
The Commission states that actual CBAM emissions must be verified by independent verifiers accredited through the applicable EU accreditation framework. The verifier evaluates the monitoring approach, calculations and supporting evidence before issuing its report.
There is consequently a clear division of responsibilities.
The installation operator owns its production information. Technical advisers can help make that information complete and reviewable. The accredited verifier reaches the independent verification conclusion. The authorised declarant uses the relevant information in its declaration.
Impartiality requirements also mean that the verification role must remain distinct from consultancy that creates an unacceptable self-review conflict.
The commercial value of engineering support is therefore not a promised low emissions number. It is earlier identification of missing evidence, more reliable forecasts and fewer unresolved issues when the importer must finalise its position.
Export competitiveness will depend on the contract as well as the plant
For Southeast European suppliers, the connection between ETS prices, hedging and CBAM points to a broader commercial change.
A competitive production cost remains essential. But a buyer assessing two otherwise comparable offers may also need to consider the reliability of emissions information, the allocation of future costs and the cash required to manage uncertainty.
That creates a potential advantage for suppliers able to combine operational performance with a defensible evidence package and a workable contract.
It does not guarantee a premium. The benefit may instead appear as a smaller buyer discount, fewer contractual contingencies or greater confidence in a long-term purchasing commitment.
The same discipline should govern hedging. A company should first establish what exposure it retains under the contract, then determine which part is driven by the carbon price and which part depends on production, documentation or legal eligibility.
For an electricity exporter, the decisive document may be a qualifying PPA supported by delivery evidence. For a metals supplier, it may be a verified product calculation supported by precursor records. For the bank, it is the connection between those documents and the borrower’s cash flow.
A lower-emission plant has commercial value, but that value can be lost in an incomplete evidence chain or an unbalanced supply agreement. The strongest exporters will be those able to carry their production advantage all the way into an enforceable price.
Supported by CBAM.Clarion.Engineer
