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{Lin:2018:10.1029/2018WR023214,
author = {Lin, Q and Bijeljic, B and Pini, R and Blunt, MJ and Krevor, SC},
doi = {10.1029/2018WR023214},
journal = {Water Resources Research},
pages = {7046--7060},
title = {Imaging and measurement of porescale interfacial curvature to determine capillary pressure simultaneously with relative permeability},
url = {http://dx.doi.org/10.1029/2018WR023214},
volume = {54},
year = {2018}
}
TY - JOUR
AB - There are a number of challenges associated with the determination of relative permeability and capillary pressure. It is difficult to measure both parameters simultaneously on the same sample using conventional methods. Instead, separate measurements are made on different samples, usually with different flooding protocols. Hence, it is not certain that the pore structure and displacement processes used to determine relative permeability are the same as those when capillary pressure was measured. Moreover, at present, we do not use porescale information from highresolution imaging to inform multiphase flow properties directly. We introduce a method using porescale imaging to determine capillary pressure from local interfacial curvature. This, in combination with pressure drop measurements, allows both relative permeabilities and capillary pressure to be determined during steady state coinjection of two phases through the core. A steady state waterflood experiment was performed in a Bentheimer sandstone, where decalin and brine were simultaneously injected through the core at increasing brine fractional flows from 0 to 1. The local saturation and the curvature of the oilbrine interface were determined. Using the YoungLaplace law, the curvature was related to a local capillary pressure. There was a detectable gradient in both saturation and capillary pressure along the flow direction. The relative permeability was determined from the experimentally measured pressure drop and average saturation obtained by imaging. An analytical correction to the brine relative permeability could be made using the capillary pressure gradient. The results for both relative permeability and capillary pressure are consistent with previous literature measurements on larger samples.
AU - Lin,Q
AU - Bijeljic,B
AU - Pini,R
AU - Blunt,MJ
AU - Krevor,SC
DO - 10.1029/2018WR023214
EP - 7060
PY - 2018///
SN - 0043-1397
SP - 7046
TI - Imaging and measurement of porescale interfacial curvature to determine capillary pressure simultaneously with relative permeability
T2 - Water Resources Research
UR - http://dx.doi.org/10.1029/2018WR023214
UR - http://hdl.handle.net/10044/1/64645
VL - 54
ER -