Operational playbook: scaling Carbon capture, utilization & storage (CCUS) from pilot to rollout

Europe's industrial sector emits roughly 780 million tonnes of CO2 annually, yet as of early 2026 only 4 million tonnes per year (Mtpa) of carbon capture capacity is operational on the continent, capturing barely 0.5% of what must be abated to meet the EU's 2040 climate targets. The International Energy Agency projects that Europe needs at least 80 Mtpa of operational CCUS capacity by 2035 to stay on a net-zero trajectory, meaning procurement teams across cement, steel, chemicals, and power generation face an unprecedented scaling challenge over the next decade. This playbook provides a structured, procurement-focused framework for taking CCUS initiatives from early assessment through pilot deployment and into full-scale rollout, with emphasis on European regulatory requirements, vendor selection, and the financial mechanics that determine whether a CCUS project reaches final investment decision.

Why It Matters

Industrial decarbonisation in Europe has reached a critical inflection point. The EU Emissions Trading System (EU ETS) allowance price averaged approximately 65 euros per tonne of CO2 in 2025, down from peaks above 100 euros in 2023 but still well above the 30 to 50 euro range that prevailed before 2021. With the Market Stability Reserve continuing to tighten supply and the Carbon Border Adjustment Mechanism (CBAM) entering its definitive phase from January 2026, the cost of unabated emissions is structurally rising for hard-to-abate sectors. For a cement plant emitting 600,000 tonnes of CO2 per year, every 10-euro increase in the EU ETS allowance price adds 6 million euros to annual compliance costs.

CCUS offers one of the few technically proven pathways for eliminating process emissions from cement, steel, and chemical production, sectors where electrification or fuel switching cannot address CO2 released from chemical reactions in raw materials. The European Commission's Industrial Carbon Management Strategy, published in February 2024, set a target of 50 Mtpa of CO2 injection capacity by 2030, supported by the Net-Zero Industry Act's requirement that EU oil and gas producers make storage capacity available at scale.

For procurement professionals, the strategic imperative is clear: organisations that secure CCUS transport and storage capacity early will lock in favourable tariffs and de-risk their decarbonisation pathways, while those that delay face rising costs and potential stranded asset risk. The Northern Lights project in Norway, a joint venture between Equinor, Shell, and TotalEnergies, began commercial operations in late 2024 with Phase 1 capacity of 1.5 Mtpa and has already contracted with emitters including Heidelberg Materials and Yara International, demonstrating that first-mover procurement advantage is real and measurable.

Key Concepts

Point-Source Capture: The process of separating CO2 from flue gases at industrial facilities. Dominant technologies include amine-based post-combustion capture (used at Heidelberg Materials' Brevik plant in Norway), oxyfuel combustion, and pre-combustion capture via autothermal reforming. Capture rates of 90% or higher are now standard in commercial contracts, with some next-generation solvents and membranes targeting 95% or above.

CO2 Transport: Captured CO2 must be compressed, purified, and transported to storage sites via pipeline or ship. Pipeline transport is cost-effective for distances under 300 kilometres and volumes above 2 Mtpa. Ship transport, as deployed by Northern Lights using converted LPG carriers, provides flexibility for distributed emitters and cross-border flows. The EU CO2 transport network is expected to reach approximately 7,500 kilometres of pipeline by 2035, according to European Commission modelling.

Geological Storage: Permanent sequestration in deep saline aquifers or depleted oil and gas reservoirs. The EU CCS Directive (2009/31/EC) governs site selection, permitting, monitoring, and long-term liability transfer. Storage operators must demonstrate containment security through seismic surveys, well integrity testing, and pressure monitoring for a minimum of 20 years post-injection before liability transfers to the host state.

Transport and Storage Tariffs: The commercial price that emitters pay per tonne of CO2 transported and stored. Northern Lights Phase 1 tariffs are estimated in the range of 50 to 80 euros per tonne, declining to 30 to 50 euros per tonne at scale. The Porthos project in Rotterdam targets tariffs below 50 euros per tonne for its initial 2.5 Mtpa capacity serving four industrial emitters in the Rotterdam port area.

Final Investment Decision (FID): The formal corporate or consortium decision to commit capital to a CCUS project, typically requiring secured offtake agreements, regulatory permits, and confirmed financing. European CCUS projects typically require 3 to 5 years from concept to FID, with permitting alone consuming 18 to 36 months depending on jurisdiction.

Prerequisites

Before launching a CCUS procurement initiative, organisations must have several foundational elements in place. A detailed Scope 1 emissions inventory, broken down by facility, process, and CO2 source (combustion versus process emissions), is essential for sizing capture equipment and estimating costs. Internal carbon pricing or shadow carbon pricing aligned with EU ETS forecasts enables accurate business case modelling.

Procurement teams need board-level endorsement of CCUS as a strategic decarbonisation pathway, typically embedded in a validated net-zero transition plan. Access to engineering consultancy support for front-end engineering design (FEED) studies is required, as CCUS projects involve bespoke integration with existing industrial processes. Legal capacity to negotiate long-term CO2 offtake agreements (typically 15 to 25 years) and familiarity with the EU CCS Directive's permitting and liability framework round out the prerequisites.

Organisations should also assess proximity to planned or operational CO2 transport infrastructure. The European Commission's Projects of Common Interest (PCI) list includes multiple CO2 transport corridors, and awareness of these planned networks informs site-level investment decisions.

Step-by-Step Implementation

Phase 1: Assessment and Planning

Begin with a comprehensive emissions mapping exercise. For each facility, quantify annual CO2 volumes, concentration levels in flue gas (higher concentrations reduce capture costs), and physical site constraints. Cement kilns typically produce flue gas with 15 to 30% CO2 concentration, while steel blast furnaces range from 20 to 27%, both significantly higher than the 4 to 8% typical of gas-fired power plants. This concentration differential materially affects capture technology selection and cost.

Develop a long-range EU ETS price scenario model spanning 2026 to 2040. The European Commission's reference scenario projects prices reaching 130 to 150 euros per tonne by 2040. Compare projected compliance costs under a no-abatement scenario against the total cost of CCUS deployment (capture CAPEX, OPEX, transport, and storage tariffs) to establish the break-even carbon price for your specific facilities.

Identify potential transport and storage providers. As of early 2026, the primary European options include Northern Lights (Norway, operational), Porthos (Netherlands, FID taken in 2023, operations expected 2026), Greensand (Denmark, pilot completed, scaling), and Ravenna CCS (Italy, Eni-led, Phase 1 targeting 4 Mtpa). Map your facilities to the nearest transport corridor and request indicative tariff quotes from storage operators.

Phase 2: Pilot Design

Select a single facility with the most favourable characteristics for a capture pilot: high CO2 concentration, adequate physical space for capture equipment, proximity to transport infrastructure, and a supportive local permitting environment. Heidelberg Materials chose its Brevik cement plant in Norway for precisely these reasons, achieving a full-scale capture installation processing 400,000 tonnes of CO2 per year.

Issue a request for proposals (RFP) to capture technology providers. Leading European suppliers include Aker Carbon Capture (modular amine-based systems), Mitsubishi Heavy Industries (KM CDR Process), and Linde Engineering. Evaluation criteria should weight capture rate guarantees (minimum 90%), energy consumption per tonne captured (target below 2.5 GJ per tonne for amine systems), solvent degradation rates, and demonstrated operational hours at comparable facilities.

Negotiate a CO2 offtake agreement with a transport and storage provider. Key commercial terms include volume commitments (minimum annual quantities and take-or-pay provisions), tariff structure (fixed versus indexed to EU ETS price), CO2 purity specifications (typically above 95% with strict limits on water, H2S, and NOx), delivery point definitions, and liability allocation during transport.

Secure regulatory permits. Under the EU CCS Directive, capture facilities require environmental impact assessments and operating permits from national authorities. In Norway, the Ministry of Energy oversees CCS permitting with typical timelines of 18 to 24 months. In the Netherlands, the State Supervision of Mines (SodM) manages storage permits. Cross-border CO2 transport requires notification under the London Protocol, which was amended in 2009 to permit such movements.

Phase 3: Execution and Measurement

During construction and commissioning (typically 24 to 36 months for a full-scale capture plant), establish a rigorous measurement, reporting, and verification (MRV) framework. The EU Monitoring and Reporting Regulation specifies how captured and stored CO2 is accounted for under the EU ETS. Only CO2 that is verifiably transferred to a permitted storage site and permanently sequestered can be deducted from an installation's reported emissions.

ArcelorMittal provides an instructive example. The steelmaker's Ghent facility in Belgium is deploying Mitsubishi Heavy Industries' capture technology as part of the Steelanol and Carbon2Value projects, targeting capture of up to 1 Mtpa. Their measurement framework integrates continuous emissions monitoring systems (CEMS) at the capture outlet, flow metering at the transport handover point, and reconciliation with storage operator injection data.

Track key operational metrics from day one: capture uptime (target above 85% in year one, rising to 92% or higher by year three), actual versus design capture rate, energy penalty (parasitic load from the capture process as a percentage of facility output), solvent or sorbent consumption rates, and total cost per tonne captured. These metrics form the evidence base for scaling decisions.

Conduct quarterly procurement reviews comparing actual tariffs and operational costs against business case assumptions. EU ETS price movements may shift the economic case materially. If allowance prices rise faster than projected, the case for accelerated rollout strengthens. If prices decline, stress-test the project's resilience against downside scenarios.

Phase 4: Scale and Optimize

With 12 to 18 months of operational data from the pilot, prepare a scaling strategy. This typically involves replicating capture installations at additional facilities, negotiating increased volume commitments with transport and storage providers (capturing volume discounts), and potentially co-investing in shared transport infrastructure.

The Antwerp@C consortium illustrates this approach. Led by major industrial emitters in the Port of Antwerp including BASF, INEOS, ExxonMobil, and TotalEnergies, the project plans a shared CO2 collection network connecting multiple capture facilities to export terminals for ship-based transport to North Sea storage sites. By aggregating volumes from multiple emitters, the consortium reduces per-tonne transport costs by an estimated 20 to 30% compared to standalone solutions.

Explore CO2 utilisation pathways as supplementary revenue streams. While geological storage remains the primary permanent abatement pathway, some captured CO2 can be directed to mineralisation (producing building materials), synthetic fuel production, or greenhouse horticulture. These applications should be evaluated on their climate permanence, with procurement teams applying the EU's carbon removal certification framework to assess genuine climate benefit.

Engage with emerging hub-and-cluster developments. The European Commission's first Innovation Fund large-scale call allocated over 1.8 billion euros to CCUS projects in 2024 and 2025, with significant funding flowing to industrial clusters in the North Sea region, the Iberian Peninsula, and the Baltic corridor. Position your organisation within these clusters to access shared infrastructure and public co-financing.

Vendor / Partner Evaluation Checklist

• Demonstrated capture technology at commercial scale (minimum 100,000 tonnes per year reference plant with 12+ months of continuous operation)
• Guaranteed capture rate of 90% or higher with contractual performance penalties for underperformance
• Energy consumption below 2.5 GJ per tonne of CO2 captured for amine-based systems, with clear heat integration proposals
• Storage operator holding a valid EU CCS Directive storage permit with completed site characterisation (3D seismic, appraisal wells, dynamic reservoir modelling)
• Financial strength to honour long-term offtake agreements (minimum investment-grade credit rating or equivalent financial security)
• Transparent tariff structure with clear escalation mechanisms tied to recognised indices (EU ETS price, inflation, energy costs)
• Compliance with the EU Monitoring and Reporting Regulation for CO2 transport and storage accounting
• Insurance coverage for leakage events during transport and injection, with defined liability caps and transfer mechanisms
• Track record of regulatory engagement with relevant national authorities (Norwegian Petroleum Directorate, Dutch SodM, UK NSTA)
• Membership in industry bodies such as the Global CCS Institute, Zero Emissions Platform, or CCUS industry associations demonstrating commitment to best practices

Common Failure Modes

Underestimating permitting timelines. European CCUS projects consistently experience permitting delays. The Porthos project required over four years from initial application to final investment decision, partly due to a nitrogen deposition challenge in Dutch courts. Procurement teams should build 12 to 18 months of buffer into project schedules and engage proactively with regulators during the pre-application phase.

Misaligned volume commitments. Take-or-pay provisions in CO2 offtake agreements expose emitters to financial risk if capture operations underperform. Heidelberg Materials' Brevik project negotiated flexible ramp-up provisions to mitigate this risk. Procurement teams should negotiate volume flexibility corridors (typically plus or minus 15 to 20% of annual contracted volumes) and align contractual milestones with capture plant commissioning schedules.

Ignoring heat integration requirements. Amine-based capture systems require significant low-grade heat (typically 100 to 120 degrees Celsius steam) to regenerate the solvent. If this heat is diverted from existing industrial processes, it reduces facility output and erodes the business case. Successful projects like Brevik integrate waste heat recovery or dedicated heat sources into the capture plant design from the outset.

Neglecting CO2 purity specifications. Impurities in captured CO2 (water, SOx, NOx, heavy metals) can cause pipeline corrosion, compressor fouling, and storage reservoir contamination. Northern Lights specifies CO2 purity above 99.7% with strict limits on 14 contaminant species. Procurement teams must ensure capture technology suppliers guarantee compliance with transport operator purity requirements, as retrofitting purification equipment adds significant cost and delay.

Failing to plan for long-term liability transfer. Under the EU CCS Directive, storage operators bear liability for stored CO2 for a minimum of 20 years post-closure before liability can transfer to the host Member State. This extended liability period affects project economics and insurance requirements. Procurement contracts should clearly delineate which party bears liability at each stage of the value chain.

Over-reliance on a single storage site. Geological risks, regulatory changes, or operator insolvency can disrupt access to a specific storage location. Diversifying across multiple storage operators or maintaining contractual rights to alternative sites reduces concentration risk. The Global CCS Institute recommends that large emitters secure access to at least two independent storage complexes.

KPIs to Track

KPI	Target Range	Measurement Frequency
CO2 capture rate (% of flue gas CO2 captured)	90 to 95%	Continuous (CEMS)
Capture plant uptime	85 to 95%	Monthly
Energy penalty (GJ per tonne CO2 captured)	2.0 to 3.0 GJ/t	Monthly
Total cost per tonne captured, transported, and stored	50 to 120 euros/t	Quarterly
EU ETS break-even price (carbon price at which CCUS is NPV-positive)	<80 euros/t	Annually
Solvent or sorbent consumption rate	Per vendor specification	Monthly
CO2 purity at transport handover point	>99% (vol)	Per shipment/batch
Permitting milestone adherence	On schedule or <3 months variance	Quarterly
Contracted storage capacity utilisation	70 to 90% of annual commitment	Annually
Scope 1 emissions reduction attributable to CCUS	40 to 90% of facility total	Annually

Action Checklist

1. Complete a facility-level Scope 1 emissions inventory identifying CO2 volumes, concentrations, and process sources at each candidate site
2. Model EU ETS price scenarios from 2026 to 2040 and calculate the break-even carbon price at which CCUS deployment becomes NPV-positive for your highest-emitting facilities
3. Map proximity of your facilities to planned or operational CO2 transport infrastructure (Northern Lights, Porthos, Antwerp@C, Delta Rhine Corridor)
4. Issue a request for information (RFI) to at least three capture technology providers, specifying your flue gas composition, volume, and site constraints
5. Request indicative transport and storage tariff quotes from at least two storage operators, including Northern Lights and one additional European provider
6. Engage legal counsel experienced in EU CCS Directive permitting to prepare a regulatory roadmap with milestone dates and risk assessment
7. Secure board-level approval for a CCUS feasibility study, including budget for front-end engineering design (FEED) work at the lead candidate facility
8. Negotiate heads of terms for a CO2 offtake agreement, focusing on volume flexibility, tariff escalation mechanisms, purity specifications, and liability allocation
9. Establish an internal CCUS project team with representation from procurement, engineering, legal, finance, and sustainability functions
10. Develop a monitoring and verification framework aligned with the EU Monitoring and Reporting Regulation, including continuous emissions monitoring system specifications and data reconciliation protocols

FAQ

Q: What is the realistic cost range for CCUS in European industrial applications as of 2026?

A: Total costs vary significantly by sector and configuration. Capture costs alone range from 40 to 60 euros per tonne for high-concentration sources (cement, steel) to 80 to 120 euros per tonne for lower-concentration applications (gas-fired power). Transport adds 5 to 15 euros per tonne for pipeline distances under 300 kilometres or 15 to 30 euros per tonne for ship-based transport. Storage tariffs range from 10 to 25 euros per tonne depending on reservoir characteristics and operator. All-in costs for a well-integrated industrial project in northwest Europe currently fall between 70 and 130 euros per tonne, with next-generation technologies targeting costs below 50 euros per tonne by 2035.

Q: How does the EU ETS interact with CCUS investment decisions?

A: CO2 that is captured and permanently stored in a permitted geological site is deducted from an installation's reported emissions under the EU ETS Monitoring and Reporting Regulation. This means emitters avoid purchasing allowances for stored CO2, creating a direct financial benefit equal to the prevailing allowance price. When the EU ETS price exceeds the all-in cost of CCUS, the investment becomes financially attractive without additional subsidies. The EU ETS also provides indirect support through the Innovation Fund, which is financed by auction revenues and has allocated over 4 billion euros to CCUS and related projects since 2020.

Q: What are the key differences between pipeline and ship-based CO2 transport for procurement planning?

A: Pipeline transport offers lower per-tonne costs (5 to 15 euros) but requires high upfront capital investment, long construction timelines (3 to 5 years), and minimum throughput volumes (typically 2 Mtpa or above) to achieve economic viability. Ship transport provides flexibility for smaller volumes (from 0.1 Mtpa), cross-border movements, and phased deployment, but at higher per-tonne costs (15 to 30 euros) and with additional liquefaction and terminal infrastructure requirements. Northern Lights has demonstrated ship-based transport from continental Europe to Norwegian storage sites, while the Delta Rhine Corridor project plans a dedicated CO2 pipeline from the German Ruhr region to Rotterdam. Procurement teams should evaluate both options based on their specific volume profiles, geographic constraints, and scaling trajectories.

Q: How long does it take to secure a storage permit in Europe?

A: Timelines vary considerably by jurisdiction. In Norway, the Ministry of Energy has processed CCS permits within 18 to 24 months, benefiting from decades of offshore regulatory experience. In the Netherlands, the Porthos project's permitting process extended beyond 36 months due to legal challenges related to nitrogen deposition rules. The UK North Sea Transition Authority has targeted 12 to 18 months for carbon storage licence awards. Across the EU, the CCS Directive requires environmental impact assessments, public consultations, and demonstration of financial security before permits are issued. Procurement teams should engage pre-application consultations with regulators at least 6 months before formal submission.

Q: What happens to liability for stored CO2 after injection ceases?

A: Under the EU CCS Directive, the storage operator retains responsibility for monitoring and remediation for a minimum of 20 years following site closure. After this period, if the operator can demonstrate that stored CO2 is behaving as modelled and that all evidence indicates permanent containment, liability transfers to the competent authority of the host Member State. The operator must also make a financial contribution to cover anticipated post-transfer monitoring costs. For procurement teams negotiating offtake agreements, it is critical to understand which party bears responsibility during each phase and to ensure contractual indemnification provisions align with the Directive's liability framework.

Sources

• International Energy Agency. "CCUS in Clean Energy Transitions." IEA Energy Technology Perspectives, 2024. https://www.iea.org/reports/ccus-in-clean-energy-transitions

• Global CCS Institute. "Global Status of CCS 2025." Global CCS Institute, 2025. https://www.globalccsinstitute.com/resources/global-status-of-ccs/

• European Commission. "Industrial Carbon Management Strategy." COM(2024) 62 final, February 2024. https://climate.ec.europa.eu/eu-action/industrial-carbon-management_en

• Northern Lights JV. "Northern Lights Project Overview and Commercial Framework." 2025. https://norlights.com/

• Equinor. "Northern Lights: The World's First Open-Source CO2 Transport and Storage Infrastructure." 2025. https://www.equinor.com/energy/northern-lights

• European Parliament and Council. "Directive 2009/31/EC on the Geological Storage of Carbon Dioxide (EU CCS Directive)." Official Journal of the European Union, 2009. https://eur-lex.europa.eu/legal-content/EN/TXT/?uri=CELEX:32009L0031

• Heidelberg Materials. "Brevik CCS Project: Full-Scale Carbon Capture at Cement Production." 2025. https://www.heidelbergmaterials.com/en/carbon-capture-storage-brevik

• Porthos CCS. "CO2 Transport and Storage in the Port of Rotterdam." 2025. https://www.porthosco2.nl/en/