Combine physical laboratory analysis with the latest in 3D digital simulation and evaluation.
An operator conducting a carbonate oilfield appraisal needed to better understand the formation’s pore-scale flow dynamics by obtaining realistic multiphase flow data at reservoir conditions, which is not possible with conventional laboratory methods. Forty-four percent of the reservoir has absolute permeability of less than 1 mD. Characterizing this tight rock using conventional techniques is time consuming and, most importantly, challenges data reliability. Decreased data reliability reduces forecast quality of the hydrodynamic model and leads to the large discrepancy between the minimum and maximum estimates of geological and recoverable reserves. A study combining laboratory tests and digital rock (DR) analysis successfully determined the flow properties of the field’s entire oil-bearing matrix.