Relevance. This study addresses the challenge of enhancing the efficiency of gas and gas-condensate field development in Russia, with a focus on increasing hydrocarbon recovery, particularly gas condensate. The introduction of reservoir pressure maintenance technology, involving the injection of various gaseous agents (hydrocarbon and non-hydrocarbon gases) into the productive formation, is proposed as a key solution to improve condensate recovery from gas-condensate reservoirs in the West Siberian oil and gas province, where current recovery rates do not exceed 30%. Aim. To determine the optimal gaseous injection agents and development schemes for the PK_18-19 reservoir, aimed at increasing condensate and gas recovery while ensuring economic viability. Methods. The study employs scientific literature analysis, mathematical modeling, and statistical methods. Results and conclusions. The authors developed the compositional model of the production target, enabling the evaluation of the effectiveness of injecting the following gaseous agents and mixtures: dry gas, nitrogen, carbon dioxide, a mixture of CH₄ and C₂H₆ (8:2 ratio), mixture of CH₄ and CO₂ (1:1), mixture of CH₄ and NO₂ (1:1), mixture of NO₂ and CO₂ (1:1), and mixture of CH₄, NO₂, and CO₂ (1:1:1 ratio). The simulation results demonstrated that carbon dioxide is the most effective agent for increasing condensate recovery, while nitrogen, despite its lower technological efficiency, proved to be the most economically viable option. The study emphasizes the importance of a comprehensive approach to selecting gaseous agents for reservoir pressure maintenance, considering both technological and economic factors, and provides recommendations for oil and gas companies to optimize field development processes.