This paper delves into a novel micro-substance tracer test in fractured horizontal well C-15. The experimental results are highly encouraging as they demonstrate that the trace material tracer is capable of satisfying the testing demands, even when there are large numbers of fracturing stages involved. Data interpretation process involved dividing the test duration into two stages-fluid flowback period and stable production period. The tracer test data were employed to analyze the production profile of the well. The findings made it evident that the primary production stage underwent alterations in different production stages. Moreover, the degree of heterogeneity pertaining to each fracturing stage was characterized by employing the residence time distribution method. It was observed that the Lorentz coefficient lying between the primary production stage and the remaining fracturing stages ranged from 0.46 to 0.68. This study expands the application of the residence time distribution method for evaluating tracer testing. Through a comprehensive analysis of heterogeneity data within the fracturing stages and the production dynamics of the well, the effectiveness of the fracturing process can be assessed. This research enables reservoir operators to gain deeper insights into the dynamics of test wells, ultimately leading to increased production efficiency.

This study focuses on addressing the challenge of accurately calculating the production caused by stress sensitivity and proppant embedment during actual production in low‐permeability gas reservoirs. To achieve this, a stress sensitivity model in the matrix zone and a proppant embedding model in the fracture area are established. Additionally, fluid flow models are formulated for the matrix zone and fracture area based on the seepage theory and fluid mechanics. Using these models, a production prediction model is developed for fractured horizontal wells in low‐permeability tight sandstone gas reservoirs considering the impact of proppant embedment. The production prediction model is solved using a coupling solution method, and the calculation results are verified against actual gas production. This study also analyses and discusses the stress sensitivity in low‐permeability gas reservoirs, the factors influencing conductivity, and the factors influencing productivity. The results indicate a strong stress sensitivity in the matrix area of low‐permeability gas reservoirs. In fracturing design, comprehensive consideration of fracture parameters is necessary. After fracturing, the optimal selection of proppants with appropriate particle sizes and careful optimization of the number of layers are crucial for maintaining stable production release. This research is significant for effectively and stably maximizing the productivity of low‐permeability gas reservoirs.