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.