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2015 (English)In: Greenhouse Gases: Science and Technology, E-ISSN 2152-3878, Vol. 5, no 4, p. 419-436Article in journal (Refereed) Published
Abstract [en]
Geological storage in sedimentary basins is considered a viable technology in mitigating atmospheric CO2 emissions. Alternating high and low permeability strata are common in these basins. The distribution of injected CO2 among such layers affects e.g. CO2 storage efficiency, capacity and plume footprint. A numerical study on the distribution of injected CO2 into a multi-layered reservoir, accounting for coupled wellbore-reservoir flow, was carried out using the T2Well/ECO2N code. A site-specific case as well as a more general case were considered. Properties and processes governing the distribution of sequestrated CO2 were identified and the potential to operationally modify the distribution was investigated. The distribution of CO2 was seen to differ from that of injected water, i.e. it was not proportional to the transmissivity of the layers. The results indicate that caution should be taken when performing numerical simulations of CO2 injection into layered formations. Ignoring coupled wellbore-reservoir flow and instead adopting a simple boundary condition at the injection well, such as an inflow rate proportional to the transmissivity of each layer, may result in significant underestimation of the proportion of CO2 ending up in the shallower layers, as not all relevant processes are accounted for. This discrepancy has been thoroughly investigated and quantified for several CO2 sequestration scenarios.
Keywords
CCS, flow distribution, geological storage, layered formation, wellbore model
National Category
Oceanography, Hydrology and Water Resources
Identifiers
urn:nbn:se:uu:diva-263036 (URN)10.1002/ghg.1477 (DOI)000360356800007 ()
Funder
EU, FP7, Seventh Framework Programme, 227286EU, FP7, Seventh Framework Programme, 309067
2015-09-302015-09-242023-12-04Bibliographically approved