CBAM hydrogen importers face the widest certificate cost range of all 6 covered sectors: from zero for certified green hydrogen to €630–840 per tonne for grey hydrogen at the current EU ETS price of approximately €70 per tonne CO₂. The production route determines everything, making hydrogen one of the most strategically consequential sectors under Regulation (EU) 2023/956. This guide covers authorization requirements, embedded emissions calculations, certificate cost projections, and the green versus grey compliance gap that shapes every hydrogen import decision in 2026 and beyond.
Caption: Certificate cost differences between grey, blue, and green hydrogen production routes at current EU ETS carbon pricing.
What CBAM Means for Hydrogen Importers in 2026
CBAM requires EU importers of hydrogen (CN code 2804 10 00) to purchase certificates proportional to the direct embedded CO₂ emissions of each tonne imported, priced at the EU ETS carbon price, with no de minimis threshold. Unlike the other four goods-based sectors, hydrogen and electricity are excluded from the 50-tonne annual mass exemption under Article 2(3a) of Regulation (EU) 2023/956, as amended by the Omnibus regulation (EU) 2025/2083.
Hydrogen is an Annex II good, which means only direct emissions are priced. Indirect emissions from the electricity used in electrolysis are excluded from the certificate calculation. This distinction matters most for green hydrogen importers because the electricity consumption that drives electrolysis carries no CBAM liability, provided the hydrogen meets the embedded emissions criteria under the applicable monitoring methodology.
The EU CBAM framework, explained in full in the EU CBAM guide, applies to hydrogen from any third country not listed in Annex III of Regulation (EU) 2023/956. Countries exempt from CBAM for all sectors include Iceland, Liechtenstein, Norway, and Switzerland. All other hydrogen-exporting countries, including those expected to become major future suppliers such as Morocco, Chile, Saudi Arabia, and Australia, are subject to the full CBAM certificate obligation.
Certificate sales begin on February 1, 2027. The first annual CBAM declaration covering calendar year 2026 imports is due September 30, 2027. Hydrogen importers who applied for authorized CBAM declarant status by March 31, 2026 may continue importing provisionally while their application is processed, with a maximum decision timeline of 120 days from a complete submission.
Green vs Grey Hydrogen: How Embedded Emissions Differ
Five documented hydrogen production pathways exist under CBAM, with grey steam methane reforming producing the highest embedded emissions and green electrolysis producing the lowest. The table below sets out direct embedded emission factors and gross certificate costs at the current reference ETS price.
| Hydrogen Type | Production Method | Direct CO₂ (tCO₂/t H₂) | Gross CBAM Cost at €70/tCO₂ |
|---|---|---|---|
| Grey | Steam methane reforming (SMR), no CCS | ~9–12 | €630–840/t H₂ |
| Blue | SMR with carbon capture and storage | ~1–3 | €70–210/t H₂ |
| Turquoise | Methane pyrolysis (solid carbon byproduct) | ~0–1 | €0–70/t H₂ |
| Pink | Nuclear-powered electrolysis | ~0–0.5 | €0–35/t H₂ |
| Green | Renewable electrolysis (RFNBO-certified) | ~0–0.3 | €0–21/t H₂ |
Grey hydrogen dominates global production today because steam methane reforming without carbon capture is the lowest-cost industrial production method. The chemical process, methane reacting with steam to yield hydrogen and carbon monoxide, produces approximately 9–12 tonnes of CO₂ per tonne of hydrogen output when no CCS is applied. At €70/tCO₂, an importer sourcing 1,000 tonnes of grey hydrogen per year faces a gross certificate obligation of €630,000–840,000 before accounting for the 2026 free allocation factor.
The net obligation in 2026 is smaller than the gross figure. Under the free allocation phase-out schedule, the CBAM factor for 2026 is 2.5%, meaning importers surrender certificates covering only 2.5% of verified embedded emissions. A 1,000-tonne grey hydrogen shipment at 10 tCO₂/t generates 10,000 tCO₂ gross, but only 250 certificates are required in 2026. At €70 each, the net certificate cost is €17,500 per 1,000 tonnes. This net cost rises steeply as the free allocation factor increases: 5% in 2027, 10% in 2028, and 48.5% by 2030.
How does green hydrogen compare on this trajectory? Certified green hydrogen with near-zero direct emissions generates a certificate obligation approaching zero at any free allocation level. This structural cost advantage widens every year through 2034, when free allocation reaches zero and grey hydrogen importers face the full gross certificate cost.
How CBAM Certificate Costs Are Calculated for Hydrogen
Three inputs determine the final certificate obligation for any hydrogen import: the specific direct embedded emissions, the CBAM factor for the relevant year, and the EU ETS price at the time of certificate purchase.
The specific direct embedded emissions must be reported per tonne of hydrogen imported, per production installation, and per production route. Importers who obtain verified actual emissions data from the non-EU producer use that figure. Importers who cannot obtain producer data use the default value published in Implementing Regulation (EU) 2025/2621. For hydrogen, the transitional default reflects the SMR-dominated global production base, set at 10.4 tCO₂/t. Default values carry a mark-up of 10% above the country-specific average in 2026, rising to 20% in 2027 and 30% from 2028 onward under the same implementing regulation.
The four steps below describe how an importer calculates the certificate obligation for a hydrogen shipment.
- Obtain specific direct embedded emissions per tonne from the non-EU producer, or apply the IR 2025/2621 default value (10.4 tCO₂/t for SMR-based grey hydrogen, with the applicable year's mark-up).
- Multiply the specific emissions by the net mass of hydrogen imported in tonnes to arrive at total embedded emissions in tCO₂.
- Apply the current year's CBAM factor (2.5% in 2026, rising annually through 2034) to calculate the number of certificates to hold and ultimately surrender.
- Multiply by the CBAM certificate price, which for 2026 imports is the quarterly average of EU ETS auction clearing prices during the quarter of importation.
Verification of actual embedded emissions is mandatory before the annual declaration. Physical site visits to non-EU production installations are required for the first verification period. Verifier registration in the CBAM Registry opens September 1, 2026, giving verifiers 13 months to complete global site visits before the September 30, 2027 declaration deadline. Hydrogen importers relying on actual values should contract accredited verifiers now given verification costs of €5,000–50,000 per installation.
CBAM Importer Authorization Requirements for Hydrogen
Hydrogen importers must hold authorized CBAM declarant status before importing under the definitive phase. Full details on the authorization process are covered in the CBAM for EU importers guide, but the hydrogen-specific compliance steps below apply to every importer at CN code 2804 10 00.
The authorization requirements under Implementing Regulation (EU) 2025/486 apply in full. Importers must submit through the Authorization Management Module of the CBAM Registry, providing a valid EORI number, business registration documents, 5 years of clean customs and tax compliance history, and a description of the hydrogen imports planned including production installations and country of origin.
The specific documentation that hydrogen importers must prepare includes the following items.
- CN code classification records confirming all hydrogen imports fall under 2804 10 00
- Production route documentation from each non-EU supplier (grey SMR, blue SMR with CCS, or green electrolysis with RFNBO certification evidence)
- Monitoring plan reference from each non-EU production installation
- RFNBO certification documentation for green hydrogen (required to apply zero or near-zero embedded emission factors under Delegated Regulation (EU) 2023/1184)
- Article 9 deduction evidence, if the non-EU producer paid a qualifying carbon price in the country of origin
No hydrogen-exporting countries currently hold confirmed Article 9 deduction status. South Korea's K-ETS is under Commission assessment and is considered the most likely qualifying scheme among active CBAM-affected exporters. Morocco, Chile, and Saudi Arabia do not have nationally binding carbon pricing schemes as of April 2026, meaning hydrogen imports from those countries carry the full certificate obligation.
Caption: Electrolysis-based green hydrogen production with certified renewable inputs, illustrating how near-zero direct emissions arise under CBAM calculation methodology.
What CBAM Means for Future Hydrogen Import Strategies
Is Green Hydrogen Actually Zero-Cost Under CBAM?
Green hydrogen certified under the EU's RFNBO framework carries near-zero direct embedded emissions. The CBAM hydrogen sector guide explains the additionality, temporal correlation, and geographical correlation criteria that must be met for electrolysis-based hydrogen to qualify for the near-zero emission factor. When a non-EU producer meets all three criteria and obtains RFNBO certification under Delegated Regulation (EU) 2023/1184, the importer may declare direct embedded emissions approaching zero tCO₂/t H₂, resulting in a certificate obligation effectively at zero.
The near-zero figure is not absolute. Even certified green hydrogen can carry trace direct emissions from facility operations, compression, and auxiliary energy use. The monitoring methodology requires these to be accounted for separately from the electrolysis electricity source. Importers should obtain a complete monitoring plan from the non-EU producer confirming how these residual emissions are measured.
Does Grey Hydrogen Face the De Minimis Exemption?
Grey hydrogen importers do not benefit from the 50-tonne annual mass de minimis threshold. Hydrogen is explicitly excluded from the de minimis provision alongside electricity under Article 2(3a) of Regulation (EU) 2023/956 as amended. Every tonne of hydrogen imported from a non-exempt third country generates a CBAM certificate obligation regardless of total annual import volume.
This exclusion reflects the strategic importance of hydrogen as a future energy carrier. The Commission determined that a de minimis threshold would create a compliance gap for what is projected to become a high-volume commodity as EU hydrogen import infrastructure develops through the late 2020s.
How Do Default Values Affect Grey Hydrogen Importers?
Grey hydrogen importers using default values from IR 2025/2621 face embedded emissions of 10.4 tCO₂/t plus the applicable mark-up. In 2026 the default-based certificate calculation is 10.4 × 1.10 (10% mark-up) = 11.44 tCO₂/t per tonne of hydrogen. At €70/tCO₂ and the 2.5% CBAM factor, the net 2026 certificate cost under defaults is approximately €20 per tonne of hydrogen, a figure that rises significantly as the mark-up increases to 30% from 2028 and as the CBAM factor climbs through the free allocation phase-out schedule.
Importers with suppliers who can provide verified actual emissions data below the default have a growing financial incentive to measure. The gap between default and actual becomes especially material from 2027 onward as both the mark-up and the CBAM factor increase simultaneously.
Can Blue Hydrogen Reduce Certificate Costs Compared to Grey?
Blue hydrogen produced via SMR with carbon capture and storage carries direct embedded emissions of approximately 1–3 tCO₂/t H₂, representing a reduction of 70–90% compared to grey SMR. The precise figure depends on CCS capture efficiency at the specific installation. At €70/tCO₂ and 2.5% CBAM factor in 2026, blue hydrogen at 2 tCO₂/t generates a net certificate cost of approximately €3.50 per tonne compared to approximately €17.50 for grey hydrogen at 10 tCO₂/t. This gap widens proportionally as the free allocation factor increases through 2034. More detail on how embedded emissions are calculated across all production types is available in the guide to how embedded emissions are calculated.
Does the De Minimis Threshold Apply to Hydrogen Importers?
Hydrogen sits outside the de minimis threshold entirely. The CBAM de minimis threshold article explains which sectors qualify for the 50-tonne annual exemption and which do not. Hydrogen and electricity are the two sectors explicitly excluded, meaning authorization and declaration obligations apply to hydrogen importers from the first tonne regardless of import volume.
What Is the CBAM Cost Difference Between Green and Grey Hydrogen by 2030?
At the consensus forecast EU ETS price of approximately €126/tCO₂ by 2030 and the 48.5% CBAM factor in that year, grey hydrogen at 10 tCO₂/t generates a net certificate obligation of approximately 10 × 48.5% × €126 = €611 per tonne. Green hydrogen at near-zero direct emissions generates a net certificate obligation approaching zero. The structural cost differential between green and grey hydrogen imports exceeds €600 per tonne by 2030 under these projections. Hydrogen importers making sourcing decisions in 2026 should model this trajectory across a range of ETS price scenarios rather than treating the current €70/tCO₂ reference as a static input.
Information on how the green hydrogen trade relationship interacts with CBAM compliance is covered in the green hydrogen and CBAM guide, and the full cost and compliance profile for grey hydrogen importers appears in the grey hydrogen and CBAM guide.