Numerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM

There are a large number of natural fractures in shale reservoirs, which create great challenges to hydraulic fracturing. Activating the natural fractures in reservoirs can form a complex fracture network, enhance fracturing effects, and increase shale gas production. Reservoir geological conditions...

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Autores principales:	Yang Yang, Zixi Jiao, Longhuan Du, Hua Fan
Formato:	article
Lenguaje:	EN
Publicado:	Frontiers Media S.A. 2021
Materias:	fluid-driven fracture fracture network morphology global cohesive zone method numerical study fracture properties Science Q
Acceso en línea:	https://doaj.org/article/30dde058bd9b43db9d877f29d3672086
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id	oai:doaj.org-article:30dde058bd9b43db9d877f29d3672086
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spelling	oai:doaj.org-article:30dde058bd9b43db9d877f29d36720862021-11-15T04:54:29ZNumerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM2296-646310.3389/feart.2021.775446https://doaj.org/article/30dde058bd9b43db9d877f29d36720862021-11-01T00:00:00Zhttps://www.frontiersin.org/articles/10.3389/feart.2021.775446/fullhttps://doaj.org/toc/2296-6463There are a large number of natural fractures in shale reservoirs, which create great challenges to hydraulic fracturing. Activating the natural fractures in reservoirs can form a complex fracture network, enhance fracturing effects, and increase shale gas production. Reservoir geological conditions (low in situ stress, natural fracture distribution, and cement strength) and operation parameters (fracturing fluid viscosity and injection rate) have an important influence on fracture network propagation. In this article, a two-dimensional hydraulic fracturing fluid-mechanic coupling numerical model for shale reservoirs with natural fractures was established. Based on the global cohesive zone model, the influence of geological conditions and operation parameters on the propagation of the hydraulic fracture network and fracturing process is investigated. The numerical simulation results show that when the horizontal in situ stress difference, approach angle, and cement strength are low, it is easier to form a complex fracture network. Research on the construction parameters indicated that when the viscosity of the fracturing fluid is low, it is easier to form a complex network of fractures, but the length of the fractures is shorter; in contrast, the fractures are straight and long. In addition, increasing the injection rate is beneficial for increasing the complexity of the fracture network while increasing the initiation pressure and width of the principal fracture reduces the risk of sand plugging. This article also proposes an optimization solution for hydraulic fracturing operations based on numerical simulation results.Yang YangZixi JiaoLonghuan DuHua FanFrontiers Media S.A.articlefluid-driven fracturefracture network morphologyglobal cohesive zone methodnumerical studyfracture propertiesScienceQENFrontiers in Earth Science, Vol 9 (2021)
institution	DOAJ
collection	DOAJ
language	EN
topic	fluid-driven fracture fracture network morphology global cohesive zone method numerical study fracture properties Science Q
spellingShingle	fluid-driven fracture fracture network morphology global cohesive zone method numerical study fracture properties Science Q Yang Yang Zixi Jiao Longhuan Du Hua Fan Numerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM
description	There are a large number of natural fractures in shale reservoirs, which create great challenges to hydraulic fracturing. Activating the natural fractures in reservoirs can form a complex fracture network, enhance fracturing effects, and increase shale gas production. Reservoir geological conditions (low in situ stress, natural fracture distribution, and cement strength) and operation parameters (fracturing fluid viscosity and injection rate) have an important influence on fracture network propagation. In this article, a two-dimensional hydraulic fracturing fluid-mechanic coupling numerical model for shale reservoirs with natural fractures was established. Based on the global cohesive zone model, the influence of geological conditions and operation parameters on the propagation of the hydraulic fracture network and fracturing process is investigated. The numerical simulation results show that when the horizontal in situ stress difference, approach angle, and cement strength are low, it is easier to form a complex fracture network. Research on the construction parameters indicated that when the viscosity of the fracturing fluid is low, it is easier to form a complex network of fractures, but the length of the fractures is shorter; in contrast, the fractures are straight and long. In addition, increasing the injection rate is beneficial for increasing the complexity of the fracture network while increasing the initiation pressure and width of the principal fracture reduces the risk of sand plugging. This article also proposes an optimization solution for hydraulic fracturing operations based on numerical simulation results.
format	article
author	Yang Yang Zixi Jiao Longhuan Du Hua Fan
author_facet	Yang Yang Zixi Jiao Longhuan Du Hua Fan
author_sort	Yang Yang
title	Numerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM
title_short	Numerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM
title_full	Numerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM
title_fullStr	Numerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM
title_full_unstemmed	Numerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM
title_sort	numerical simulation of shale reservoir fluid-driven fracture network morphology based on global czm
publisher	Frontiers Media S.A.
publishDate	2021
url	https://doaj.org/article/30dde058bd9b43db9d877f29d3672086
work_keys_str_mv	AT yangyang numericalsimulationofshalereservoirfluiddrivenfracturenetworkmorphologybasedonglobalczm AT zixijiao numericalsimulationofshalereservoirfluiddrivenfracturenetworkmorphologybasedonglobalczm AT longhuandu numericalsimulationofshalereservoirfluiddrivenfracturenetworkmorphologybasedonglobalczm AT huafan numericalsimulationofshalereservoirfluiddrivenfracturenetworkmorphologybasedonglobalczm
_version_	1718428798019436544

Numerical Simulation of Shale Reservoir Fluid-Driven Fracture Network Morphology Based on Global CZM

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