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recovery. Abstract. The lack of well test interpretation techniques applicable to chemical flooding reservoirs has restricted the formation evaluation and project design in EOR (Enhanced Oil Recovery) production. In this study, a two-phase five-component well test model for polymer-surfactant flooding is proposed which considers the main physicochemical phenomena including polymer in-situ viscosity, permeability reduction, inaccessible pore volume, adsorption, phase behavior, capillary desaturation, and relative permeability. Base on PEBI gridding, a fully implicit numerical well test simulator is developed. The impact of polymer and surfactant injection on transient pressure response is revealed by parametric studies. Results show that the injection of polymer increases the peak value of the derivative curve and the flow-continued time, and the surfactant injection affects the pressure transient response in an opposite way to polymer injection. The qualitative explanation for the impacts of polymer and surfactant injection on pressure transient response is given via the changing of mobility in the near wellbore region.

Development of a Numerical Well Test Simulator for Polymer-surfactant Flooding and the Pressure Transient Response Study