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By increasing the viscosity of the displacing fluid (gas or foam), the displacement process is stabilized; By blocking the high-permeability swept layers and diverting the fluids into low-permeability unswept zones; and.
The displacement process is captured via a high-speed video microscope under ambient conditions.
Quasi-static model is used in this work and the drainage displacement process is simulated.
Oil rate responses, GOR declines and low water production rates indicate a very efficient oil displacement process is occurring.
It is also observed from the displacement profile that the displacement process is delayed in the numerical simulation than that in laboratory experiment (see Figs. 14, 15, 16).
The basic assumptions include: (1) the model contains oil and water two-phase flow; (2) the fluid flow obeys Darcy's law; (3) the displacement process is isothermal; (4) the fluid flow without considering gravity and capillary pressure.
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The pressure drops and water saturation in the displacement process are shown in Fig. 9.
The same displacement process was performed in core sample B. The gas mobility reduction was observed during slug of CO2 injection after foam surfactant solution.
Liu et al. (2015b) investigated the CO2 CH4 displacement process in sand packs, and the displacement process was scanned with a resolution of approximately 34.2 mm by an X-ray CT scanner.
This was due to the matrix flow in the miscible displacement process being slow during the pulse, although greater amounts of Cl− entered the matrix, so that it initially had no evident effect on the solute in the effluent.
The history matching of the displacement process was optimized by using the Levenberg Marquardt algorithm to minimize the error between the simulated and experimental production data (oil and water).
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