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:2015:10.1002/2015WR018046,
author = {Reynolds, C and Krevor, S},
doi = {10.1002/2015WR018046},
journal = {Water Resources Research},
pages = {9464--9489},
title = {Characterising flow behaviour for gas injection: relative permeability of CO sub 2 /sub -brine and N sub 2 /sub-water in heterogeneous rocks},
url = {http://dx.doi.org/10.1002/2015WR018046},
volume = {51},
year = {2015}
}
TY - JOUR
AB - We provide a comprehensive experimental study of steady state, drainage relative permeability curves with CO2-brine and N2-deionized water, on a single Bentheimer sandstone core with a simple two-layer heterogeneity. We demonstrate that, if measured in the viscous limit, relative permeability is invariant with changing reservoir conditions, and is consistent with the continuum-scale multiphase flow theory for water wet systems. Furthermore, we show that under capillary limited conditions, the CO2-brine system is very sensitive to heterogeneity in capillary pressure, and by performing core floods under capillary limited conditions, we produce effective relative permeability curves that are flow rate and fluid parameter dependent. We suggest that the major uncertainty in past observations of CO2-brine relative permeability curves is due to the interaction of CO2 flow with pore space heterogeneity under capillary limited conditions and is not due to the effects of changing reservoir conditions. We show that the appropriate conditions for measuring intrinsic or effective relative permeability curves can be selected simply by scaling the driving force for flow by a quantification of capillary heterogeneity. Measuring one or two effective curves on a core with capillary heterogeneity that is representative of the reservoir will be sufficient for reservoir simulation.
AU - Reynolds,C
AU - Krevor,S
DO - 10.1002/2015WR018046
EP - 9489
PY - 2015///
SN - 0043-1397
SP - 9464
TI - Characterising flow behaviour for gas injection: relative permeability of CO sub 2 /sub -brine and N sub 2 /sub-water in heterogeneous rocks
T2 - Water Resources Research
UR - http://dx.doi.org/10.1002/2015WR018046
UR - http://hdl.handle.net/10044/1/28023
VL - 51
ER -