Numerical Study on the Division of Proppant Particles in the Horizontal Wellbore–Multifracture System

Non-uniform proppant distribution across simultaneous multiple fractures significantly undermines the conductivity. Conventional models often focus on proppant transport inside the fracture, neglecting the critical role of wellbore in determining proppant division. To bridge this gap, this study utilizes a Eulerian–Lagrangian model to simulate proppant transport within a horizontal wellbore and three intersecting fractures. We systematically evaluate the sensitivity of proppant placement to key parameters: injection rate, fluid viscosity, proppant size, density, and fracture width. The results demonstrate that increasing the injection rate is pivotal for transitioning from near-wellbore ‘heel-side’ plugging to effective toe-side coverage, concurrently reducing wellbore cleanout requirements. Conversely, low-viscosity fluids and high-density proppants exacerbate gravitational settling, restricting proppant entry to heel-side fractures. When proppant density approaches that of the carrier fluid, gravitational settling is minimized, facilitating a nearly uniform distribution across all three fractures. Additionally, narrow fracture widths act as hydraulic bottlenecks, where frequent particle–wall interactions dissipate kinetic energy and limit proppant penetration. This work offers a mechanistic understanding of proppant division, providing actionable insights for optimizing fluid systems and pump schedules.