Simulating the Flow of Variable-salinity Water in Response to CO2 Injection

Sedimentary basins around the world considered suitable for carbon storage usually contain other natural resources such as petroleum, coal, geothermal energy and groundwater. Storing carbon dioxide in geological formations in the basins adds to the competition for access to the subsurface and the use of pore space where other resource-based industries also operate. Managing potential impacts that industrial-scale injection of carbon dioxide may have on other resource development must be focused to prevent potential conflicts and enhance synergies where possible. Such a sustainable coexistence of various resource developments can be accomplished by implementing a Framework for Basin Resource Management strategy (FBRM). The FBRM strategy utilizes the concept of an Area of Review (AOR) for guiding development and regulation of CO2 geological storage projects and for assessing their potential impact on other resources. The AOR is determined by the expected physical distribution of the CO2 plume in the subsurface and the modelled extent of reservoir pressure increase resulting from the injection of the CO2. This information is used to define the region to be characterised and monitored for a CO2 injection project. The geological characterisation and risk- and performance-based monitoring will be most comprehensive within the region of the reservoir containing the carbon dioxide plume and should consider geological features and wells continuously above the plume through to its surface projection; this region defines where increases in reservoir pressure will be greatest and where potential for unplanned migration of carbon dioxide is highest. Beyond the expanse of the carbon dioxide plume, geological characterisation and monitoring should focus only on identified features that could be a potential migration conduit for either formation water or carbon dioxide.

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The Effect of Fines Migration During CO2 Injection Using Pore Scale Characterization

Othman

Wang

Hussain

2018

SPE Asia Pacific Oil and Gas Conference and Exhibition

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Recent laboratory studies have shown fines migration induced decrease in rock permeability during CO2 injection. Fines migration is a pore scale phenomenon, yet previous laboratory studies did not conduct comprehensive pore scale characterization. This study utilizes integrated pore scale characterization techniques to study the phenomenon. We present CO2 injection experiments performed on two Berea sandstone samples. The core samples are characterized using nitrogen permeability, X-ray micro-computed tomography (micro-CT), Scanning Electronic Microscopy with Energy Dispersive X-ray Spectroscopy (SEM-EDS) and Itrax X-ray Fluoresence (XRF) scanning. The core samples were flooded with freshwater, then CO2-saturated water, and finally water-saturated supercritical CO2 (scCO2). To calculate permeability, the pressure difference across the core samples was monitored during these fluid injections. The produced water samples were analysed using Inductively Coupled Plasma-Optical Emission Spectrometry (ICPOES). After the flooding experiment, nitrogen permeability, micro-CT, SEM-EDS and Itrax-XRF scanning was repeated to characterize pore scale damage. Micro-CT image based computations were run to estimate permeability decrease along the core sample length after injection. Results show dissolution of dolomite and other high density minerals. Mineral dissolution dislodges fines particles which migrate during scCO2 injection. Berea 1 and Berea 2 showed respectively 29% and 13% increase in permeability during CO2-saturated water injection. But after water-saturated scCO2 injection, both Berea 1 and Berea 2 showed 60% decrease in permeability. The permeability damage of the sample can be explained by fines migration and subsequent blockage. SEM-EDS images also show some examples of pore blockage.

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Simulating the Flow of Variable-salinity Water in Response to CO2 Injection

Cited by 3 publications

References 20 publications

Numerical Simulations on the Low-Pressure Water-Injection-Induced Seepage Rules of Coal with Pre-existing Plane/Surface Fractures

Numerical Simulations on the Low-Pressure Water-Injection-Induced Seepage Rules of Coal with Pre-existing Plane/Surface Fractures

Framework for the assessment of interaction between CO₂geological storage and other sedimentary basin resources

The Effect of Fines Migration During CO2 Injection Using Pore Scale Characterization

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Simulating the Flow of Variable-salinity Water in Response to CO2 Injection

Cited by 3 publications

References 20 publications

Numerical Simulations on the Low-Pressure Water-Injection-Induced Seepage Rules of Coal with Pre-existing Plane/Surface Fractures

Numerical Simulations on the Low-Pressure Water-Injection-Induced Seepage Rules of Coal with Pre-existing Plane/Surface Fractures

Framework for the assessment of interaction between CO2geological storage and other sedimentary basin resources

The Effect of Fines Migration During CO2 Injection Using Pore Scale Characterization

Contact Info

Product

Resources

About

Framework for the assessment of interaction between CO₂geological storage and other sedimentary basin resources