Owing to the inherent heterogeneity of the carbonates within a field, rock properties quantified at the near wellbore scale often prove invalid when applied at a larger reservoir scale. Fractures in carbonates, which are the primary pathways for fluids migration, can range from isolated microscopic fissures to kilometer-long corridors or fracture swarms, and these can have a substantial impact on field-wide production performance, and ultimate recovery.
Schlumberger provides customized geophysical methods for imaging and assessing large-scale porosity heterogeneity across the reservoir, which is key when estimating the reservoir’s true potential. To attain a high reservoir sweep efficiency, exact position of conductive fracture clusters must be known and accurately mapped. This is important in obtaining realistic dynamic reservoir simulations, essential to strategic well placement, for both injector or producer wells.
Field-wide porosity and saturation distributions must be understood to estimate the potential production from a carbonate reservoir.
Schlumberger geomechanics experts develop mechanical earth models that describe rock stresses and rock mechanical properties, predicting how fracture conductivities may change over the life of a field.
Modeling flow in fractured reservoirs is a challenging task that requires integration of a unique combination of data.