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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CHAPTER 3.<br />
INVERTING SHEAR-WAVE SPLITTING MEASUREMENTS FOR FRACTURE PROPERTIES<br />
B T v will only differ when significant VTI anisotropy is present.<br />
Furthermore, I believe that they<br />
will only differ when the mechanism causing VTI anisotropy acts at a smaller length-scale than the<br />
vertical fractures (e.g., horizontally aligned anisotropic minerals). If the VTI anisotropy is induced<br />
by horizontally aligned fractures or by larger scale sedimentary layers (e.g., Backus, 1962) then it is<br />
not clear that B T h <strong>and</strong> B T v should be allowed to differ.<br />
It is possible to calculate the fracture normal <strong>and</strong> tangential compliance as a function <strong>of</strong> fracture<br />
density, aspect ratio <strong>and</strong> fill by assuming an idealised fracture geometry (e.g., penny-shaped or elliptical).<br />
Several such methods are available in the literature (e.g., Hudson, 1981; Hudson et al., 1996),<br />
<strong>and</strong> well summarised by Hall <strong>and</strong> Kendall (2000).<br />
Fractures <strong>and</strong> fluids<br />
A key difference between fracture models in the literature is how they treat the fluids that fill the<br />
fractures. Reservoirs will be saturated with gas, brine or oil (or a multiphase mixture), <strong>and</strong> these<br />
fluids will also saturate the fractures. The presence <strong>of</strong> fluid in a fracture will have a significant effect<br />
on the fracture compliance, <strong>and</strong> hence the overall rock stiffness tensor.<br />
The compliance <strong>of</strong> a flat, low aspect ratio crack will be far greater than a spherical pore. As a<br />
result, the incidence <strong>of</strong> a pressure wave will compress a fracture far more than a pore, leading to<br />
non-uniform compression <strong>of</strong> the saturating fluid <strong>and</strong> the development <strong>of</strong> pressure gradients between<br />
fluids in the pores <strong>and</strong> fractures. The fluid will attempt to flow to equalise these gradients, however<br />
it will be restricted by the permeability <strong>of</strong> the rock matrix <strong>and</strong> its own viscosity. The extent to which<br />
this pressure gradient equalisation can occur is crucial for determining the fracture compliance. This<br />
phenomenon is known as squirt-flow, <strong>and</strong> can be best demonstrated by considering an idealised system<br />
<strong>of</strong> aligned penny-shaped fractures that can either be fully connected to a system <strong>of</strong> spherical pores,<br />
partially connected to them, or totally isolated from the porosity (Figure 3.1).<br />
Isolated fractures<br />
Early effective medium models models such as Hudson (1981) <strong>and</strong> T<strong>and</strong>on <strong>and</strong> Weng (1984) consider<br />
there to be no fluid connection between fractures. An incident P-wave travelling normal to the fracture<br />
faces must compress both the fracture faces <strong>and</strong> the fluid within it. Because the fluid has some stiffness<br />
the overall compliance <strong>of</strong> the fracture is decreased. The normal <strong>and</strong> tangential compliance, B N <strong>and</strong><br />
B T , <strong>of</strong> a set <strong>of</strong> isolated, fluid-filled fractures is given by Hudson (1981) as<br />
B N = 4 ( ) ( ξ λ r + 2µ r ) 1<br />
3 µ r λ r + µ r 1 + K ,<br />
B T = 16 ( ) ( ξ λ r + 2µ r ) 1<br />
3 µ r 3λ r + 4µ r 1 + M , (3.7)<br />
where<br />
K = K fl<br />
πaµ r (λ r + 2µ r )<br />
(λ r + µ r ) ,<br />
M = 4µ fl<br />
πaµ r (λ r + 2µ r )<br />
(3λ r + 4µ r ) . (3.8)<br />
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