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Summary The paper presents the results of modeling polymer flooding in a high-viscosity oil field in various modes. For modeling, a multilayer laterally heterogeneous reservoir model was used. This model was obtained as a result of automatic history matching of data from a real high-viscosity oil field in the Tatarstan (Russia). The considered modes of polymer injection differ in the duration of the injection, the concentration of the polymer, and the time of the beginning of its injection. For each of the modes, the volume of additionally produced oil is analyzed relative to injection without polymer over the entire time interval. The results obtained are additionally illustrated by the patterns of polymer propagation and oil displacement in the reservoir volume. It is shown that for high-viscosity oil fields, injection of polymer solution at earlier stages of development can give a significantly greater effect. In addition, for the same total polymer cost, an increase in polymer injection time at a not very high concentration may be preferable to a short injection of a more concentrated solution. |
