We investigate the physics, chemistry, and techno-economics of CO2 storage underground

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.

Our Research Projects

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StrataTrapper Advanced Modelling of CO2 Migration and Trapping

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THMC4CCS: ThorougH experiMental and numerical investigation of Coupled processes for geologiC Carbon ‎Storage

Royal Academy of Engineering Senior Research Fellowship

ExpReCCS: Expansion of ResourCes for CO2 Storage on the Horda Platform

inFUSE Prosperity Partnership

Shell Digital Rocks Laboratory

Citation

BibTex format

@article{Rucker:2020:10.1016/j.jcis.2019.11.086,
author = {Rucker, M and Bartels, W-B and Garfi, G and Shams, M and Bultreys, T and Boone, M and Pieterse, S and Maitland, GC and Krevor, S and Cnudde, V and Mahani, H and Berg, S and Georgiadis, A and Luckham, PF},
doi = {10.1016/j.jcis.2019.11.086},
journal = {Journal of Colloid and Interface Science},
pages = {159--169},
title = {Relationship between wetting and capillary pressure in a crude oil/brine/rock system: From nano-scale to core-scale},
url = {http://dx.doi.org/10.1016/j.jcis.2019.11.086},
volume = {562},
year = {2020}
}
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RIS format (EndNote, RefMan)

TY  - JOUR
AB  - HypothesisThe wetting behaviour is a key property of a porous medium that controls hydraulic conductivity in multiphase flow. While many porous materials, such as hydrocarbon reservoir rocks, are initially wetted by the aqueous phase, surface active components within the non-wetting phase can alter the wetting state of the solid. Close to the saturation endpoints wetting phase fluid films of nanometre thickness impact the wetting alteration process. The properties of these films depend on the chemical characteristics of the system. Here we demonstrate that surface texture can be equally important and introduce a novel workflow to characterize the wetting state of a porous medium.ExperimentsWe investigated the formation of fluid films along a rock surface imaged with atomic force microscopy using ζ-potential measurements and a computational model for drainage. The results were compared to spontaneous imbibition test to link sub-pore-scale and core-scale wetting characteristics of the rock.FindingsThe results show a dependency between surface coverage by oil, which controls the wetting alteration, and the macroscopic wetting response. The surface-area coverage is dependent on the capillary pressure applied during primary drainage. Close to the saturation endpoint, where the change in saturation was minor, the oil-solid contact changed more than 80%.
AU  - Rucker,M
AU  - Bartels,W-B
AU  - Garfi,G
AU  - Shams,M
AU  - Bultreys,T
AU  - Boone,M
AU  - Pieterse,S
AU  - Maitland,GC
AU  - Krevor,S
AU  - Cnudde,V
AU  - Mahani,H
AU  - Berg,S
AU  - Georgiadis,A
AU  - Luckham,PF
DO  - 10.1016/j.jcis.2019.11.086
EP  - 169
PY  - 2020///
SN  - 0021-9797
SP  - 159
TI  - Relationship between wetting and capillary pressure in a crude oil/brine/rock system: From nano-scale to core-scale
T2  - Journal of Colloid and Interface Science
UR  - http://dx.doi.org/10.1016/j.jcis.2019.11.086
UR  - http://gateway.webofknowledge.com/gateway/Gateway.cgi?GWVersion=2&SrcApp=PARTNER_APP&SrcAuth=LinksAMR&KeyUT=WOS:000508752700017&DestLinkType=FullRecord&DestApp=ALL_WOS&UsrCustomerID=1ba7043ffcc86c417c072aa74d649202
UR  - https://www.sciencedirect.com/science/article/pii/S0021979719314146?via%3Dihub
UR  - http://hdl.handle.net/10044/1/87545
VL  - 562
ER  -
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