Table 2 & Appendix A. Properties of operations injecting CO2 into saline aquifers ...

• Main Authors: Michael, K, Golab, A, Shulakova, V, Ennis-King, J, Allinson, G, Sharma, S, Aiken, T
• Format: Dataset
• Language: English
• Published: PANGAEA 2015
• Subjects: Project; Location; Scale; Status; Date/time start; Date/time end; Rate; Mass; Unit; Lithology/composition/facies; Porosity; Permeability, gas; DEPTH, sediment/rock; Thickness; Particle concentration; Temperature, water; Pressure, load; Sub-seabed CO2 Storage Impact on Marine Ecosystems ECO2; Snøhvit
• Online Access: https://dx.doi.org/10.1594/pangaea.855518; https://doi.pangaea.de/10.1594/PANGAEA.855518

The experience from CO2 injection at pilot projects (Frio, Ketzin, Nagaoka, US Regional Partnerships) and existing commercial operations (Sleipner, Snøhvit, In Salah, acid-gas injection) demonstrates that CO2 geological storage in saline aquifers is technologically feasible. Monitoring and verification technologies have been tested and demonstrated to detect and track the CO2 plume in different subsurface geological environments. By the end of 2008, approximately 20 Mt of CO2 had been successfully injected into saline aquifers by existing operations. Currently, the highest injection rate and total storage volume for a single storage operation are approximately 1 Mt CO2/year and 25 Mt, respectively. If carbon capture and storage (CCS) is to be an effective option for decreasing greenhouse gas emissions, commercial-scale storage operations will require orders of magnitude larger storage capacity than accessed by the existing sites. As a result, new demonstration projects will need to develop and test injection ... : Supplement to: Michael, K; Golab, A; Shulakova, V; Ennis-King, J; Allinson, G; Sharma, S; Aiken, T (2010): Geological storage of CO2 in saline aquifers—A review of the experience from existing storage operations. International Journal of Greenhouse Gas Control, 4(4), 659-667 ...