Electricity traders importing power into the European Union are increasingly separating conventional electricity priced against applicable default emissions factors from deliveries supported by evidence meeting the EU Carbon Border Adjustment Mechanism (CBAM) actual-emissions requirements. The split is affecting how long-term power purchase agreements, spot-market positions, and cross-border transmission capacity are valued.
Standard import pricing tied to default emissions factors
Conventional wholesale electricity remains the first pricing category, but its delivered cost must reflect prospective CBAM certificate obligations. For a purchase of 1 MWh at an exchange hub for import into the EU, a trader considers the electricity price, losses, transmission capacity, balancing charges, credit costs, and expected carbon liability.
When the applicable default emissions factor is high, the resulting carbon cost can remove an otherwise positive wholesale price spread across the EU border. The Energy Community Secretariat identified this issue in its Q1 2026 market monitoring as a challenge affecting regional electricity exchanges.
Verified deliveries require traceable evidence and extra settlement work
A second pricing category covers electricity physically sourced from an eligible installation and supported by a traceable contractual arrangement. Such deliveries may qualify for actual-emissions treatment, but eligibility requires additional costs linked to PPA structuring, evidence collection, nomination allocation, metering reconciliation, and verification.
A trader cannot treat an entire generation portfolio as eligible when only some delivery hours meet the relevant requirements. Volumes that satisfy the criteria must be separately identified and ring-fenced within trading and settlement systems.
Commercial structures for allocating CBAM exposure
Two approaches can be used to structure electricity quotations that account for CBAM exposure. A cost-plus import model combines the electricity price and ordinary trading expenses with the applicable verified or default carbon component for each megawatt-hour.
A carbon-differential sharing model assigns a conditional share of the difference between fallback treatment and the actual-emissions outcome to the producer. The arrangement can create financial incentives for generators, scheduling agents, and importers to improve delivery records and emissions evidence quality.
Neither structure changes the importing declarant’s legal responsibilities under CBAM.
CBAM certificate reference prices influence long-term contract terms
CBAM certificate reference prices add another variable to long-term electricity contracts. For 2026 imports, published quarterly references were €75.36/tCO2e for Q1, €75.28/tCO2e for Q2, and €82.32/tCO2e for Q3.
From 2027, the reference price calculation moves to a weekly basis. A fixed premium agreed in October 2026 could therefore expose either producer or buyer to larger subsequent carbon-price movements than initially anticipated.
Contractual floors, caps, reopening provisions, and indexation mechanisms are described as needing to define that exposure clearly. Pricing documentation should also distinguish the applicable CBAM certificate reference price from EU Emissions Trading System allowance futures, which are separate market instruments.
Treatment of delivery hours without qualifying evidence
Traders must decide how to price individual hours within a product marketed as qualifying for actual-emissions treatment when supporting requirements are not met. One option is immediate reclassification of affected electricity followed by invoicing under standard import pricing methodology including applicable carbon exposure.
An alternative allows provisional qualification with later financial reconciliation. The provisional approach is described as offering more flexibility while introducing additional collateral requirements and counterparty risk.
The second approach should be supported by contractual rights to inspect original generation, metering, and nomination records rather than relying only on summary declarations from the producer.
Contract taxonomy affects transparency in verified versus conventional products
As traders gain experience with CBAM-related transactions, quotations may increasingly reflect the probability that particular volumes will qualify for actual-emissions treatment. Pricing becomes less transparent when sellers offer a general combination of renewable electricity and a CBAM benefit without specifying included rights and evidence.
A clear contractual product taxonomy should separate physical electricity delivery, CBAM eligibility, renewable certificate attributes, and balancing services. These elements may be bundled commercially, but their obligations and settlement mechanisms should remain identifiable.
Electricity trading desks able to quote and settle conventional and verified deliveries separately are described as better positioned to reflect different costs and risks associated with each product. The commercial value of renewable electricity depends not only on generation source but also on what claims an importer can substantiate under applicable rules at the EU border.