The article describes injection well placement method used in generation of oil field development scenarios within the scope of Epsilon software package development. This method is an improved modification of previously implemented algorithms for selection of project injection well locations. Epsilon (version 1.1) implements two algorithms for selection of project injection well locations from a set of points rejected during creation of the closest-spacing irregular pattern for project production wells due to geological or economic considerations. The first branch-and-bound optimization algorithm implies selection of a limited number of project injection well locations from the set of rejected points with account of constraints. These constraints include the minimum and maximum distance to drilled or project production wells, the presence of responding wells, and the effects on a limited maximum number of responding wells. The second algorithm provides for iterative subdivision of the entire production target area into squares of a given area and search for candidates for conversion to injection from "rejected" project locations within each square. Both algorithms, applied one after the other, yield a comprehensive set of project injection wells located at a certain spacing from project production wells. The resulting set of locations is used for project injection well placement in all field development scenarios generated in Epsilon software package through distribution of project production wells by years of planning (5-year horizon). At the same time, for voidage replacement purposes in high-rate production zones, characterized by decreasing reservoir pressures, some wells from a generated set of project injection wells should be brought to injection. Control of reservoir pressure, which is one of the most important factors contributing to energy potential of the productive formation, is of utmost importance. Reservoir pressure control entails identification of low and excess voidage replacement zones and monitoring the number of put into service/shut-in injection wells. The presented method enables: a) consideration of drilled and project production wells brought in and out of operation by forecast years; b) consideration of reservoir energy state as of the forecast year; c) conversion of idle and drilled wells brought out of operation to injection; d) planning of shutting-in of drilled and project injection wells.
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