Numerical investigation of hydraulic fracture propagation in a layered reservoir using the cohesive zone method

Guo, Jianchun; Luo, Bo; Lu, Cong; Lai, Jie; Ren, Jun

doi:10.1016/j.engfracmech.2017.10.013

Cited by 188 publications

(74 citation statements)

References 32 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…It can be seen in Figure 6 that the greater the stress difference, the more easily HFs tend to cross through NFs. The smaller the stress difference, the more conducive to the expansion of NFs [15,16].…”

Section: In Situ Stressmentioning

confidence: 99%

“…CZM has great advantages in predicting crack propagation orientation in different kinds of materials (such as metals, concrete, and rocks [14]). Furthermore, it has been used for simulating hydraulic fracture interactions with natural fracture [15][16][17].In this paper, using this method to simulate the hydraulic fracturing from initiation and propagation, the rock deformation and fluid exchange between porous infiltrated media and fractures are being coupled. The cohesive element is used to explain the tip fracture process.…”

mentioning

confidence: 99%

mentioning

confidence: 99%

See 2 more Smart Citations

Using Cohesive Zone Model to Simulate the Hydraulic Fracture Interaction with Natural Fracture in Poro-Viscoelastic Formation

et al. 2019

View full text Add to dashboard Cite

Hydraulic fracturing is a widely used production stimulation technology for conventional and unconventional reservoirs. The cohesive element is used to explain the tip fracture process. In this paper, the cohesive zone model was used to simulate hydraulic fracture initiation and propagation at the same time rock deformation and fluid exchange. A numerical model for fracture propagation in poro-viscoelastic formation is considered. In this numerical model, we incorporate the pore-pressure effect by coupling fluid diffusion with shale matrix viscoelasticity. The numerical procedure for hydraulically driven fracture propagation uses a poro-viscoelasticity theory to describe the fluid diffusion and matrix creep in the solid skeleton, in conjunction with pore-pressure cohesive zone model and ABAQUS was used as a platform for the numerical simulation. The simulation results are compared with the available solutions in the literature. The higher the approaching angle, the higher the differential stress, tensile stress difference, injection rate, and injection fluid viscosity, and it will be easier for hydraulic fracture crossing natural fracture. These results could provide theoretical guidance for predicting the generation of fracture network and gain a better understanding of deformational behavior of shale when fracturing.Energies 2019, 12, 1254 2 of 12 side, it may cause additional resources to leak. Therefore, understanding of how the hydraulic fractures interact with natural fractures is necessary and is beneficial to our future simulations and improvements. Overall, continuous research on hydraulic fracturing is necessary and worthwhile. Hydraulic fracture intersection with natural fracture was investigated through both laboratory and mine-back experimental approaches [4][5][6][7]. When hydraulic fractures intersect with natural fractures, there are three different developments. Hydraulic fractures cross over natural fractures without changing the volume or shape of natural fractures; hydraulic fractures divert into the natural fracture and expand the volume of the flow path; hydraulic fractures enter natural fractures and form a complex fracture network structure.Biot first proposed viscoelastic theory to study the linear viscoelasticity and anisotropy of porous media [8]. The influence of the permeability on the deformation and the settlement problem of the loaded column was discussed. A micromechanical method for explaining the theory of pore viscoelasticity of Biot is proposed by Abousleiman et al. [9]. The problem of drilling under plane-strain deformation is discussed and the effects of combined poro-and visco-elasticity are investigated. Simakin and Ghassemi [10] put forward another poro-viscoelastic model by considering the relaxation of the deviatoric stress and the symmetric effective stress. These constitutive models can be used to simulate the coupling process between fluid flow and creep deformation of matrix rocks, but they cannot be directly applied to simulate hydraulic fracturing, especially the ...

show abstract

Section: In Situ Stressmentioning

confidence: 99%

mentioning

confidence: 99%

See 1 more Smart Citation

Using Cohesive Zone Model to Simulate the Hydraulic Fracture Interaction with Natural Fracture in Poro-Viscoelastic Formation

et al. 2019

View full text Add to dashboard Cite

show abstract

“…Wang et al (2016) developed a hydraulic fracture model for both poroelastic and poroplastic formations with the cohesive zone method, where the effects of plastic deformation near the fracture tip and inside the reservoir are considered. Guo et al (2017) proposed a cohesive zone model to investigate hydraulic fracture in a layered reservoir to study the influence of geologic and fracture execution parameters. Wang (2015; combined extended finite element method (XFEM) and cohesive zone method to study fracture re-orientation from unfavorable perforations, and fracture interference and coalescence from multi-stage fracturing.…”

Section: Introductionmentioning

confidence: 99%

Hydraulic fracture propagation in naturally fractured reservoirs: Complex fracture or fracture networks

Wang

2019

Journal of Natural Gas Science and Engineering

135

View full text Add to dashboard Cite

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, pre-existing 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 (SRV), drained reservoir volume (DRV) and completion efficiency. 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, a global cohesive zone model is presented to investigate hydraulic propagation in naturally fractured reservoirs, along with a comprehensive discussion on hydraulic fracture propagation behaviors in naturally fractured reservoirs. The results indicate that in naturally fractured reservoirs, hydraulic fracture can turn, kink, branch and coalesce, and the fracture propagation path is quite complex, but it does not necessarily mean that fracture networks can be created, even under low horizontal stress difference, because of strong stress shadow effect and flow-resistance dependent fluid distribution. Perhaps, 'complex fracture', rather than 'fracture networks', is the norm in most unconventional reservoirs.

show abstract

“…It is well known that a fracture initiates once the stress on the wellbore wall overcomes the concentrated hoop stress and the tensile strength of the rock (Chuanliang et al 2015;Guo et al 2017a, b;Zhu et al 2014). Therefore, FIP (i.e., the wellbore pressure at the critical moment of fracture initiation) is determined by the hoop stress and the tensile strength.…”

Section: Introductionmentioning

confidence: 99%

Mudcake effects on wellbore stress and fracture initiation pressure and implications for wellbore strengthening

Feng

Gray

2018

Pet. Sci.

View full text Add to dashboard Cite

Although a large volume of mudcake filtration test data is available in the literature, effects of mudcake on wellbore strengthening cannot be quantified without incorporating the data into a stress-analysis model. Traditional models for determining fracture initiation pressure (FIP) either consider a wellbore with an impermeable mudcake or with no mudcake at all. An analytical model considering permeable mudcake is proposed in this paper. The model can predict pore pressure and stress profiles around the wellbore, and consequently the FIP, for different mudcake thickness, permeability, and strength. Numerical examples are provided to illustrate the effects of these mudcake parameters. The results show that a low-permeability mudcake enhances FIP, mainly through restricting fluid seepage and pore pressure increase in the nearwellbore region, rather than by mudcake strength. Fluid loss pressure (FLP) should be distinguished from FIP when a mudcake is present on the wellbore wall. Fracture may occur behind the mudcake at FIP without mudcake rupture. The small effect of mudcake strength on FIP does not mean its effect on FLP is small too. Mudcake strength may play an important role in maintaining integrity of the wellbore once a fracture has initiated behind the mudcake.

show abstract

Numerical investigation of hydraulic fracture propagation in a layered reservoir using the cohesive zone method

Cited by 188 publications

References 32 publications

Using Cohesive Zone Model to Simulate the Hydraulic Fracture Interaction with Natural Fracture in Poro-Viscoelastic Formation

Using Cohesive Zone Model to Simulate the Hydraulic Fracture Interaction with Natural Fracture in Poro-Viscoelastic Formation

Hydraulic fracture propagation in naturally fractured reservoirs: Complex fracture or fracture networks

Mudcake effects on wellbore stress and fracture initiation pressure and implications for wellbore strengthening

Contact Info

Product

Resources

About