Abstract
All reservoirs are fractured to some degree. Depending on the density, dimension, orientation and the cementation of natural fractures and the location where the hydraulic fracturing is done, preexisting natural fractures can impact hydraulic fracture propagation and the associated flow capacity. Understanding the interactions between hydraulic fracture and natural fractures is crucial in estimating fracture complexity, stimulated reservoir volume, drained reservoir volume and completion efficiency. However, because of the presence of natural fractures with diffuse penetration and different orientations, the operation is complicated in naturally fractured gas reservoirs. For this purpose, two numerical methods are proposed for simulating the hydraulic fracture in a naturally fractured gas reservoir. However, what hydraulic fracture looks like in the subsurface, especially in unconventional reservoirs, remain elusive, and many times, field observations contradict our common beliefs. In this study, the hydraulic fracture model is considered in terms of the state of tensions, on the interaction between the hydraulic fracture and the natural fracture (45°), and the effect of length and height of hydraulic fracture developed and how to distribute induced stress around the well. In order to determine the direction in which the hydraulic fracture is formed strikethrough, the finite difference method and the individual element for numerical solution are used and simulated. The results indicate that the optimum hydraulic fracture time was when the hydraulic fracture is able to connect natural fractures with large streams and connected to the well, and there is a fundamental difference between the tensile and shear opening. The analysis indicates that the growing hydraulic fracture, the tensile and shear stresses applied to the natural fracture.
Highlights
Since its introduction, hydraulic fracturing has been established as the premier production enhancement procedure in the petroleum industry and has continued to overwhelmingly dominate low-permeability reservoirs as one of the most important field development operations (Rubin 1993)
By simulating the clefts around the well in the reservoir using a discrete element method, a hydraulic fracture with different lengths in the reservoir and in a predetermined direction will extend along the length of the production rate
The intersection of gap and reverse suction phenomena that occurs in the interaction between hydraulic fracture and natural fracture in naturally fractured reservoirs are considered, and their effects on production rates are investigated
Summary
Hydraulic fracturing has been established as the premier production enhancement procedure in the petroleum industry and has continued to overwhelmingly dominate low-permeability reservoirs as one of the most important field development operations (Rubin 1993). Achieving more production requires re-activation of the reservoir to increase permeability and raising the production of wells. Because of the well construction and low permeability of the reservoir. In very high permeability reservoirs, hydraulic fractures have a dual purpose: to stimulate the well and to provide sand control. The fracture accelerates production without impacting the well reserves. In low-permeability reservoirs, hydraulic fracture contributes both to well productivity and to the well reserves, because in such reservoirs the well would not produce an economic rate without the hydraulic fracture (Pang et al 2016).
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