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AbstractCurrent studies of geologic storage of CO 2 , with the exception of CO 2 sequestration in coal beds, focuses on supercritical CO 2 , emphasizing the stability of the fluid, solubility of CO 2 in saline formation water and miscibility with crude oil. Likewise, with the exception of very early research, the use of CO 2 to enhance oil recovery (EOR) historically focused on supercritical CO 2 to achieve miscible conditions with crude oil. The only possibility of liquid CO 2 geologic storage is in formations with temperatures less than the critical temperature of CO 2 .Due to the naturally occurring geothermal temperature gradient, most all geologic formations currently considered for CO 2 sequestration and EOR exceed the T cCO2 .A research plan has been developed to investigate the use of depleting (mature) oil reservoirs with formation temperatures less than critical temperature of CO 2 to sequester liquid CO 2 and investigate the implications of EOR from the liquid CO 2 displacement process. Relatively higher pressures are required to attain liquid CO 2 , which translate to fracture gradients as high as 1.0 psi/ft. However, fracture stimulation data published in early literature and field data from fracture stimulation companies in the Illinois Basin show that fracture gradients of up to 1.0 psi/ft are commonly recorded in the shallower producing horizons of the Basin. Therefore, the pressure requirement may not be a detriment.Because of the liquid/gas phase changes and consequent changes in density and viscosity of CO 2 at subcritical temperatures, low temperature oil reservoirs provide a unique opportunity for liquid CO 2 storage and the application of a novel and innovative EOR-CO 2 cyclic multi-reservoir displacement process within the Illinois Basin.
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