Simultaneous numerical simulation of the hydraulic fractures geometry in multi-stage fracturing for horizontal shale gas wells

Prieto, Miguel L.; Aristizabal, Jadier; Pradilla, Diego; Gómez, Jessica María

doi:10.1016/j.jngse.2022.104567

Cited by 14 publications

(5 citation statements)

References 18 publications

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“…The FDM is a class of numerical simulation approaches to solve differential equations by approximating the derivatives with finite differences within the discretization of time and spatial domain. Prieto et al 122 used the implicit FDM along with the transmissibility of the fracture for the study of hydraulic fracturing geometry in multistage fracturing in horizontal shale wells. They used the FDM to solve the partial differentiation equation of fracture propagation in shale reservoirs.…”

Section: Finite Element Methodsmentioning

confidence: 99%

A comprehensive review of numerical simulation methods for hydraulic fracturing

Ismail,

Azadbakht

2024

Num Anal Meth Geomechanics

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Hydraulic fracturing unlocks previously inaccessible hydrocarbons in unconventional reservoirs by creating artificial pathways in the unconventional reservoir. Numerical simulation expands the scope of hydraulic fracturing design for various reservoir conditions. This review paper explores the synergy between numerical simulation and hydraulic fracturing modeling, focusing on critical elements like geomechanical behavior, geological conditions, and fluid dynamics. Analytical models in hydraulic fracturing design are discussed to underscore their foundational importance. The assumption of constant fracture height limits the application of Perkins–Kern–Nordgren model (PKN) and Kristianovich‐Geertsma‐de Klerk model (KGD). Radial models assume 3D flow but lack reliability in nonradial settings, and the Pseudo 3D model (P3D) shares PKN's assumptions with variable fracture height, sacrificing some details for efficiency. Planar 3D model (PL3D) enhances accuracy by discarding PKN's elastic response assumption but requires extended computation. Unconventional fracture model is effective for complex scenarios but relies on DFN modeling parameters for accuracy. The choice of numerical simulation method in hydraulic fracturing depends on the specific aspect studied, each with its strengths and limitations. For instance, boundary element methods are efficient for exterior problems, finite element modeling suits 3D nonplanar fractures, and the extended finite element method excels in hydraulic and natural fracture interactions. Peridynamics shows potential but needs further development for cost‐effectiveness. PFC and UDEC/3DEC‐based simulations can explore microscopic mechanisms. Combining these methods with other approaches provides a comprehensive study of realistic reservoir conditions. This review guides the selection of a suitable numerical simulation methodology based on the study's scope.

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Section: Finite Element Methodsmentioning

confidence: 99%

A comprehensive review of numerical simulation methods for hydraulic fracturing

Ismail,

Azadbakht

2024

Num Anal Meth Geomechanics

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show abstract

“…In this paper, using the plane strain assumption to describe fracture propagation and fluid flow will indeed introduce some error into the results, while considering the large kinetic energy of injected 6 Geofluids fracturing fluid and the limited influence of gravity, it can be approximately simplified to the same flow state in all cross sections, which is the assumption adopted in the classical hydraulic fracturing KGD model [46]. This assumption is widely used in numerical models of hydraulic fracturing [21,25,47,48].…”

Section: Fluid Flow In Porous Mediamentioning

confidence: 99%

Phase Field Modeling of Multiple Fracture Growth in Natural Fractured Reservoirs

Liu

2023

Geofluids

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In recent years, hydraulic fracturing techniques have been widely used in extracting unconventional reservoir resources. During multicluster fracturing process, the stress shadowing effect can lead to a nonuniform distribution of fracturing fluid. In this paper, a two-dimensional multiple fracture propagation model is developed based on phase field method considering the distribution of fracturing fluid within each fracture during fracturing process. The distribution of fracturing fluid injected into each fracture is calculated through solving governing equations of perforation friction as well as wellbore friction. Numerical results demonstrate that the natural fractures in the reservoir have a significant influence on the distribution of injected fluid and the morphology of fracture network. In addition, higher injection rates and higher fluid viscosity stimulations are in favor of inducing uniform distribution of injected fluid into each cluster. The presented numerical model provides an effective tool to extend our understandings in generating fracture networks.

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“…Pezzulli et al 15 used HFM asymptotes in the finite element method to predict the position of the hydraulic fracture front in a viscous-ductile state. Prieto et al 16 proposed a numerical simulation strategy combining the fracture propagation module, formation stress module, and flow distribution module to calculate the geometry and distribution of hydraulic fractures within the formation. Wang et al 17 simulated the interaction between hydraulic and natural fractures by the EPM fracture simulation method.…”

Section: Introductionmentioning

confidence: 99%

Study on the Law of True Triaxial Hydraulic Fracturing by Acoustic Emission Monitoring

Hailong,

Wang,

Anze

et al. 2024

ACS Omega

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Hydraulic fracturing generates fractures in a coal seam, which has been extensively used in coal mining and disaster management. To study the influences of water injection pressure and time on the propagation of hydraulic fracture, we conducted true triaxial hydraulic fracturing experiments under acoustic emission monitoring. Five briquette specimens were prepared by molding the mixture of coal powder, cement, river sand, and distilled water under 60 MPa to simulate the properties of coal seam. True triaxial loading was used to simulate the in situ stress environment of the coal seam. Hydraulic fracturing experiments on the test specimens were conducted under different water injection pressures and times. The following conclusions have been drawn. At the fixed injection time, increasing water injection pressure promotes the propagation of hydraulic fracture and the migration of water in the coal seam after the fractures are connected. The number of fractures increases from 3 to 8 as the water injected pressure increased from 3 to 9 MPa. Under the constant water injection pressure, the increase in longitudinal wave velocity in the test specimen decreases with the prolongation of water injection time. When the water reaches the action boundary of the water injection pressure, the water stops moving. At this moment, the water injection time has no effect on the longitudinal wave velocity anymore. The fracturing influence range can be increased by increasing the water injection pressure to produce a fracture network of a large radius with many fractures. Appropriately prolonging hydraulic fracturing time can ensure that the fracturing fluid fully moistens the coal seam and thus effectively reduces dust pollution.

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Simultaneous numerical simulation of the hydraulic fractures geometry in multi-stage fracturing for horizontal shale gas wells

Cited by 14 publications

References 18 publications

A comprehensive review of numerical simulation methods for hydraulic fracturing

A comprehensive review of numerical simulation methods for hydraulic fracturing

Phase Field Modeling of Multiple Fracture Growth in Natural Fractured Reservoirs

Study on the Law of True Triaxial Hydraulic Fracturing by Acoustic Emission Monitoring

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