Discrete Fracture Network Simulation of Shale Reservoir

Abstract

Shale reservoirs are characterized by low porosity, low permeability, and extensive natural fractures, where fluid migration and storage primarily depend on complex fracture networks. As the primary flow channels in shale reservoirs, natural fractures not only directly govern hydrocarbon migration and distribution but also significantly influence the expansion of hydraulic fracturing fracture networks and fracturing effectiveness. Given the pronounced heterogeneity, anisotropy, and fractal characteristics of shale fractures, traditional equivalent continuum models struggle to accurately describe their intricate geometry and flow behavior. This study employs a discrete fracture network (DFN) simulation method to model spatial parameters including fracture orientation, inclination angles, and lengths. The results provide a realistic representation of natural fracture distribution in shale reservoirs, offering enhanced structural foundations for reservoir evaluation, fracturing design, and flow simulation. Therefore, DFN modeling of natural fracture systems in shale reservoirs serves dual purposes: it provides crucial insights into storage mechanisms and flow processes, while also constituting a pivotal element for optimizing shale hydrocarbon development efficiency and fracturing operations.