The application of a new Material Point Method (MPM) approach to model the proppant distribution in a reservoir where hydraulic fractures interact with natural fractures is presented and validated with an Eagle Ford well. The new MPM approach uses particles to represent the slurry and its effects on the hydraulic and natural fractures. The particles are injected in the hydraulic fractures and their action causes the hydraulic fractures to propagate and interact with the natural fractures thus providing new pathways for the proppant to move away from the wellbore when optimal natural fracture orientations are encountered. Elementary tests showed that long fractures oriented in 30 and 60 degree from the hydraulic fracture directions facilitate the proppant placement. However, the stress anisotropy seems to have little effects for fractures oriented in 30 and 60 degree but allows a better proppant placement for fracture oriented 90 degrees from the hydraulic fracture. The application of the new technology to an entire Eagle Ford well shows that the simulated proppant indicates a large propped volume towards the heel and a poor proppant placement at the toe stages as indicated by other methods. These field validated results, show that the macroscopic modeling of proppant distribution using the coupled solid/fluid MPM technology could be used in improving our understanding of the complex hydraulic fracturing process and the resulting proppant distribution that provide the needed initial stimulated permeability.

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