Microseismic Monitoring and Geomechanical Modelling of CO2 - bris
Microseismic Monitoring and Geomechanical Modelling of CO2 - bris
Microseismic Monitoring and Geomechanical Modelling of CO2 - bris
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pressure, P fl<br />
σ ′ ij = σ ij − β w I ij P fl , (5.1)<br />
5<br />
<strong>Geomechanical</strong> simulation <strong>of</strong> CO 2<br />
injection<br />
Even the self-assured will raise their perceived self-efficacy if models teach them better ways <strong>of</strong> doing<br />
things.<br />
Albert B<strong>and</strong>ura<br />
5.1 Introduction<br />
<strong>Microseismic</strong> monitoring provides information about the geomechanical deformation occurring in <strong>and</strong><br />
around the reservoir. As such, the interpretation <strong>of</strong> microseismic activity can be greatly improved<br />
by geomechanical modelling. <strong>Geomechanical</strong> models commonly use finite element techniques to simulate<br />
the deformation caused by pore pressure changes in the reservoir. Injection <strong>of</strong> CO 2 will increase<br />
the pore pressure in the reservoir. This represents the loading for the geomechanical model, which<br />
computes the deformation both inside <strong>and</strong> around the reservoir. By examining the stress evolution<br />
it is possible to identify areas in <strong>and</strong> around the reservoir where fractures are likely to form or be<br />
reactivated. In this chapter I use a relatively novel technique where a geomechanical model is coupled<br />
to a fluid-flow simulator. This allows changes in pore pressure to be passed directly to the geomechanical<br />
model, <strong>and</strong> changes in porosity <strong>and</strong> permeability to be returned to update the fluid model. The<br />
modelling method has been developed by the Integrated Petroleum Engineering, Geomechanics <strong>and</strong><br />
Geophysics (IPEGG) consortium. In this chapter I introduce the modelling technique <strong>and</strong> demonstrate<br />
it with several simple numerical simulations. I use these to examine how factors such as the<br />
reservoir geometry <strong>and</strong> material properties affect the stress evolution during CO 2 injection.<br />
5.2 Effective stress <strong>and</strong> stress path parameters<br />
The concept <strong>of</strong> effective stress was introduced by Terzaghi (1943). When a stress is applied to a porous<br />
material, part <strong>of</strong> the stress will be supported by the matrix material, <strong>and</strong> part will be supported by<br />
the fluid in the pores. The part <strong>of</strong> the stress supported by the matrix is termed the effective stress,<br />
given in tensorial form as σ ′ ij . It is the effective stress that will determine the deformation <strong>of</strong> the rock<br />
frame. The effective stress is a function <strong>of</strong> the external stress applied to the rock, σ ij , <strong>and</strong> the pore<br />
where I ij is a 3×3 identity matrix, <strong>and</strong> β w is the Biot-Willis parameter (e.g., Mavko et al., 1992),<br />
assumed here to be 1. The magnitudes <strong>of</strong> the principle effective stresses are given by the eigenvalues <strong>of</strong><br />
σ ′ ij , <strong>and</strong> when referring to these I will use only one subscript, e.g., σ′ 1. The corresponding eigenvectors<br />
give the orientations <strong>of</strong> the principal effective stresses. One <strong>of</strong> the principal stresses is usually orientated<br />
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