Trend analysis: Carbon transport & storage infrastructure — where the value pools are (and who captures them)

The global CO2 transport and storage infrastructure market is projected to exceed $50 billion in cumulative investment by 2035, yet fewer than 15% of announced projects have reached final investment decision. The disconnect between ambition and execution is creating distinct value pools for the companies that can build, finance, and operate the midstream backbone of carbon capture at scale.

Why It Matters

Carbon capture only works if captured CO2 has somewhere to go. The transport and storage segment is the bottleneck that determines whether CCUS delivers on its climate potential or remains a collection of isolated demonstration projects. Without pipeline networks and geological storage hubs, individual capture facilities face prohibitive per-tonne costs for trucking or shipping CO2 to injection sites. The International Energy Agency estimates that meeting net-zero targets requires 1 billion tonnes per year of CO2 storage capacity by 2030, up from roughly 45 million tonnes today. Closing that gap demands a buildout comparable in scale to the natural gas pipeline networks constructed over decades. For investors and developers, the infrastructure layer represents the most capital-intensive but also the most defensible part of the CCUS value chain: once a pipeline corridor is permitted and built, it becomes a natural monopoly with recurring revenue from multiple capture sources. The firms that secure permits, acquire pore space rights, and build the first trunk lines in key industrial corridors will shape the economics of carbon management for decades.

Key Concepts

CO2 pipeline networks are dedicated pipelines designed to transport supercritical or dense-phase carbon dioxide from capture facilities to storage sites. Unlike natural gas pipelines, CO2 pipelines operate at higher pressures (typically 1,200-2,200 psi) and require corrosion-resistant materials to handle impurities in the CO2 stream. The US already operates approximately 5,000 miles of CO2 pipelines, primarily for enhanced oil recovery in Texas and the Permian Basin, but the net-zero scenario requires 30,000-65,000 additional miles.

Geological sequestration involves injecting CO2 into deep underground formations where it is permanently trapped through structural, residual, solubility, and mineral trapping mechanisms. Suitable formations include depleted oil and gas reservoirs, deep saline aquifers, and basalt formations. Storage site selection requires detailed subsurface characterization to confirm injectivity, capacity, and containment integrity. The US Department of Energy estimates the country holds 8,600 billion tonnes of theoretical CO2 storage capacity in saline formations alone.

Hub-and-cluster models aggregate CO2 from multiple industrial emitters in a geographic region, feeding into shared transport infrastructure and common storage sites. This approach reduces per-emitter capital costs by 40-60% compared to point-to-point solutions and enables smaller emitters to access CCUS economics that would otherwise be unattainable.

KPI	Current Benchmark	Leading Practice	Laggard Threshold
CO2 transport cost per tonne (pipeline)	$8-15/tonne (100 km)	$5-8/tonne	>$20/tonne
CO2 transport cost per tonne (shipping)	$15-30/tonne	$12-18/tonne	>$40/tonne
Storage cost per tonne injected	$10-25/tonne	$8-12/tonne	>$35/tonne
Pipeline permitting timeline (years)	4-7	2-3	>8
Storage site characterization cost	$20-50 million	$10-20 million	>$80 million
Hub utilization rate (% of design capacity)	25-40%	>60%	<15%

What's Working

The US 45Q tax credit driving pipeline economics. The Inflation Reduction Act increased the 45Q credit to $85 per tonne for dedicated geological storage, fundamentally altering the investment case for CO2 transport infrastructure. Summit Carbon Solutions' proposed 2,000-mile pipeline network across the US Midwest would connect 30+ ethanol plants to a storage site in North Dakota, creating the largest CO2 pipeline system built in a single phase. The enhanced 45Q credit covers transport and storage costs while leaving margin for operators, making projects bankable for the first time without relying on enhanced oil recovery revenue.

Northern Lights as the template for open-access CO2 shipping. The Northern Lights project in Norway, a joint venture of Equinor, Shell, and TotalEnergies, is the world's first open-access CO2 transport and storage infrastructure. Phase 1, operational since 2024, can receive 1.5 million tonnes per year of liquefied CO2 shipped from capture facilities across Europe. The project has signed commercial agreements with emitters in Norway, the Netherlands, Belgium, and the UK, demonstrating that ship-based CO2 transport can serve as a flexible alternative to pipelines for cross-border carbon management. Phase 2 expansion to 5 million tonnes per year has received government support.

Gulf Coast industrial hub development. The US Gulf Coast is emerging as the most advanced CCUS cluster globally, leveraging existing pipeline rights-of-way, deep geological knowledge from decades of oil and gas operations, and proximity to heavy industry. ExxonMobil's Bayou Bend project has secured subsurface rights for storing up to 1 billion tonnes of CO2 beneath the Texas coastline. Separately, Denbury (now part of ExxonMobil) operates the largest dedicated CO2 pipeline network in the US. The concentration of petrochemical plants, refineries, LNG terminals, and power generation along the Gulf Coast creates a natural cluster where shared infrastructure can serve dozens of emitters.

What's Not Working

Pipeline permitting and landowner opposition. Summit Carbon Solutions' Midwest pipeline has faced sustained resistance from landowners across Iowa, South Dakota, and Minnesota, resulting in permit denials and project delays. The Navigator CO2 Ventures pipeline was cancelled entirely in 2023 after failing to secure adequate easements. Unlike natural gas pipelines, CO2 pipelines lack federal eminent domain authority in most states, forcing developers to negotiate voluntary agreements with every landowner along the route. This permitting challenge adds years and hundreds of millions of dollars to project timelines.

Subsurface uncertainty and monitoring costs. While the US has enormous theoretical storage capacity, commercially proven capacity with detailed characterization remains limited. Moving from regional assessments to site-specific permits requires 3-5 years of geological evaluation, test wells, and seismic surveys, often costing $30-50 million per site before a single tonne is injected. Long-term monitoring, measurement, and verification (MMV) requirements extend liability for decades after injection ceases. Pore space ownership laws vary by state and remain unsettled in several jurisdictions, creating legal uncertainty for storage operators.

Mismatch between capture project timelines and infrastructure readiness. Many industrial emitters have announced capture projects contingent on transport and storage being available, while infrastructure developers wait for firm commitments from emitters before securing financing. This chicken-and-egg problem has stalled numerous projects. The Global CCS Institute reported in 2025 that of 628 announced CCS projects worldwide, fewer than 100 had confirmed access to transport and storage infrastructure, with the remainder dependent on planned but not yet financed midstream capacity.

Key Players

Established Leaders

• ExxonMobil: Acquired Denbury for $4.9 billion to gain the largest US CO2 pipeline network and Gulf Coast storage assets. Targeting 100 million tonnes per year of CO2 storage capacity by 2040.
• Equinor: Lead partner in Northern Lights and operator of the Sleipner CO2 storage site, which has safely stored over 28 million tonnes of CO2 since 1996.
• Shell: Co-owner of Northern Lights and operator of the Quest CCS facility in Alberta. Investing in multiple hub-and-cluster projects across Europe and North America.
• Occidental Petroleum: Developing large-scale direct air capture hubs paired with storage in the Permian Basin through its 1PointFive subsidiary.

Emerging Startups

• Summit Carbon Solutions: Developing the largest proposed CO2 pipeline in the US, connecting Midwest ethanol plants to dedicated geological storage.
• Storegga: UK-based developer of the Acorn CCS project in Scotland, targeting North Sea depleted reservoirs with ship and pipeline transport options.
• Deep Sky: Canadian company building CO2 removal and storage hubs, combining multiple capture technologies with geological storage in Quebec.
• CarbonVault: Developing mineralization-based permanent storage solutions using reactive rock formations as an alternative to deep well injection.

Key Investors and Funders

• US Department of Energy: Allocated $12 billion for CCUS through the Bipartisan Infrastructure Law, including $2.5 billion for CO2 transport infrastructure and regional storage validation.
• European Investment Bank: Financing Northern Lights expansion and supporting CCUS hub development across the EU through the Innovation Fund.
• Brookfield Asset Management: Investing in CO2 pipeline infrastructure through energy transition funds, targeting regulated midstream returns.

Where the Value Pools Are

Pore space aggregation and storage rights. Companies that secure long-term storage rights in proven geological formations hold an increasingly scarce and valuable resource. As demand for permanent CO2 sequestration grows, pore space will function similarly to mineral rights: the early movers who characterize, permit, and control access to premium storage sites will earn recurring injection fees from multiple customers. The Gulf Coast and North Sea represent the highest-value basins today, but emerging opportunities exist in the Williston Basin, Illinois Basin, and offshore Australia.

Midstream pipeline operations. CO2 pipelines share the natural monopoly characteristics of natural gas midstream: high upfront capital costs, long asset lives, and volume-based tariff revenue. Operators that build trunk lines connecting industrial clusters to storage hubs can lock in 15-25 year take-or-pay contracts with shippers, providing predictable cash flows that appeal to infrastructure investors. The tariff structure rewards scale: larger diameter pipelines serving multiple emitters achieve significantly lower per-tonne costs than small dedicated lines.

CO2 shipping and logistics. For regions without pipeline access, particularly cross-border European routes, liquefied CO2 shipping is emerging as a flexible transport option. The Northern Lights model demonstrates that ship-based transport enables emitters in countries without domestic storage to access offshore geological formations. Shipping also avoids the permitting challenges of overland pipelines. Companies building purpose-built CO2 carriers and liquefaction terminals are positioning for a market that could handle 50-100 million tonnes per year in Europe alone by 2035.

Monitoring, measurement, and verification services. Regulators and investors require continuous assurance that stored CO2 remains permanently sequestered. The MMV services market includes subsurface monitoring (pressure gauges, seismic surveys), atmospheric detection, groundwater sampling, and digital reporting platforms. As the number of active storage sites grows from dozens to hundreds, the demand for third-party MMV providers will scale proportionally. Companies offering integrated monitoring platforms with regulatory reporting capabilities command premium pricing.

Action Checklist

• Map your facility's proximity to announced CO2 pipeline routes and storage hubs to assess transport options and costs
• Evaluate the economic case for joining a hub-and-cluster model versus developing point-to-point CO2 transport
• Secure long-term storage agreements or pore space options in geologically characterized basins before premium sites are fully contracted
• Assess eligibility for 45Q tax credits, EU Innovation Fund grants, or national CCUS subsidy programs to improve project economics
• Develop contingency plans for transport: evaluate both pipeline and shipping options to reduce single-mode dependency
• Engage with regulators on pipeline permitting requirements early, building landowner and community engagement into project timelines
• Integrate long-term MMV costs and liability requirements into project financial models rather than treating them as post-closure expenses

FAQ

How much does it cost to build a CO2 pipeline? CO2 pipeline costs range from $1-4 million per mile depending on diameter, terrain, and regulatory requirements. A 12-inch pipeline suitable for transporting 5 million tonnes per year over 100 miles would cost roughly $200-400 million. Costs increase significantly in populated areas due to permitting complexity and safety setback requirements. Repurposing existing natural gas pipelines for CO2 service can reduce capital costs by 50-70% where technically feasible.

What is the difference between CO2 pipeline transport and CO2 shipping? Pipeline transport moves CO2 continuously in dense or supercritical phase at high pressure through fixed infrastructure. It offers the lowest per-tonne costs at high volumes over moderate distances (under 500 km) but requires large upfront capital and lengthy permitting. Shipping transports liquefied CO2 at low temperature and moderate pressure in purpose-built vessels. Shipping offers flexibility for cross-border transport and lower upfront investment but has higher per-tonne operating costs and requires liquefaction and receiving terminal infrastructure.

How long does CO2 stay underground once injected? When stored in properly characterized geological formations, CO2 is expected to remain trapped for thousands to millions of years. Multiple trapping mechanisms work over different timescales: structural trapping (immediate), residual trapping (years to decades), solubility trapping (decades to centuries), and mineral trapping (centuries to millennia). The Sleipner project in Norway has monitored CO2 behavior since 1996, confirming stable containment with no detected leakage over nearly three decades.

What are the main risks of CO2 transport and storage? Pipeline risks include potential leaks or ruptures, which can create localized CO2 concentrations hazardous to human health. The 2020 Satartia, Mississippi pipeline rupture hospitalized 45 people and highlighted the need for robust safety standards. Storage risks include induced seismicity from injection pressure, well integrity failures, and caprock seal compromise. These risks are manageable with proper site selection, engineering, and monitoring, but they require rigorous regulatory oversight and long-term liability frameworks.

Who is responsible for stored CO2 after injection stops? Liability frameworks vary by jurisdiction. In the US, the EPA's Underground Injection Control Class VI program requires operators to monitor storage sites for 50 years post-injection, after which liability may transfer to a government authority. The EU CCS Directive requires a minimum 20-year post-closure monitoring period before liability transfers to the member state. Several jurisdictions are developing long-term stewardship funds financed by per-tonne fees during injection to cover post-transfer monitoring costs.

Sources

1. International Energy Agency. "CCUS in Clean Energy Transitions." IEA, 2025.
2. Global CCS Institute. "Global Status of CCS 2025." GCCSI, 2025.
3. US Department of Energy. "National Carbon Capture, Transport, and Storage Infrastructure Strategy." DOE, 2025.
4. Northern Lights JV. "Project Development and Commercial Update." Equinor, Shell, TotalEnergies, 2025.
5. Carbon Tracker Initiative. "Carbon Capture and Storage: Risks and Opportunities in the Energy Transition." Carbon Tracker, 2025.
6. Pipeline and Hazardous Materials Safety Administration. "CO2 Pipeline Safety Regulations Update." PHMSA, 2025.
7. BloombergNEF. "CCUS Market Outlook: Transport and Storage Infrastructure." BNEF, 2025.
8. Summit Carbon Solutions. "Midwest Carbon Pipeline Project Overview." Summit Carbon Solutions, 2025.