Modeling Fracture Networks in Carbonates

Fracture detection and orientation information obtained from borehole imaging tools may not necessarily be representative of regional variations in the reservoir.  It is therefore important to combine local borehole-derived information with large-scale observations as provided by 3D seismic surveys. Permeability in fracture corridors can range well above 10 darcies. These corridors can act as major conduits for fluids flowing within the reservoir, and operators need to understand the distribution of these fracture systems to locate injector and producer wells in order to maximize reservoir sweep efficiency and minimize water breakthrough. One method for identifying these corridors using seismic data is the FCM fracture cluster mapping workflow.
Depending on the type of well, depletion or injection can cause pressure changes in the reservoir. These pressure changes lead to stress alterations, which further modify the apertures, and the permeability of the fractures. Schlumberger geomechanics experts develop mechanical earth models (MEMs) that describe rock stresses and rock mechanical properties, predicting changes in fracture conductivities, and therefore reservoir performance. Monitoring the reservoir via a dynamic MEM allows the operator to make necessary changes to optimize the life of the well.

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Fracture Characterization:
An Integrated Approach

An integrated approach to fracture characterisation
Understanding the complexities of carbonate reservoirs is key to unlocking world’s remaining conventional oil.