Abstract: To address the challenge of dynamically predicting gas production for indirectly fractured wells in broken soft coal seams, a productivity prediction model for such wells is established. The model couples multiple physical processes, including coalbed methane (CBM) desorption, diffusion, seepage, and interlayer flow, etc. Through laboratory interlayer flow experiments, the interlayer flow friction coefficient between coal rock and sandstone is obtained. An indirectly fractured reservoir seepage experiment is designed to validate the model. Simulation results indicate that indirect fracturing could promote CBM desorption near the interface and in areas far from the fractures, thereby significantly enhancing gas production. The permeability of adjacent layers and the thickness ratio of adjacent rock layers to the coal seam are both positively correlated with gas production. However, when the thickness ratio exceeds 1.6, the enhancement effect diminishes. The fracture height in adjacent layers has little influence on gas production, whereas increasing fracture length can substantially improve productivity. The factors influencing productivity sensitivity, in descending order, are fracture length, sandstone layer permeability, sandstone layer thickness, and fracture height in sandstone layers. The coefficient of determination for fitting between the field-measured daily gas production and the predicted values from a test well in the Qinshui Basin was 0.850, and the root mean square error was 0.0265×10⁴ m³/d further verifying the reliability of the model. The findings provide a theoretical basis for layer selection, and dewatering and production system optimization of indirectly fractured wells in broken soft coal seams.