Relevance. Geologic-hydrodynamic modeling is an integral part of field development design. The process of geological and hydrodynamic model adaptation to the development history is multi-iterative and is accompanied by a high degree of uncertainty of geological parameters. The quality of model adaptation directly affects the reliability of forecast indicators, on the basis of which key design decisions are made. One of the main macroparameters in model adaptation is the type of relative phase permeability curves. Optimization of setting this macro-parameter will significantly reduce resource and time costs during geological and hydrodynamic model adaptation. Aim. Development of an approach for automatic adjustment of relative phase permeability curves. Methods. Geologic-hydrodynamic modeling, mathematical modeling, statistical methods. Results and conclusions. The authors have developed the approach of automatic adjustment of relative phase permeability curves to the dynamics of reservoir performance. The approach is implemented as a machine code in the Python programming language. Initial testing was carried out on six deposits with terrigenous and carbonate reservoir type of fields of Volga-Ural and Timan-Pechora oil and gas bearing provinces. High convergence of actual curves of relative phase permeabilities, adjusted in the process of multi-iteration adaptation of hydrodynamic model, with calculated model curves was noted. At the next stage, the method was tested on a complex carbonate object with high fluid viscosity. It was found that within one iteration it was possible to adjust the integral parameters of oil production and water cut with a high degree of convergence. Thus, the developed approach makes it possible to significantly reduce the time of adjustment of relative phase permeability curves for the dynamics of reservoir development by using the program module.