The article presents a methodology for analysing historical gas production data and determining the gas reserves and the petrophysical parameters of a reservoir-aquifer system. These parameters are obtained from a fitting algorithm using production data sets. A forecast of the future field gas production can be created on the calibrated mathematical model basis. The developed method is based on the material balance assumptions and the widely used Fetkovich and van Everdingen-Hurst equations for calculating water influx. To conduct the calculations and analyse production data, the computer application was developed using Python programming language. A user-friendly graphical interface makes the proposed application convenient and intuitive to use. The software was calibrated based on the literature data from the gas field of known parameters and then validated using five case studies of the actual gas fields in the Polish Carpathian Foredeep. From the tests, very high compatibility between the computed and the real field values were obtained. An additional comparison with the commercial program MatBal confirmed the proper functioning of the application.

The study examines the application of dry gas injection technology (cycling process) in different depletion stages (25%, 50%, 75%, 100% of the initial reservoir pressure, and the dew point pressure) at a gas condensate field. The injection took place with varying numbers of injection wells relative to production wells (4:1, 3:1, 2:1, 1:1, and 1:2). The study assessed the impact of dry gas injection periods, ranging from 1 to 3 years, on increasing the condensate recovery factor in a real gas condensate reservoir named X. A hydrodynamic model was used and calibrated with historical data, resulting in a comprehensive approach. Compared to the traditional depletion development method, this approach led to a significant 9% rise in the condensate recovery factor. The results indicate that injection has a positive effect on enhancing the recovery factor of condensate and gas when compared to primary development methods based on depletion. As a result, these findings facilitate a rapid evaluation of the possibility of introducing similar measures in gas-condensate reservoirs in the future for reservoir systems that have a low and moderate potential for liquid hydrocarbons C5+. The optimised multidimensional hydrodynamic calculations, utilising geological and technological models, are crucial in determining the parameters for the technological production and injection wells.