A productivity prediction model for fractured horizontal wells in tight sandstone gas reservoirs: Accounting for reservoir heterogeneity and non-uniform fracture distribution.

The article focuses on developing an advanced productivity prediction model for multi-stage fractured horizontal wells in tight gas reservoirs by integrating equivalent wellbore theory with a generalized pseudo-pressure function. This model systematically incorporates multiple flow mechanisms—including stress sensitivity, slip effects, threshold pressure gradient, non-Darcy flow, and fracture heterogeneity—to more accurately represent gas flow behavior in complex, heterogeneous reservoirs. Validation using field data from a multi-fractured horizontal well in the Ordos Basin, China, demonstrates the model's superior predictive accuracy compared to traditional approaches. Sensitivity analyses reveal that fracture spacing, fracture half-length variations, and matrix permeability heterogeneity critically influence well productivity, underscoring the importance of accounting for spatial variations in fracture and reservoir properties. The study concludes with recommendations for future enhancements, such as incorporating dynamic fracture evolution and extending applicability to other unconventional reservoirs.