ABSTRACT Multi‐stage hydraulic fracturing in horizontal wells is vital for stimulating unconventional reservoirs, yet uneven fracture propagation often restricts the effective communication volume of the reservoir. We constructed a field‐scale Unconventional Fracturing Model that couples fluid flow, proppant transport, stress‐shadow mechanics, and height growth to explore competitive propagation among multiple clusters. Parametric experiments systematically varied cluster spacing, perforation count, proppant mass, and injection rate. Simulations reproduce the characteristic stress‐shadow pattern—fractures shorter near the wellbore midpoint and longer at stage edges—and quantify how perforation and injection parameters influence this imbalance. Widening cluster spacing most effectively equalizes fracture lengths and flows, reducing perforation density, lowering proppant loading, and increasing injection flow rate, further enhancing uniformity. Together, these adjustments keep the standard deviation of fracture length within design limits, improve fracture‐width retention, and promote more even fluid distribution across the stage. The results offer high‐level guidance for limited‐entry completion design to maximize stimulated‐reservoir volume in unconventional oil fields.
Xue et al. (2025) studied this question.