Evaluating the Impact of EOR on for a Niger-Delta Case Study. A Mathematical and Simulation Approach

Abstract

Abstract Chemical flooding is thought to be a more practical and economical way to increase heavy oil recovery. The ideal concentration of the injected chemical species, required to maintain fluid viscosity, must be taken into account and optimized to enhance injection performance. The objective of this study is to study the effect of injection chemicals (Alkali polymer-surfactant species) in order to maximize injection performance of the Field XY heavy oil reservoir in the Niger Delta region. The phenomenon of fluid and heat transfer within chemical species in the reservoir and rock pore structures are modelled with three fluid phases and a 3-dimensional domain, using mathematical equations of momentum, transport and heat transfer, and solved by finite difference approximations to illustrate the problem. The CMG 2021 software's simulation findings provide result validation and a subset of the experimental data are compared with the recovery outcomes. The oil recovery findings indicate that the water saturation in the "flooded" zone was reduced while the viscosity of the injected surfactant-polymer solution was increased, thereby improving the heavy oil recovery. Fluid-Fluid aqueous reactions and rock interactions with fluid and its impact on reservoir pressure and recovery is discussed. Measurements of interfacial tension reveal over 90% decrease, which is in agreement with experimental findings.