Enhancing Horizontal Wells Production Efficiency Using Fracture Propagation and Numerical Simulation Techniques

Abstract To investigate the impact of actual fracture propagation morphology on productivity prediction in multi-cluster fracturing and optimize stimulation designs, this study employs the displacement discontinuity method (DDM) to analyze the effects of cluster spacing and cluster number on fracture propagation patterns and fluid distribution. Using CMG numerical simulation software with actual geological parameters from Block M of Xinjiang Oilfield, a homogeneous single-well fracturing model was established to determine optimal stimulation parameters for maximum productivity. Results indicate that as cluster numbers increase, the range of fluid intake percentage and fracture length differences initially expands. Challenges such as unclear fracture propagation patterns and frequent well interference significantly constrain efficient development of low-permeability reservoirs. Through integration of geological characteristics and fracture propagation simulations, the study analyzes volumetric fracture propagation in horizontal well groups and the influence of natural fractures on hydraulic fracture growth, clarifying key well interference factors. Key findings include: (1) In naturally fractured zones, hydraulic fracture behavior is dominated by the induction, capture, and barrier effects of natural fractures; (2) Asymmetric propagation and non-uniform initiation caused by natural fractures are primary drivers of well interference; (3) The development degree of natural fractures critically influences hydraulic fracture propagation. These insights provide a scientific basis for optimizing hydraulic fracturing parameters in the reservoir.