Development of a 3D numerical model for quantifying fluid-driven interface debonding of an injector well

Feng, Yongcun; Li, Xiaorong; Gray, K. E.

doi:10.1016/j.ijggc.2017.04.008

Cited by 103 publications

(29 citation statements)

References 27 publications

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“…[30][31][32][33][34][35][36] ABAQUS gets a rich material database to meet most engineering needs, and UMAT subroutines define arbitrary material properties autonomously. ABAQUS is a general purpose finite-element-analysis code that can analyze fluid seepage and mechanical problems in porous media and has been widely used for solving mechanical problems around a wellbore in recent years.…”

Section: Numerical Modelmentioning

confidence: 99%

“…ABAQUS is a general purpose finite-element-analysis code that can analyze fluid seepage and mechanical problems in porous media and has been widely used for solving mechanical problems around a wellbore in recent years. [30][31][32][33][34][35][36] ABAQUS gets a rich material database to meet most engineering needs, and UMAT subroutines define arbitrary material properties autonomously.…”

Section: Numerical Modelmentioning

confidence: 99%

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Wellbore shrinkage during drilling in methane hydrate reservoirs

Yan

Yang

Yan³

et al. 2019

Energy Science & Engineering

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Methane hydrates as a clean and abundant energy source, have attracted the attention of the world. However, the instability of hydrate reservoirs makes it difficult to drill production wells. After drilling, the creep properties of hydrate reservoir would cause wellbore shrinkage, which will affect the drilling safety. This study is to analysis law of wellbore shrinkage after a hydrate well drilled. The results demonstrate that wellbore shrinkage mainly results from plastic deformation and creep deformation. The largest and smallest values are separately found in the directions of the maximum and minimum horizontal in‐situ stress. With the increase of initial in‐situ stress ratio, wellbore shrinkage linearly rise. Under the condition of low horizontal in‐situ stress ratio, wellbore shrinkage is mainly determined by creep deformation. Under the condition of high horizontal in‐situ stress ratio, wellbore shrinkage commonly depends on plastic deformation and creep deformation. With deepening methane hydrate reservoirs, wellbore shrinkage shows a nonlinear increase. For formations with higher hydrate saturation, larger wellbore shrinkage would occur. The research results can provide a theoretical basis for the selection of drilling method while drilling in hydrate formations.

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Section: Numerical Modelmentioning

confidence: 99%

Section: Numerical Modelmentioning

confidence: 99%

Wellbore shrinkage during drilling in methane hydrate reservoirs

Yan

Yang

Yan³

et al. 2019

Energy Science & Engineering

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“…The cohesive traction-separation law is applied to control the fracture process for the fracture process zone (as shown in Figure 3). The law consists of three sections: initial loading constitutive Figure 3: Bilinear T-S law [27]. law (before damage), damage initiation, and damage evolution of the interface [27].…”

Section: Cohesive Traction-separation Lawmentioning

confidence: 99%

Evaluations of Fracture Injection Pressure and Fracture Mouth Width during Separate-Layer Fracturing with Temporary Plugging

Wang

Zhou

Liang

et al. 2018

Mathematical Problems in Engineering

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Separate-layer fracturing with temporary plugging (SLFTP) is a potential way to stimulate multiple layer reservoirs due to its low cost, low risk, and high efficiency. In this study, based on the cohesive zone model (CZM), a 3D fully fluid-solid coupling and multiple layer model is established to investigate factors influencing fracture injection pressure and fracture mouth width. The cohesive layer properties are based on the reported study, which have been validated through a series of numerical experiments. Innovatively, the spring model is innovatively proposed to represent the plugging effect of diverting agents and prop the aperture of the previous fractures. Simulation results reveal that the effects of previous fractures in multiple layer formations can be neglected, which is quite different from multistage fracturing for horizontal wells. Fracture injection pressure can be evaluated more accurately by taking the following factors into consideration: the minimum horizontal principal stress, rock tensile strength, injection rate, and pore pressure enhancement. Further, fracture mouth width is strongly influenced by rock tensile strength, Young’s modulus, and injection rate. This study provides a guidance for candidate well selection and diverting agent optimization during SLFTP in multilayer formations.

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“…The formula is reducible to Darcy law when reaches zero. The stress equilibrium equation of the solid formation under current configuration can be described in the form of virtual work (Wang 2015;ABAQUS 2014;Feng et al 2017): where is the total stress matrix, f is the body force vector, t is the surface stress vector, v is the virtual velocity vector, is the virtual strain rate matrix, V is the solid volume, and S is the surface area controlled by traction-separation law. The displacement is set as the nodal variables by discretizing the equation with a Lagrangian formulation for the solid formation.…”

Section: Coupling Between Fluid and Rockmentioning

confidence: 99%

“…The continuity of reservoir fluid is governed by the equation below in which the increase rate of fluid volume stored at a point equals the rate of volume of fluid flowing into the point within the time increment (Wang 2015;ABAQUS 2014;Feng et al 2016Feng et al , 2017:…”

Section: Coupling Between Fluid and Rockmentioning

confidence: 99%

A 3D numerical model for investigation of hydraulic fracture configuration in multilayered tight sandstone gas reservoirs

Gao

Cheng

Yan

2017

J Petrol Explor Prod Technol

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Multilayered tight sandstone gas reservoirs with low porosity and low permeability are usually developed by two kinds of hydraulic fracturing techniques, including general fracturing (simultaneously fracturing multiple target zones) and separate layer fracturing (sequentially fracturing the target zones from the bottom-up). However, fractures from different target zones are likely to communicate in the fracturing process which detrimentally causes the waste of fracturing fluid and proppants and finally affects the efficiency of fracturing treatment. Therefore, investigation related to hydraulic fracture configurations under different fracturing stimulation treatments is necessary with the objective of optimizing the fracturing design and predicting the production rate. In this paper, a 3D finite element model is established to simulate the propagation of multiple hydraulic fractures in the vertical well, and fracture configurations under different fracturing techniques and formation properties are analyzed and compared. The results indicate that, in vertical wells, stress interference between the fracture tips will accelerate the communication of adjacent vertical fractures along the height direction. And separate layer fracturing is preferable for stimulating multilayered tight sandstone gas reservoirs. Also, adjacent pay zones and barriers with high in situ stress contrast, high tensile strength contrast and low elastic modulus contrast are able to effectively prevent the communication of fractures along the height direction and lead to the increase of fracture length and width, and so does the barriers with large thickness.

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Development of a 3D numerical model for quantifying fluid-driven interface debonding of an injector well

Cited by 103 publications

References 27 publications

Wellbore shrinkage during drilling in methane hydrate reservoirs

Wellbore shrinkage during drilling in methane hydrate reservoirs

Evaluations of Fracture Injection Pressure and Fracture Mouth Width during Separate-Layer Fracturing with Temporary Plugging

A 3D numerical model for investigation of hydraulic fracture configuration in multilayered tight sandstone gas reservoirs

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