Production Capacity and Key Factors Influencing Tight Sandstone Gas Reservoirs

Abstract Tight sandstone reservoirs typically exhibit high initial water saturation, which often leads to the emergence of gas-water two-phase flow during the development process. This phenomenon results in significant water production issues in certain gas wells, adversely affecting their production capacity. In this study, a numerical simulation model is developed to investigate the dynamics of gas-water two-phase flow in tight gas reservoirs. The model integrates the geological characteristics of tight gas formations with the seepage behavior of hydraulic fractures to more accurately capture the flow mechanisms at play. The study examines how several key factors, including critical flow saturation, water saturation, the water-phase seepage curve index, startup pressure gradient, permeability, and reservoir thickness, influence gas well productivity. These parameters are critical in determining the flow efficiency and overall performance of tight gas reservoirs, where traditional development methods may not be as effective. The simulation results indicate that these factors significantly impact well performance, with critical flow saturation and permeability showing the most profound effects on production capacity. By optimizing these parameters, the study suggests strategies to enhance gas well performance, reduce water production, and improve overall reservoir management. The model also provides valuable insights into the development of gas wells in tight sandstone formations, offering a more comprehensive approach to addressing water production challenges. Ultimately, the research contributes to the optimization of gas extraction processes, improving efficiency and extending the productive life of tight gas reservoirs.