Regional spotlight: Carbon capture, utilization & storage (CCUS) in EU — what's different and why it matters

The European Union's approach to carbon capture, utilization, and storage (CCUS) diverges sharply from the trajectory playing out in North America and the Middle East. While the US leans heavily on generous tax incentives through the 45Q credit and the Inflation Reduction Act to attract private capital, the EU has constructed a regulatory architecture that couples CCUS deployment with binding emissions reduction targets, cross-border infrastructure mandates, and industrial decarbonization obligations. The result is a CCUS landscape shaped less by subsidy economics and more by regulatory compulsion, strategic infrastructure planning, and an emerging framework for CO2 transport and storage as a shared European utility. Understanding these distinctions is essential for sustainability leaders evaluating CCUS partnerships, investments, or supply chain decarbonization strategies with European exposure.

Why It Matters

The EU Emissions Trading System (ETS), the world's largest carbon market, reached sustained prices above EUR 60 per tonne of CO2 through 2025, with forward curves projecting EUR 80-100 by 2030 as the Market Stability Reserve continues to tighten supply. At these price levels, CCUS becomes economically rational for cement, steel, refining, and chemical production facilities that face abatement costs exceeding EUR 70 per tonne through alternative means. This price signal is fundamentally different from the US, where the 45Q credit provides a fixed $85 per tonne for geological storage regardless of prevailing carbon prices.

The European Commission's Industrial Carbon Management Strategy, adopted in February 2024, established a target of 50 million tonnes of annual CO2 storage capacity by 2030 and 280 million tonnes by 2040. These targets carry regulatory weight: the Net-Zero Industry Act requires that member states contribute to collective storage capacity, and the revised CCS Directive mandates that holders of oil and gas production licenses assess their depleted reservoirs for CO2 storage suitability. For the first time, there is a binding obligation on hydrocarbon producers to make subsurface assets available for carbon storage, a provision with no equivalent in US or Asian regulatory frameworks.

EU industrial emitters face a convergence of pressures that make CCUS not optional but structurally necessary. The Carbon Border Adjustment Mechanism (CBAM), fully operational from 2026, ensures that imported goods face equivalent carbon costs, removing the competitive disadvantage argument that historically stalled European CCUS investment. Simultaneously, the revision of the Industrial Emissions Directive requires best available techniques (BAT) assessments for major installations, with CCUS increasingly recognized as BAT for cement and lime production where process emissions cannot be eliminated through electrification or fuel switching.

Key Concepts

EU ETS as a CCUS Price Signal operates differently from direct subsidy mechanisms. Rather than guaranteeing a fixed payment per tonne of CO2 captured, the ETS creates a cost of emitting that industrial operators must either pay through purchasing allowances or avoid through abatement. CCUS becomes attractive when the capture and storage cost falls below the ETS allowance price. With ETS prices projected to exceed EUR 80 by 2028, and capture costs for concentrated industrial sources (cement, hydrogen production, ammonia) ranging from EUR 40-80 per tonne, the economic case for CCUS at these facilities has crossed the viability threshold without requiring additional grant funding.

Cross-Border CO2 Transport Infrastructure represents a distinctly European approach to CCUS deployment. The EU has designated several CO2 transport corridors as Projects of Common Interest (PCIs) eligible for Connecting Europe Facility funding, including the Northern Lights pipeline system connecting Norwegian offshore storage with emitters across Northwest Europe, and the Aramis project linking Dutch and German industrial clusters to North Sea storage. This networked approach contrasts with the point-to-point pipeline model dominant in North America, where individual project developers must secure their own transport and storage arrangements.

Contracts for Difference (CfDs) for Industrial Decarbonization provide a bridge mechanism where ETS prices remain below breakeven levels for specific CCUS applications. The EU Innovation Fund has allocated EUR 4 billion for large-scale CCUS projects through competitive CfD auctions, guaranteeing a strike price that covers the gap between capture costs and prevailing carbon prices. The Netherlands, Denmark, and Germany have implemented national CfD programs (SDE++, CCSF, and Klimaschutzvertrage respectively) that complement EU-level support, creating layered incentive structures without replicating the single-instrument approach of the US 45Q credit.

Geological Storage Regulation Under the CCS Directive establishes a comprehensive legal framework for CO2 storage that exceeds requirements in most other jurisdictions. Storage operators must obtain permits requiring detailed geological characterization, risk assessments, monitoring plans, corrective measures protocols, and financial security covering post-closure obligations for a minimum of 20 years. The directive also establishes liability transfer mechanisms where, after a defined post-closure period and regulatory approval, responsibility for stored CO2 transfers from the operator to the member state. This long-term liability framework provides investment certainty that project-by-project arrangements in other regions cannot match.

EU CCUS KPIs: Benchmark Ranges

Metric	Below Average	Average	Above Average	Top Quartile
Capture Cost (Cement/Lime)	>EUR 80/t	EUR 60-80/t	EUR 45-60/t	<EUR 45/t
Capture Cost (Hydrogen/Ammonia)	>EUR 60/t	EUR 40-60/t	EUR 30-40/t	<EUR 30/t
Transport Cost (Pipeline, per 100 km)	>EUR 12/t	EUR 8-12/t	EUR 5-8/t	<EUR 5/t
Storage Cost (Offshore Saline Aquifer)	>EUR 20/t	EUR 12-20/t	EUR 8-12/t	<EUR 8/t
ETS Breakeven Margin	Negative	EUR 0-10/t	EUR 10-25/t	>EUR 25/t
Permitting Timeline (Storage Site)	>6 years	4-6 years	3-4 years	<3 years
Capture Rate Achieved	<85%	85-90%	90-95%	>95%

What's Working

Northern Lights: The Shared Infrastructure Model

Northern Lights, the joint venture between Equinor, Shell, and TotalEnergies, represents the most advanced open-access CO2 transport and storage project globally. Phase 1, operational from 2024, provides 1.5 million tonnes per year of storage capacity in saline aquifers beneath the Norwegian continental shelf. Phase 2, sanctioned in 2025, expands capacity to 5 million tonnes per year. The project accepts CO2 from any qualified emitter in Europe via ship transport, eliminating the need for individual emitters to develop their own storage solutions. Heidelberg Materials signed the first commercial contract to transport CO2 from its Brevik cement plant in Norway, capturing approximately 400,000 tonnes annually using amine-based post-combustion technology. The Brevik project achieved 95% capture rates during commissioning, validating full-scale cement CCUS at commercial conditions.

Dutch CCUS Cluster Development

The Netherlands has emerged as the EU's CCUS pacesetter through deliberate industrial cluster strategy. The Porthos project in the Port of Rotterdam will capture approximately 2.5 million tonnes of CO2 per year from four industrial facilities (Air Liquide, Air Products, ExxonMobil, and Shell) and transport it via a shared pipeline to depleted gas fields in the North Sea. The Dutch SDE++ subsidy scheme awarded Porthos a 15-year CfD contract, providing revenue certainty independent of ETS price fluctuations. The Aramis project, also in Rotterdam, plans an additional 5 million tonnes per year of transport and storage capacity by 2030. Together, these projects transform Rotterdam from Europe's largest emissions cluster into a potential decarbonization hub, demonstrating how coordinated industrial policy can reshape legacy fossil fuel infrastructure.

Danish Full-Value-Chain Projects

Denmark authorized its first CO2 storage licenses in 2023, with Project Greensand achieving the first offshore CO2 injection in the Danish North Sea using repurposed oil infrastructure. The INEOS-operated project demonstrated that depleted oil reservoirs in the Danish sector can safely store CO2, with monitoring confirming containment integrity through multiple injection cycles. Denmark's approach is notable for its speed: the permitting process from application to injection authorization took approximately 18 months, compared to multi-year timelines in other jurisdictions. The Danish Energy Agency has offered additional storage licenses with a combined potential capacity exceeding 20 million tonnes per year, positioning Denmark as a major storage destination for Northern European emitters.

What's Not Working

Permitting Delays and Public Acceptance

Despite supportive policy frameworks, CCUS permitting in several EU member states remains slow and contentious. Germany's CCS law historically prohibited onshore CO2 storage, and while the government proposed legislative reform in 2024, political opposition from state governments and environmental organizations continues to delay approval. The result is that German industrial emitters must plan for CO2 export to offshore storage in Norway, Denmark, or the Netherlands, adding EUR 15-25 per tonne in transport costs compared to domestic storage. Public opposition to onshore CO2 pipelines in Belgium and the Netherlands has forced route modifications and extended project timelines by 12-24 months, increasing costs and creating investment uncertainty.

Capture Technology Cost Reduction Pace

First-generation amine-based capture systems dominate EU projects, but costs have declined more slowly than projected. The anticipated learning curve from first-of-a-kind to Nth-of-a-kind plants has not materialized as rapidly as solar or wind cost reductions. Shell's Quest facility in Canada, often cited as a benchmark, achieved capture costs of approximately CAD 80 per tonne after optimization, but European projects face higher labor, materials, and regulatory compliance costs. Second-generation capture technologies (calcium looping, membrane systems, and direct separation reactors) remain at pilot or demonstration scale in Europe, with commercial deployment timelines extending to 2030-2032.

Utilization Pathway Limitations

The "U" in CCUS remains underdeveloped in the EU context. CO2 utilization in synthetic fuels (e-fuels) requires green hydrogen at costs that remain above EUR 4 per kilogram, making e-fuel production uneconomic without substantial subsidies. Mineral carbonation, where CO2 reacts with industrial wastes to produce construction aggregates, operates at small scale with limited market uptake. The European Commission's emphasis on permanent geological storage reflects a pragmatic assessment that utilization pathways cannot absorb the volumes necessary for industrial decarbonization. Current EU utilization capacity stands at approximately 500,000 tonnes per year, less than 1% of the 2030 storage target.

Key Players

Industrial Emitters and Capture Developers

Heidelberg Materials operates the Brevik CCS project, the world's first full-scale cement carbon capture facility, and has announced capture feasibility studies at plants in Germany, Poland, and the UK.

BASF is developing capture technology for its Ludwigshafen chemical complex, the largest integrated chemical site in Europe, targeting 1-2 million tonnes per year of CO2 capture by 2030.

ArcelorMittal is piloting the Steelanol project in Ghent, Belgium, capturing carbon-rich waste gases from blast furnace operations and converting them to ethanol, combining capture with utilization.

Transport and Storage Operators

Equinor leads the Northern Lights joint venture and holds operatorship of Norway's largest CO2 storage reservoirs, positioning the company as Europe's dominant storage service provider.

Wintershall Dea (now merged with Harbour Energy) developed the Greensand project infrastructure and holds storage exploration licenses across the Danish and Norwegian continental shelves.

Gasunie and Fluxys, the Dutch and Belgian gas transmission operators, are repurposing natural gas pipeline infrastructure for CO2 transport, leveraging existing rights-of-way and engineering expertise.

Investors and Public Funders

EU Innovation Fund has allocated over EUR 4 billion to CCUS projects through four rounds of large-scale project funding, making it the single largest public funding source for European CCUS.

European Investment Bank provides concessional lending and guarantees for CCUS infrastructure classified as Projects of Common Interest under EU energy policy.

Climate Investment Platform coordinates blended finance structures combining EU grants, national subsidies, and private capital for first-of-a-kind CCUS installations.

Action Checklist

• Map your European facilities' emissions profiles against ETS forward curves to identify sites where CCUS reaches positive net present value before 2030
• Evaluate access to planned CO2 transport corridors (Northern Lights, Porthos, Aramis) and assess logistics costs for connecting your facilities
• Review national CfD and subsidy programs in your operating jurisdictions (SDE++, CCSF, Klimaschutzvertrage) for application windows and eligibility
• Assess whether your Best Available Techniques reference documents (BREFs) will mandate CCUS consideration at next permit renewal
• Engage with storage operators to secure capacity reservations, as available permitted storage is expected to tighten significantly after 2028
• Develop internal expertise in EU CCS Directive compliance requirements, including monitoring, reporting, and financial security obligations
• Evaluate CBAM exposure for imported products and determine whether CCUS at supplier facilities affects your competitive position
• Commission feasibility studies for capture technology selection, prioritizing vendors with demonstrated performance at European reference plants

FAQ

Q: How does the EU ETS compare to the US 45Q credit as a driver for CCUS investment? A: The EU ETS provides a market-based price signal that fluctuates with supply and demand, currently around EUR 60-70 per tonne with projections above EUR 80 by 2028. The US 45Q offers a fixed $85 per tonne for geological storage. For high-concentration CO2 sources (hydrogen, ammonia, ethanol), the US incentive is more generous and certain. For cement and steel with capture costs of EUR 60-80, the EU ETS must reach the upper range of projections to provide comparable returns. However, the EU's complementary CfD mechanisms close this gap by guaranteeing strike prices that cover the differential.

Q: Can EU emitters access storage outside their own member state? A: Yes, and cross-border CO2 transport is actively encouraged. The London Protocol was amended to permit cross-border CO2 transport for sub-seabed storage, and the EU has designated multiple cross-border CO2 corridors as Projects of Common Interest. Northern Lights explicitly serves as a multi-country storage destination. However, emitters must comply with the waste shipment regulation's notification requirements and ensure the receiving country's storage permits meet CCS Directive standards.

Q: What is the realistic timeline for a new CCUS project in the EU from concept to operation? A: Plan for 5-8 years for a full-chain project including capture, transport, and storage. Capture technology selection and front-end engineering design typically require 18-24 months. Environmental impact assessments and permitting add 12-36 months depending on jurisdiction and whether onshore or offshore. Construction requires 24-36 months. Projects connecting to existing transport and storage infrastructure (such as Northern Lights) can compress timelines to 4-5 years by eliminating the storage development phase.

Q: How does CBAM affect the business case for European CCUS versus relocating production? A: CBAM ensures that imported goods entering the EU face carbon costs equivalent to ETS prices, eliminating the cost advantage of producing in jurisdictions without carbon pricing. This means that relocating cement, steel, or chemical production outside the EU no longer avoids carbon costs on goods sold in the European market. CCUS at existing European facilities therefore becomes a competitive strategy rather than a cost burden, particularly for producers serving European customers.

Q: What are the long-term liability implications for companies investing in CO2 storage in the EU? A: Under the CCS Directive, storage operators bear liability during the injection period and for a minimum of 20 years post-closure. After this period, if monitoring demonstrates that stored CO2 is behaving as predicted and all conditions are met, liability transfers to the relevant member state government. This transfer mechanism is unique to the EU and significantly reduces the long-term risk profile for storage investors compared to jurisdictions where perpetual private liability applies.

Sources

• European Commission. (2024). Industrial Carbon Management Strategy. Brussels: European Commission, DG CLIMA.
• International Energy Agency. (2025). CCUS in Clean Energy Transitions: European Regional Assessment. Paris: IEA Publications.
• Northern Lights JV. (2025). Annual Report 2024: Operations and Commercial Agreements. Stavanger: Northern Lights DA.
• Global CCS Institute. (2025). Global Status of CCS 2025: Europe Chapter. Melbourne: Global CCS Institute.
• European Commission. (2023). Regulation (EU) 2023/956: Carbon Border Adjustment Mechanism. Official Journal of the European Union.
• Heidelberg Materials. (2025). Brevik CCS Project: First Year Operational Performance Report. Heidelberg: Heidelberg Materials AG.
• Netherlands Enterprise Agency. (2025). SDE++ 2024 Results: Carbon Capture and Storage Allocations. The Hague: RVO.