CO and brine flows in heterogeneous geologic …CO 2 and brine flows in heterogeneous geologic...
Transcript of CO and brine flows in heterogeneous geologic …CO 2 and brine flows in heterogeneous geologic...
CO2 and brine flows in heterogeneous geologic systemsANNA HERRING
ARC DECRA POSTDOCTORAL FELLOW
DEPT. APPL IED MATHEMATICS , RSPE
AUSTRAL IAN NATIONAL UNIVERS ITY
Geologic CO2 sequestration
Goals of this project● Understand & predict CO2 transport &
trapping ○ on short time scales (months – decades of
years)○ under varying injection parameters ○ in heterogeneous & anisotropic rocks
Image from Ruben Juanes, MIT
Use understanding of microscale physics to inform reservoir‐scale operations
X‐ray microCTmultiphase flow studies
High Pressure Flow Cell
Reservoir conditions• Pore pressure 1350 PSI• Temperature 50oC
Fluids• scCO2• KI‐doped water (“brine”)
Imaging Parameters• 120 kV, 60 mA• voxel size approx. 4 µm• Region of Interest acquisition• 12‐20 hrs acquisition time
Experimental Process1. Install dry rock core2. Saturate core with X‐ray attenuating brine3. scCO2 injection (25 pore volumes) 4. Chase brine injection (25 pore volumes)
video courtesy of Mohammad Saadatfar, ANU
36 mm
Ø = 12 mm
Reservoir sandstoneCoarse grained, layered
Reservoir sandstoneFine grained, layered
Quarry sandstonehomogenous
Reservoir sandstoneCoarse grained, layered
Reservoir sandstoneFine grained, layered
Quarry sandstonehomogenous
Dynamic Flow Patterns – scCO2 injectionReservoir sandstone
Coarse grained, layered
Quarry sandstonehomogenous
Reservoir sandstoneCoarse grained, layered
Reservoir sandstoneFine grained, layered
Quarry sandstonehomogenous
Trapped CO2 Distributions
X‐ray microCTmultiphase flow studies inform:Dynamic flow processes◦ Pressure and flow rate signals◦ 2D (radiograph) flow patterns over time◦ Fluid volume to achieve breakthrough, steady state
Quasi‐static (equilibrium) states◦ 3D Distribution, amount of CO2 after after CO2 injection◦ Stability of CO2 (how much CO2 remains trapped after forced injection of water?)◦ Microscopic information◦ interfacial area between water and CO2◦ contact angle (wettability)◦ fluid connectivity
Integration of CT experiments and pore network modeling
SimulationRockWaterCO2‐analogue
Øren, P. E., L. C. Ruspini, M. Saadatfar, R. M. Sok, M. Knackstedt, and A. Herring (2019), In‐situ pore‐scale imaging and image‐based modelling of capillary trapping for geological storage of CO2, Int. J. Greenh. Gas Control, 87, 34–43, doi:10.1016/J.IJGGC.2019.04.017.
ExperimentRockWaterCO2‐analogue
Øren, P. E., L. C. Ruspini, M. Saadatfar, R. M. Sok, M. Knackstedt, and A. Herring (2019), In‐situ pore‐scale imaging and image‐based modelling of capillary trapping for geological storage of CO2, Int. J. Greenh. Gas Control, 87, 34–43, doi:10.1016/J.IJGGC.2019.04.017.
Integration of CT experiments and pore network modeling
Expe
rimen
tSimulation
Integration of CT experiments and pore network modeling
Pore network model
Øren, P. E., L. C. Ruspini, M. Saadatfar, R. M. Sok, M. Knackstedt, and A. Herring (2019), In‐situ pore‐scale imaging and image‐based modelling of capillary trapping for geological storage of CO2, Int. J. Greenh. Gas Control, 87, 34–43, doi:10.1016/J.IJGGC.2019.04.017.
Allows for characterization of flow properties beyond experimental conditions:
• Capillary trapping curve• Relative permeability curves• Capillary pressure – saturation curves• Sensitivity to contact angle
Forecast
Continue integration of multiphase flow experiments and modelling◦ identify critical heterogeneous transition zones/layers◦ Investigate interplay between injection parameters (e.g. flow rate) and layers
Map these features throughout depth of core, incl. via larger scale imaging ‐ ANUCTLab‐Whole Core Scanner◦ 62mm core, 120 mm long, 28 μm voxels @ 140 kV
◦ compare to 12 mm core, 36 mm long, 4 μm voxels @ 120 kV microCT
Incorporate multi‐scale heterogeneity into large (reservoir scale) models and simulators
ANU CTLab‐Whole Core Scanner
Voxel = 28μmMedical CTVoxel = 195μm
Acknowledgements
Questions?
Co‐authors:M. Saadatfar, R.M. Sok, M. Knackstedt (ANU)P.E. Øren, L.C. Ruspini (Petricore Norway)
ARC Discovery Early Career Fellowship DE180100082
The authors wish to acknowledge financial assistance provided through Australian National Low Emissions Coal Research and Development (ANLEC R&D). ANLEC R&D is supported by COAL21 Ltd and the Australian Government through the Clean Energy Initiative.
Visualizations created with Drishti https://github.com/nci/drishti
Øren, P. E., L. C. Ruspini, M. Saadatfar, R. M. Sok, M. Knackstedt, and A. Herring (2019), In‐situ pore‐scale imaging and image‐based modelling of capillary trapping for geological storage of CO2, Int. J. Greenh. Gas Control, 87, 34–43, doi:10.1016/J.IJGGC.2019.04.017.
ctlab.anu.edu.au