Fig. 7. Cartesian grid (centroid X) pattern for flooding simulation.
Rock-Fluid Properties and Well Completion
After building the reservoir grid model in STARS, the input/output frequency control was set and different variables relevant to our prescribed reservoir model were chosen. Fig. 8 depicts the porosity map in case of surfactant/polymer/nanoparticle flooding. Porosity in each case were measured in the range 17-18%. Formation pore volume of core samples were measured during brine saturation, and observed as 16.00 cm3, 16.22 cm3 and 16.51 cm3 for I, II and III respectively. Liquid permeabilities were obtained in the range 350-400 mD, as calculated from flow-meter tests. Thereafter, liquid saturation values were incorporated in a well-sorted consolidated sandstone rock. Initial oil saturation values were inputted as 79.76%, 80.08% and 80.25% prior to secondary and tertiary recovery tests; for surfactant, surfactant-polymer and surfactant-polymer-nanoparticle flooding models respectively in CMG-STARS model. It was assumed that no solvent gas was present within the core before and during recovery tests. The injector well was created at the node [1 1 1], whereas the producer well was situated at [100 1 1]. The well-bore radius was fixed at 1 cm (0.01 m) in K-direction. Datasets related to grid formation, formation pore volume, oil phase volume, temperature, initial saturation, and temperature are shown in Table 3.