Many petrophysical models describe the relationship of reservoir permeability with various parameters of the pore space structure and rock saturation. The presence of a large number of such models is due to the heterogeneity of the mineral composition of rocks, the shape, and size of grains that make up the mineral skeleton, and, accordingly, the structure of the pore space - one of the main factors influencing the permeability. The nature of the saturation of the pore space and the characteristics and physical state of the components of the formation fluid also has a significant effect. The combination of the above-mentioned factors influencing the value of reservoir permeability is the reason for the complexity of petrophysical models, and their variability allows for the creation of only generalized models that need to be adapted for each layer to achieve the required level of reliability. This approach involves a lot of factual material, laboratory research, and highly qualified staff. In this paper, the authors propose an effective way to solve the problem of determining the permeability coefficients of reservoirs based on the results of well logging. Having the value of the reservoir permeability coefficient determined in the well by one of the direct methods, in other wells, the authors propose to determine not the absolute value of the permeability coefficient but its relative change. According to the Schlumberger model, such a change is closely related to the change in the residual water coefficient and porosity, which can be determined from the well logging data
Received 18.01.2022
Revised 23.03.2022
Accepted 23.05.2022
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