To improve existing technologies for the development of gas condensate fields, studies were carried out using digital modeling tools. The aim of the research is to optimize the cycling process in the development of gas condensate fields with significant condensate reserves. The study was carried out on the basis of a digital threedimensional model for a different number of injection wells (2, 4, 6, 8, 10 wells). Based on the research results, it was found that when dry gas is injected into a productive reservoir, reservoir pressure is maintained at a higher level compared to the depletion development option. Thanks to this, favorable conditions are provided for the stabilization of hydrocarbon production and the period of stable development of the gas condensate reservoir is extended. The results of the conducted studies indicate that the introduction of reservoir pressure maintenance technology provides an increase in the cumulative production of gas and condensate. This result is achieved primarily by transferring part of the condensed hydrocarbons into the gas phase, followed by its production. It should be noted that when dry gas is injected into a productive reservoir, micro- and macro-trapped gas is also displaced from the pore space. The simulation results indicate that an increase in the number of injection wells leads to a greater coverage of the gas-bearing area of the gas condensate reservoir by the injection agent. Also, according to the analysis, it was found that there is a certain maximum number of injection wells, using which the highest hydrocarbon recovery factor is achieved. According to the results of processing the calculated data, the maximum number of injection wells for the implementation of reservoir pressure maintenance technology for the conditions of a particular reservoir is 6.18(6) wells. The final condensate recovery factor for the set number of injection wells is increased by 5.76% compared to the development in reservoir energy depletion mode