The paper discusses the relationship between the mechanical properties of oil-saturated reservoirs and stability of the near-wellbore zone during the long-term exploitation of an oil field. The relevance of this task is associated with on one hand the choice of the most rational wellbore design, and on the other – the necessity to consider the mechanisms of rock pressure manifestation, reservoir destruction during fluid movement, etc. These interconnected factors are typically assessed through studies of dynamic petrophysics in the field of oil and gas reservoir development. During the operation of producing wells, a significant decrease is observed in reservoir pressure as a result of the formation of a depression cone in the near-wellbore zone. The most optimal approach is to analyse changes in reservoir pressure over time. The paper provides an example of tracer studies of the averaged filtration parameters of reservoir rocks in the interval between injection and production wells. The paper describes cases of modelling in-reservoir fluid dynamics, where the injection well is located on the flank of the structure, and the production well is at its crest, and vice versa. The paper also presents assessments of mechanical properties (hardness, yield strength, etc.) of core samples at various levels of confining pressure.  Terrigenous and volcanoclastic-sedimentary reservoirs with a specific cavernous pore structure were used for testing. The results of these studies allowed the classification of the tested samples according to the criteria of Deere and Miller, as well as the establishment of correlation relationships between individual physiccal and mechanical properties.

Keywords: bottom hole zone, terrigenous reservoirs, mechanical properties, confining pressure

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