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and CO2 injection. The average pressure, oil rate, and water-oil volume ratio (WOR) of the three scenarios were matched with the available field data and the history matches were compared to each other. The results indicated that the three simulators provided comparable trends for the production history and pressure maps of the field. The rate of asphaltene precipitation was then compared between the three simulators and the results indicated that the three simulators generated similar trends forasphaltene precipitation behaviour, but with different numerical values. The results of the heterogeneous 3-D field-scale simulation study confirmed that the precipitation model behaved as expected, with the amount of asphaltene content of the oil phase decreasing as the pressure decreased above the saturation pressure, and the asphaltenes beginning to re-dissolve back into the oil phase below the saturation pressure, hence the amount of precipitated asphaltene decreased. It was found that asphaltene deposition moved along the displacement front during CO2 injection. This is because the deposition process is related to the development of the miscibility front of the CO2 flood that moves in the direction of flow from the injector to the producer. However, for conventional waterflooding, a much lower mass of deposited asphaltenes was found. These findings from the full-field simulation study agree with field observations reported in the literature. It was also found that the precipitated asphaltene might be deposited throughout the reservoir and not only in the vicinity of the wellbore

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