Explainer: Carbon transport & storage infrastructure — what it is, why it matters, and how to evaluate options

Global CO2 capture capacity reached 49 million tonnes per year in 2025, but only 30% of that captured carbon has dedicated transport and storage infrastructure to handle it at scale. The bottleneck in carbon capture and storage is no longer the capture technology itself: it is getting CO2 from where it is captured to where it can be permanently stored underground. Carbon transport and storage infrastructure encompasses the pipelines, ships, trucks, rail systems, injection wells, and geological reservoirs that move and sequester CO2. Without this midstream and downstream infrastructure, even the most efficient capture facilities have nowhere to send their emissions.

Why It Matters

The Intergovernmental Panel on Climate Change (IPCC) estimates that meeting 1.5°C targets requires sequestering 6 to 10 gigatonnes of CO2 annually by 2050. Current global storage capacity stands at roughly 45 million tonnes per year, meaning a 100x to 200x scale-up is needed in 25 years. The transport and storage layer determines whether that scale-up is physically and economically achievable.

For sustainability professionals, this infrastructure shapes three critical decisions. First, it determines the cost floor for carbon removal credits: transport and storage typically account for 30% to 50% of total CCS project costs. Second, it dictates which industrial clusters can decarbonize affordably, since proximity to storage sites or pipeline networks directly impacts economics. Third, it creates long-duration liability frameworks that require new approaches to risk management and regulatory compliance.

The policy environment is accelerating investment. The US Inflation Reduction Act increased the 45Q tax credit for geological storage to $85 per tonne. The EU's Net-Zero Industry Act targets 50 million tonnes of annual CO2 injection capacity by 2030. The UK's Track-1 and Track-2 cluster programs are committing billions in public funding. These regulatory signals are converting carbon transport and storage from a research topic into an infrastructure buildout challenge.

Key Concepts

CO2 pipelines are the primary method for onshore CO2 transport over distances of 100 to 1,000+ kilometers. CO2 is compressed to a supercritical state (above 31°C and 73 atmospheres) and transported as a dense-phase fluid. Pipeline costs range from $1 million to $4 million per kilometer depending on diameter, terrain, and regulatory requirements. The US already operates over 8,000 kilometers of CO2 pipelines, primarily for enhanced oil recovery in Texas and the Permian Basin.

Ship-based transport is emerging as the preferred option for offshore storage and cross-border CO2 movement. Liquefied CO2 carriers operate at roughly -50°C and 7 bar pressure. The Northern Lights project in Norway uses purpose-built vessels to transport CO2 from continental European emitters to subsea storage sites. Ship transport becomes cost-competitive with pipelines at distances beyond 500 to 800 kilometers or when crossing water bodies.

Geological storage involves injecting CO2 into deep subsurface formations where it is permanently trapped. Three primary formation types are used: depleted oil and gas reservoirs (well-characterized geology but limited capacity), deep saline aquifers (vast capacity but less geological data), and unmineable coal seams (niche applications). Storage sites require injection wells, monitoring systems, and regulatory permits covering post-injection liability periods of 20 to 50+ years.

Storage hubs and clusters aggregate CO2 from multiple emitters in an industrial region and route it to shared storage sites. This hub model reduces per-tonne costs by 30% to 60% compared to point-to-point solutions. Major cluster programs include the Humber in the UK, Rotterdam in the Netherlands, the Houston Ship Channel in the US, and the Alberta Carbon Trunk Line in Canada.

Monitoring, reporting, and verification (MRV) for storage sites uses seismic surveys, downhole pressure sensors, groundwater sampling, and satellite-based surface deformation monitoring (InSAR) to confirm CO2 remains permanently sequestered. Regulatory frameworks such as the EU CCS Directive require monitoring plans and corrective measures protocols before injection permits are granted.

What's Working

The Northern Lights project in Norway began commercial operations in 2025, becoming the first open-access CO2 transport and storage service. It offers European industrial emitters a path to permanent geological storage without requiring each company to develop its own infrastructure. Initial capacity is 1.5 million tonnes per year, with plans to scale to 5 million tonnes.

In the US, the DOE's Regional Direct Air Capture Hubs program is investing $3.5 billion across two initial hub sites in Texas and Louisiana. These hubs pair direct air capture facilities with dedicated pipeline networks and storage reservoirs, creating integrated infrastructure that serves multiple capture technologies and industrial sources.

The Porthos project in the Port of Rotterdam is constructing a shared pipeline and offshore storage system that will serve refineries, hydrogen plants, and chemical facilities in the Netherlands' largest industrial cluster. The project demonstrates how shared infrastructure reduces the cost barrier for individual emitters, with per-tonne transport and storage costs projected at EUR 30 to 40.

Enhanced oil recovery (EOR) operations in the Permian Basin have stored over 600 million tonnes of CO2 since the 1970s, providing decades of operational data on CO2 behavior in geological formations. While EOR is not pure climate mitigation, the operational experience informs modern dedicated storage projects on well integrity, reservoir management, and monitoring requirements.

What's Not Working

Permitting timelines remain a critical barrier. In the US, Class VI well permits (required for dedicated CO2 storage) take an average of 3 to 5 years to obtain from the EPA. Only a handful of states have received primacy to issue permits themselves. The backlog of pending applications exceeds 100, creating a multi-year queue that delays project deployment.

Pipeline routing and community opposition have stalled several major projects. The Navigator CO2 Ventures pipeline, which would have connected ethanol plants across the US Midwest to storage sites, was canceled in 2023 after failing to secure easements across Iowa. The Summit Carbon Solutions pipeline faced similar resistance, highlighting the need for better community engagement and benefit-sharing frameworks.

Pore space ownership and long-term liability remain legally ambiguous in many jurisdictions. Who owns the subsurface space where CO2 is stored? Who is responsible if CO2 migrates beyond the permitted injection zone after the operator has closed the site? Only a few US states and the EU have established clear legal frameworks for post-closure liability transfer from operators to government authorities.

Cost overruns on early projects have created investor caution. The Gorgon CCS project in Australia, operated by Chevron, captured only 30% of its target volume in its first five years due to equipment failures and water management issues at the injection site. The project cost A$3.1 billion and has become a cautionary example of underestimating storage site complexity.

Key Players

Established Leaders

• Equinor: Operator of Northern Lights and Sleipner (the world's longest-running CO2 storage site since 1996). Over 25 years of offshore storage experience.
• ExxonMobil Low Carbon Solutions: Largest CO2 pipeline operator in the US. Developing the Houston CCS hub with 100+ million tonnes per year capacity target.
• Shell: Partner in Northern Lights, Porthos, and the Polaris CCS project in Alberta. Operating Quest CCS in Canada since 2015.
• Occidental Petroleum: Developing the Stratos direct air capture hub in Texas with 500,000 tonnes per year capacity. Significant EOR-based storage experience.
• TotalEnergies: Partner in Northern Lights. Developing the Aramis CO2 transport network in the North Sea.

Emerging Startups

• Storegga: Developing the Acorn CCS project in Scotland with dedicated offshore pipeline and storage infrastructure in the North Sea.
• Deep Sky: Building a CO2 transport and permanent storage hub in Quebec, Canada, targeting 500,000 tonnes per year initial capacity.
• Carbon Vault: Developing mineralization-based permanent storage using basalt formations, offering an alternative to sedimentary basin storage.
• CarbonFree: Operating the SkyCycle system for CO2 mineralization into solid calcium carbonate, avoiding the need for geological injection.

Key Investors and Funders

• US Department of Energy: $12 billion allocated across CCS demonstration, DAC hubs, and regional hydrogen hubs with storage components.
• European Commission Innovation Fund: EUR 40 billion fund supporting CCS infrastructure projects across EU member states.
• Brookfield Renewable Partners: Major investor in CCS infrastructure assets with multi-billion-dollar commitments.

Action Checklist

1. Map proximity to storage infrastructure: Assess your facilities' distance from existing or planned CO2 pipeline networks and storage hubs. Proximity determines transport cost feasibility.
2. Evaluate hub membership models: Determine whether joining a shared infrastructure hub (versus developing bespoke transport) reduces your per-tonne cost to below $50 for transport and storage combined.
3. Assess regulatory readiness: Confirm that your target storage jurisdiction has clear permitting pathways, liability transfer mechanisms, and monitoring standards in place.
4. Engage with MRV requirements: Understand what monitoring, reporting, and verification obligations apply to your chosen storage approach, including post-closure monitoring periods.
5. Model total chain costs: Build a full cost model from capture exit to permanent storage, including compression, dehydration, pipeline tariffs or shipping fees, injection, and monitoring.
6. Track policy incentives: Monitor 45Q credit values, EU Innovation Fund calls, and national CCS support programs that can close the economics gap for your project timeline.
7. Evaluate storage permanence risk: Compare geological storage options (saline aquifer vs. depleted reservoir vs. mineralization) on permanence, capacity, and verification confidence.

FAQ

What is the difference between CO2 transport by pipeline and by ship? Pipelines move CO2 in a dense supercritical phase and are cost-effective for onshore distances up to 800 kilometers with steady flow volumes. Ships carry liquefied CO2 at low temperatures and are more flexible for offshore storage access, cross-border movement, and variable volumes. Ship-based transport becomes economically competitive beyond 500 kilometers or when crossing water.

How long does CO2 stay underground in geological storage? Properly selected and managed geological storage sites retain CO2 for thousands to millions of years. Natural CO2 accumulations have remained trapped in geological formations for over 100 million years. Multiple trapping mechanisms (structural, residual, solubility, and mineral trapping) increase permanence over time as CO2 dissolves into formation water and mineralizes.

What does carbon transport and storage cost per tonne? Transport costs range from $5 to $15 per tonne for short pipeline distances (under 200 km) to $15 to $30 per tonne for longer routes or ship-based transport. Storage costs (including injection, monitoring, and post-closure obligations) add $10 to $30 per tonne for onshore sites and $15 to $40 per tonne for offshore sites. Total transport and storage costs typically fall between $20 and $60 per tonne.

What are the main risks of CO2 storage? Key risks include wellbore integrity failure (CO2 leaking through poorly sealed injection or legacy wells), induced seismicity from pressure changes in the formation, CO2 migration beyond the permitted storage complex, and groundwater contamination if CO2 reaches shallow aquifers. All risks are manageable with proper site selection, well construction, and monitoring, but they require rigorous regulatory oversight.

How do I evaluate whether a storage site is suitable? Assess five factors: capacity (does the formation have enough pore space for your project volume?), injectivity (can CO2 be injected at the required rate?), containment (are there reliable cap rocks preventing upward migration?), characterization (is there sufficient geological data from seismic surveys and well logs?), and regulatory readiness (does the site have or can it obtain the necessary permits?).

Sources

1. Global CCS Institute. "Global Status of CCS 2025." GCCSI, 2025.
2. International Energy Agency. "CCUS in Clean Energy Transitions." IEA, 2024.
3. Northern Lights JV. "Commercial Operations Update." Equinor, Shell, TotalEnergies, 2025.
4. US Department of Energy. "Carbon Capture, Utilization, and Storage: Infrastructure and Deployment." DOE Office of Fossil Energy, 2024.
5. European Commission. "Net-Zero Industry Act: CO2 Storage Capacity Targets." EC, 2024.
6. National Petroleum Council. "Meeting the Dual Challenge: CO2 Transport and Storage Scale-Up." NPC, 2024.
7. Intergovernmental Panel on Climate Change. "Climate Change 2023: Mitigation of Climate Change, Chapter 12." IPCC AR6 WGIII, 2023.