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| Snohvit CO2 storage | |
|---|---|
| Name | Snohvit CO2 storage |
| Location | Barents Sea, Norway |
| Operator | Equinor |
| Start year | 2008 (LNG project), CO2 injection 2008–2011 (pilot), later studies |
| Type | Subsurface carbon dioxide storage |
| Reservoir | Tubåen Formation (Lower Jurassic) |
| Depth | ~2,500–3,000 m |
| Status | Operated / studied |
Snohvit CO2 storage is a subsurface carbon dioxide sequestration initiative associated with the Snohvit natural gas development on the Barents Sea continental shelf off Hammerfest, Norway. The project links the Snohvit gas field development, the Snøhvit LNG plant, and subsurface injection into the Tubåen Formation within the Hammerfest Basin, and has been a focal point for Norwegian, European, and international research on carbon capture and storage and subsea infrastructure deployment. Early pilot injection, long-term monitoring, regulatory scrutiny, and economic assessments have connected it to organizations such as Equinor, StatoilHydro (former), Petoro, and institutions including the Norwegian Petroleum Directorate and CLIMIT.
The Snohvit CO2 initiative emerged from development of the Snohvit gas field discovered by Exxon, Statoil, TotalEnergies, and partners in the 1980s and 1990s, with production linked to the onshore Melkøya LNG facility near Hammerfest. The project context includes technology and policy actors such as Gassco, Gassnova, Norwegian Ministry of Petroleum and Energy, and research partners like SINTEF and NGI (Norwegian Geotechnical Institute). Snohvit has been referenced alongside other CCS efforts such as Sleipner (CO2 storage), Kårstø, Longannet, and international projects including Boundary Dam Power Station and Quest (CCS project). The initiative raised technical questions involving seismic surveying firms, drilling contractors like Transocean and Seadrill, and service companies including Schlumberger and Halliburton.
The injection target for Snohvit is the Tubåen Formation within the Hammerfest Basin, stratigraphically beneath the Hekkingen Formation and capped by regional seals including the Stø Formation and Tromsø Formation equivalents. Geoscientific characterization involved borehole data from exploration wells, 3D seismic surveys conducted by companies such as PGS and TGS, and reservoir studies by ConocoPhillips and TotalEnergies technical teams. Petrophysical analyses drew on methods developed at GEUS and laboratories at University of Oslo and University of Bergen. Structural mapping referenced regional geology texts on the Barents Sea Shelf and compared to analogues in the North Sea and the Ormen Lange area. The storage horizon depth, porosity, permeability, and caprock integrity informed risk models using tools from DNV and Det Norske Veritas.
CO2 handling options for Snohvit were entwined with LNG processing at the Melkøya plant operated by Equinor and partners Petoro and Aker Solutions. Capture concepts referenced liquefaction and gas treatment technologies applied at Snøhvit LNG and compared to capture systems at Sleipner, Kårstø, and Quest. Transport assessments considered subsea pipelines and tie-ins using manufacturers like Aker and pipeline contractors such as Kvaerner. Gassco and Heerema-class installation vessels featured in planning for subsea manifolds. Technical feasibility studies involved DNV GL and academic groups from University College London and MIT for system modeling and life-cycle analysis.
Pilot injection activities drew on expertise from Equinor and contractors including Halliburton for well completion and Schlumberger for downhole logging. Monitoring programs integrated 4D seismic surveys by PGS and TGS, oceanographic monitoring by Institute of Marine Research (Norway), and geochemical sampling coordinated with NGU (Geological Survey of Norway). Modeling efforts used software from Schlumberger and RPS Group and incorporated regulatory reporting to the Norwegian Petroleum Directorate. Monitoring suites also engaged environmental scientists from NIVA (Norwegian Institute for Water Research) and marine biologists at University of Tromsø. The monitoring strategy paralleled approaches from projects like Sleipner (CO2 storage) and Otway Project.
Environmental risk assessments addressed potential leakage pathways, impacts on the Barents Sea ecosystem, and interactions with fisheries represented by The Norwegian Fishermen's Association. Safety and contingency planning referenced standards from International Maritime Organization and ISO norms, with emergency response coordination involving Norwegian Coastal Administration and local authorities in Finnmark. Baseline studies included benthic ecology surveys by Institute of Marine Research (Norway) and pollutant dispersion modeling using frameworks from EMSA and JRC (European Commission Joint Research Centre). Ethical and stakeholder engagement processes involved Nordland County Municipality and community consultation modeled after practices in Lofoten and Arctic development guidance from Arctic Council bodies.
The legal regime for Snohvit CO2 operations operates under Norwegian petroleum and environmental law, with oversight by the Norwegian Petroleum Directorate, Norwegian Environment Agency, and policy instruments from the Norwegian Ministry of Petroleum and Energy. International law considerations referenced the London Protocol and Oslo-Paris Convention (OSPAR) agreements on marine pollution and sub-seabed disposal, and compliance frameworks engaged IEA recommendations and UNFCCC reporting mechanisms. Licensing, permitting, and liability arrangements involved state-owned entities such as Gassnova and fiscal partners Petoro and contractual frameworks similar to those overseen by Equinor in other Norwegian projects.
The Snohvit CO2 program evolved alongside the broader Snøhvit LNG development financed by a consortium including Equinor, RWE, Gaz de France (GDF Suez) (now Engie), TotalEnergies, and ExxonMobil. Capital expenditure, operational costs, and carbon pricing considerations were analyzed relative to European energy markets and instruments like the European Union Emissions Trading System and Norwegian carbon tax regimes. Project iterations involved feasibility studies commissioned by Gassnova and commercial evaluations by DNV and McKinsey & Company-style consultancies, and were influenced by developments at Sleipner (CO2 storage) and international CCS demonstrations at Boundary Dam Power Station and Quest (CCS project). Historical timelines reflect exploration by Exxon and early operator transitions including Statoil rebranding to Equinor, with public reporting to the Norwegian Petroleum Directorate and academic analyses published by University of Oslo and University of Bergen research groups.
Category:Carbon capture and storage Category:Barents Sea Category:Equinor projects