Predicting Oil Recovery through CO2 Flooding Simulation Using Methods of Continuous and Water Alternating Gas
Margaretha Marissa Thomas (a*), Fathaddin, M.T. (a), Usman Pasarai

a)Petroleum Engineering Department, Universitas Trisakti,
Jakarta, Indonesia
*)mmarissa89[at]gmail.com
b)PPPTMGB Lemigas, Jakarta, Indonesia

Abstract

In this study, CO2 Flooding simulation models were used to predict oil recovery. The models were previously validated by laboratory experiments of Continuous Injection and Water Alternating Gas (CO2) injection for miscible condition. Sensitivity test was performed to attain the best injection rate parameters.The simulation experiments indicated that the optimal performance for both methods obtained at injection rate of 0,09 cuft/day. The scenarios of continuous CO2 injection showed that the maximum recovery factor (RF) is 21%. While the scenarios of Water Alternating Gas, the maximum RF is 38%. Based on the whole scenarios used, WAG displacement resulted in more effective RF value than Continuous Flooding, within the range of injection rate studied.

Keywords: CO2 Injection, Simulation, Recovery Factor

Topic: Chemical Engineering

Link: https://ifory.id/abstract-plain/eAnrc9zYMEdt

Web Format | Corresponding Author (Muhammad Taufiq Fathaddin)