In this section
Our research includes exploring fundamental pore scale fluid dynamics, developing digital rocks analysis techniques, increasing the accuracy of field scale reservoir simulation, and evaluating the feasibility of scaling up CO2 storage to climate relevant scales.
StrataTrapper Advanced Modelling of CO2 Migration and Trapping
THMC4CCS: ThorougH experiMental and numerical investigation of Coupled processes for geologiC Carbon Storage
@article{Reynolds:2017:osf.io/vwahr,
author = {Reynolds, C and Blunt, M and Krevor, S},
doi = {osf.io/vwahr},
title = {Multiphase flow characteristics of heterogeneous rocks from CO2 storage reservoirs in the United Kingdom},
url = {http://dx.doi.org/10.31223/osf.io/vwahr},
year = {2017}
}
TY - JOUR
AB - <jats:p>We have studied the impact of heterogeneity on relative permeability and residual trapping for rock samples from the Bunter sandstone of the UK Southern North Sea, the Ormskirk Sandstone of the East Irish Sea, and the Captain Sandstone of the UK Northern North Sea. Reservoir condition CO2-brine relative permeability measurements were made while systematically varying the ratio of viscous to capillary flow potential, across a range of flow rates, fractional flow, and during drainage and imbibition displacement. This variation resulted in observations obtained across a range of core-scale capillary number 0.2 < Nc < 200. Capillary pressure heterogeneity was quantitatively inferred from 3D observations of the fluid saturation distribution in the rocks. For each of the rock samples a threshold capillary number, 5 < Nc < 30, was found, below which centimetre-scale layering resulted in a heterogeneous distribution of the fluid phases and a commensurate impact on flow and trapping. The threshold was found to be dependent on the capillary number alone, irrespective of the displacement path (drainage or imbibition) and average fluid saturation in the rock. The impact of the heterogeneity on the relative permeability varied depending on the characteristics of the heterogeneity in the rock sample, whereas heterogeneity increased residual trapping in all samples above what would be expected from the pore-scale capillary trapping mechanism alone. Models of subsurface CO2 injection should use properties that incorporate the impacts of heterogeneity at the flow regime of interest or risk significant errors in estimates of fluid flow and trapping.</jats:p>
AU - Reynolds,C
AU - Blunt,M
AU - Krevor,S
DO - osf.io/vwahr
PY - 2017///
TI - Multiphase flow characteristics of heterogeneous rocks from CO2 storage reservoirs in the United Kingdom
UR - http://dx.doi.org/10.31223/osf.io/vwahr
ER -