Case study: Carbon transport & storage infrastructure — a city or utility pilot and the results so far

Norway's Northern Lights project, the world's first open-source CO2 transport and storage infrastructure, received its inaugural commercial shipment of liquefied CO2 in September 2025, marking a turning point for carbon capture deployment across Europe. Operated as a joint venture between Equinor, Shell, and TotalEnergies, the project has invested approximately $2.7 billion to build a ship-based CO2 transport system and a permanent geological storage site beneath the North Sea floor at a depth of 2,600 meters (Northern Lights JV, 2025). As of early 2026, the facility is processing 1.5 million tonnes of CO2 per year from industrial emitters across Norway, Germany, and the Netherlands, with contracts in place to scale to 5 million tonnes annually by 2029. This case study examines how a government-backed pilot evolved into a commercially operational cross-border carbon transport and storage network.

Why It Matters

The International Energy Agency estimates that carbon capture, utilization, and storage must reach 6 gigatonnes of CO2 per year by 2050 to meet net-zero targets, yet global capture capacity stood at just 49 million tonnes per year at the end of 2025 (IEA, 2025). The bottleneck is not capture technology alone: the absence of transport and storage infrastructure prevents emitters from connecting capture equipment to permanent sequestration sites. Without pipelines, ships, and injection wells, even the most efficient capture plant has nowhere to send its CO2.

Europe faces a particularly acute version of this challenge. The continent's largest industrial emitters, cement plants in Germany, steel mills in the Netherlands, waste-to-energy facilities in Scandinavia, are located hundreds of kilometers from suitable geological storage formations. Onshore storage faces public opposition in many EU member states, pushing viable sites offshore beneath the North Sea, the Norwegian continental shelf, and parts of the Baltic. The EU's Net Zero Industry Act, finalized in 2024, set a target of 50 million tonnes of annual CO2 injection capacity by 2030, requiring member states to map storage resources and streamline permitting for transport infrastructure.

For energy executives and industrial operators, the Northern Lights model answers a fundamental question: can carbon transport and storage function as a shared utility service, accepting CO2 from multiple sources across national borders, rather than requiring each emitter to build dedicated infrastructure? The results so far suggest it can, but with significant caveats around cost, regulatory harmonization, and scaling timelines.

Key Concepts

Several technical and regulatory concepts are essential to understanding how the Northern Lights pilot operates and how similar systems can be replicated.

Liquefied CO2 transport by ship is the core logistics innovation. Rather than building dedicated pipelines from each capture site to a storage location, Northern Lights accepts CO2 that has been compressed and cooled to approximately negative 26 degrees Celsius at intermediate collection terminals. Purpose-built CO2 carriers, each with a capacity of 7,500 cubic meters, transport the liquefied CO2 to the onshore receiving terminal at Oygarden on Norway's west coast, where it is temporarily stored before being pumped through a 100-kilometer subsea pipeline to the injection site.

Geological storage in saline aquifers involves injecting CO2 into porous sandstone formations capped by impermeable shale layers that prevent upward migration. The Northern Lights storage site, located in the Johansen Formation, was selected after extensive seismic surveys and exploratory drilling confirmed a storage capacity exceeding 100 million tonnes with multiple containment barriers. Monitoring systems track pressure, temperature, and CO2 plume migration in real time.

Open-access infrastructure model means Northern Lights operates as a service provider rather than a vertically integrated system. Any industrial emitter that meets the CO2 quality specifications (at least 99.5% purity, with limits on water, hydrogen sulfide, and other contaminants) can contract for transport and storage capacity. This model separates the capture investment decision from the storage investment decision, lowering barriers for mid-size emitters.

Cross-border regulatory framework required bilateral agreements between Norway, which is not an EU member, and EU states whose emitters wish to export CO2. The London Protocol amendment allowing transboundary CO2 transport for geological storage entered into force provisionally in 2024, removing a key legal barrier to international CO2 shipping.

What's Working

First Commercial Operations Validate the Technical Model

Northern Lights received its first commercial CO2 cargo from the Heidelberg Materials cement plant at Brevik, Norway, in September 2025. The Brevik facility captures approximately 400,000 tonnes of CO2 per year from its kiln exhaust using amine-based post-combustion capture technology. By January 2026, six cargo deliveries had been completed without significant operational disruptions. The CO2 purity specifications were met consistently, injection pressures remained within design parameters, and the subsea monitoring system confirmed that the CO2 plume was migrating as predicted by reservoir models (Equinor, 2026). This real-world performance data provides the confidence that insurers, regulators, and future customers need to commit to long-term contracts.

Multi-Customer Pipeline Is Building

Beyond Heidelberg Materials, Northern Lights has signed binding transport and storage agreements with Yara International for 800,000 tonnes per year from its ammonia production facility in the Netherlands and with Aker Carbon Capture for CO2 volumes from multiple waste-to-energy plants in Sweden and Denmark. A total of 12 memoranda of understanding are in place with emitters across seven European countries. The aggregate contracted volume for Phase 2, scheduled to begin operations in 2028, already exceeds 3.5 million tonnes per year, validating the demand-side economics of the open-access model (Northern Lights JV, 2025).

Government Risk-Sharing Accelerated Investment

The Norwegian government covered approximately 80% of the Phase 1 capital expenditure through the Longship project framework, committing NOK 16.8 billion (approximately $1.6 billion) in direct funding. This de-risking enabled the joint venture partners to commit their combined $1.1 billion share at an acceptable hurdle rate. The funding structure was deliberately designed to prove the business model at Phase 1 scale so that Phase 2 and beyond could attract progressively more private capital. Phase 2 financing, currently in structuring, targets a 50/50 public-private split, and the joint venture anticipates that Phase 3 could be predominantly privately financed (Norwegian Ministry of Petroleum and Energy, 2025).

Storage Monitoring Exceeds Regulatory Requirements

The monitoring program at the Johansen Formation deploys permanent ocean-bottom seismic nodes, downhole pressure and temperature gauges, and periodic surface seismic surveys to track the injected CO2. After the first six months of injection, monitoring data confirmed that the CO2 plume extended approximately 800 meters from the injection well, consistent with pre-injection simulations to within 5% accuracy. No leakage has been detected at any monitoring point. This performance record is building the regulatory and public confidence needed to permit additional storage sites in the North Sea and elsewhere (Norwegian Petroleum Directorate, 2026).

What's Not Working

Transport Costs Remain High

The current cost of transporting CO2 by ship from continental European capture sites to the Oygarden terminal ranges from EUR 50 to EUR 80 per tonne, depending on distance and volume. Combined with storage costs of approximately EUR 30 per tonne and capture costs of EUR 60 to EUR 120 per tonne (depending on the CO2 source concentration), the total CCS chain cost reaches EUR 140 to EUR 230 per tonne. This exceeds the EU Emissions Trading System carbon price, which has fluctuated between EUR 55 and EUR 75 per tonne through 2025, creating a significant gap that must be closed by subsidies, contracts for difference, or rising carbon prices.

Shipping Logistics Create Scheduling Complexity

Unlike pipeline transport, which provides continuous CO2 offtake, ship-based transport introduces batch scheduling constraints. Capture plants must have intermediate storage capacity to buffer CO2 production between ship arrivals. The current fleet of two purpose-built CO2 carriers can handle approximately 1.5 million tonnes per year, but scaling to 5 million tonnes will require six to eight additional vessels, each costing approximately EUR 100 million. The shipbuilding lead time is 30 to 36 months, and only a handful of yards have experience constructing CO2 carriers, creating a potential supply chain bottleneck.

Regulatory Fragmentation Across Borders Slows Contracting

While the London Protocol amendment addressed the legal framework for transboundary CO2 transport, practical implementation varies significantly by country. Germany only lifted its effective moratorium on CO2 export in late 2024 through the Carbon Management Strategy, and permitting for CO2 collection hubs in German ports is still in early stages. Belgium and France have not yet ratified the London Protocol amendment provisionally. Each bilateral agreement requires separate negotiation of liability transfer provisions: who is responsible if stored CO2 leaks decades after injection ceases? These unresolved questions extend contracting timelines by 12 to 18 months relative to domestic projects.

Onshore Pipeline Permitting Faces Public Opposition

While the subsea pipeline from Oygarden to the storage site was permitted and built on schedule, proposals for onshore CO2 pipelines connecting inland industrial clusters to coastal shipping terminals have encountered significant resistance in Germany and the Netherlands. Public concerns about pipeline safety, rooted partly in the 2020 Denbury CO2 pipeline rupture in Satartia, Mississippi, have led several German states to invoke local planning objections. This opposition may force reliance on truck or rail transport to coastal terminals, adding EUR 10 to EUR 20 per tonne in logistics costs and increasing the carbon footprint of the transport chain itself.

Key Players

Established Companies

• Equinor: Lead operator of Northern Lights JV with a 33.3% stake, providing subsurface expertise from decades of North Sea oil and gas operations and managing the storage site operations.
• Shell: Equal partner in Northern Lights, contributing shipping logistics expertise and leveraging its global LNG fleet management experience for CO2 carrier operations.
• TotalEnergies: Equal partner providing project finance structuring and connecting Northern Lights to its portfolio of industrial emitters across France and Belgium.
• Heidelberg Materials: First commercial customer, operating the Brevik cement CCS facility that delivers CO2 to Northern Lights via ship from its dedicated liquefaction and loading terminal.
• Yara International: Contracted 800,000 tonnes per year of transport and storage capacity for CO2 captured from ammonia production in Sluiskil, Netherlands.

Startups

• Aker Carbon Capture: Provides modular carbon capture systems to waste-to-energy plants across Scandinavia and has contracted storage capacity with Northern Lights for multiple client facilities.
• Horisont Energi: Developing the Polaris CO2 storage project in the Barents Sea as a complementary storage site, aiming to offer additional North Sea storage capacity by 2029.
• Carbfix: Pioneered rapid CO2 mineralization technology in Iceland and is exploring integration of its mineral storage approach with ship-based transport from Northern Lights for permanent sequestration.

Investors and Funders

• Norwegian Ministry of Petroleum and Energy: Provided NOK 16.8 billion in Longship project funding covering 80% of Phase 1 capital costs.
• European Commission Innovation Fund: Awarded EUR 180 million to the Brevik CCS project and is evaluating funding applications for Phase 2 emitter connections.
• European Investment Bank: Provided EUR 300 million in project finance for Northern Lights Phase 2 infrastructure expansion.

KPI Summary

KPI	Baseline (2023)	Current (2026)	Target (2029)
Annual CO2 injection capacity (Mt/yr)	0	1.5	5.0
Contracted customer facilities	0	3	12
CO2 carrier vessels in fleet	0	2	8
Transport cost (EUR/tonne, 1,000 km)	N/A	65	40
Storage cost (EUR/tonne)	N/A	30	22
Countries with active emitter contracts	0	3	7
Cumulative CO2 stored (Mt)	0	0.6	8.5

Action Checklist

• Conduct a feasibility assessment of CO2 capture at your facility, including source concentration, annual volume, and proximity to coastal or pipeline transport hubs
• Engage with Northern Lights or comparable storage operators at least 24 months before planned capture commissioning to secure transport and storage capacity agreements
• Evaluate whether your national regulatory framework permits CO2 export and identify any bilateral agreements required for cross-border transport
• Design intermediate CO2 storage capacity at the capture site to buffer production between ship or pipeline offtake schedules
• Apply for EU Innovation Fund, national CCS support schemes, or contracts for difference that bridge the gap between total CCS chain cost and prevailing carbon prices
• Establish baseline monitoring and reporting systems aligned with the EU CCS Directive requirements for measurement, reporting, and verification of stored CO2
• Assess CO2 purity specifications and contaminant limits to ensure compatibility with transport and storage operator requirements

FAQ

Q: How does ship-based CO2 transport compare to pipeline transport in cost and capacity? A: Ship transport currently costs EUR 50 to EUR 80 per tonne for distances of 500 to 1,500 kilometers, while dedicated CO2 pipelines cost EUR 10 to EUR 25 per tonne over similar distances once built. However, pipelines require minimum throughput of roughly 2 to 5 million tonnes per year to achieve these unit economics and take 5 to 8 years to permit and construct. Ship transport offers flexibility for smaller volumes and can be operational within 2 to 3 years. The Northern Lights model uses ships for Phase 1 volumes and is evaluating pipeline connections for higher-volume Phase 3 routes where the economics favor fixed infrastructure.

Q: What happens to the stored CO2 after injection ceases? A: Under the EU CCS Directive and Norwegian regulations, the storage operator must monitor the site for a minimum of 20 years after injection stops, demonstrating that the CO2 plume is stable and no leakage is occurring. After this post-closure period, responsibility transfers to the national government. The storage operator must set aside financial provisions during the operational phase to cover post-closure monitoring costs. At the Northern Lights site, the Johansen Formation's multiple sealing layers and the 2,600-meter depth provide natural containment, and CO2 is expected to gradually dissolve into formation brine and mineralize over centuries, becoming permanently trapped.

Q: Is there enough geological storage capacity in Europe to matter at scale? A: The CO2 Storage Atlas of the Norwegian Continental Shelf estimates over 70 billion tonnes of theoretical storage capacity in Norwegian waters alone, with at least 1.2 billion tonnes classified as proven. The UK North Sea offers an additional estimated 78 billion tonnes of theoretical capacity. The Netherlands, Denmark, and Iceland also have significant identified storage resources. By comparison, the EU emits approximately 2.9 billion tonnes of CO2 per year from all sources. Even conservative estimates of bankable storage capacity suggest that geological limitations will not constrain European CCS deployment for decades, though individual site characterization and permitting remain time-consuming processes.

Q: Can developing countries replicate this model without Norway's petroleum wealth? A: The Northern Lights model depends heavily on upfront government funding, which reflects Norway's fiscal capacity and strategic interest in repurposing North Sea petroleum infrastructure. However, elements of the model are transferable. The open-access, multi-customer approach reduces per-tonne costs and can attract multilateral development bank financing. The World Bank's CCS Trust Fund and the Asian Development Bank have both signaled interest in supporting shared CO2 storage infrastructure in Southeast Asia and the Middle East, where suitable geological formations exist near major industrial clusters. The key prerequisite is a credible carbon pricing or regulatory mechanism that creates demand for storage services.

Sources

• Northern Lights JV. (2025). Annual Report 2025: Commercial Operations and Phase 2 Development Update. Stavanger, Norway: Northern Lights JV DA.
• International Energy Agency. (2025). CCUS in Clean Energy Transitions: 2025 Status Report. Paris: IEA.
• Equinor. (2026). Northern Lights: First Year Operational Performance and Monitoring Results. Stavanger, Norway: Equinor ASA.
• Norwegian Ministry of Petroleum and Energy. (2025). Longship: CCS Project Progress Report to Parliament. Oslo, Norway: OED.
• Norwegian Petroleum Directorate. (2026). CO2 Storage Atlas: Norwegian Continental Shelf, 2026 Update. Stavanger, Norway: NPD.
• European Commission. (2024). Net Zero Industry Act: Implementation Framework for Carbon Management. Brussels: European Commission.
• South Pole and Bellona Foundation. (2025). European CO2 Transport and Storage Infrastructure: Gap Analysis and Investment Needs. Zurich/Oslo: South Pole Group.
• Heidelberg Materials. (2025). Brevik CCS Project: First Year Operations Report. Heidelberg, Germany: Heidelberg Materials AG.