Stimulated reservoir volume estimation for shale gas fracturing: Mechanism and modeling approach

Ren, Lan; Lin, Rungtai; Zhao, Jinzhou; Rasouli, Vamegh; Zhao, Jiangyu; Yang, Hao

doi:10.1016/j.petrol.2018.03.041

Cited by 59 publications

(28 citation statements)

References 20 publications

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“…3 tr represents the trace of the stress tensor. Based on Darcy's Law, the fluid flow velocity can be expressed as follows: If ignore the gravitational term, substituting Equation (14) in Equation (12), the relationship between strain and pore pressure can be obtained:…”

Section: Coupling Model Of Fluid and Geomechanicsmentioning

confidence: 99%

“…This model takes into account the stress interference effect between HFs, which leads to the limitation of fracture length opening, but does not consider its nonplanar extension behavior. Ren et al 14 established a multicluster fracture extension model based on the pseudo-three-dimensional model and used the discontinuous displacement method in the boundary element method to solve the coupling problem. The model takes into account the nonuniform extension of each hydrofracture.…”

Section: Introductionmentioning

confidence: 99%

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Study on induced stress of hydraulic fracturing in fractured‐porous elastic media

Wang

Zhao

et al. 2020

Energy Science & Engineering

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The study on induced stress of hydraulic fracturing is an important part of hydraulic fracturing design, temporary plugging and steering fracturing design, and completion design in oil and gas development. Based on fracture continuum method (FCM), cohesive unit method, and finite volume method (FVM), the propagation behavior of multiple hydraulic fractures (HFs) in fractured‐porous media reservoir is simulated from the perspective of fluid and geological stress coupling. The influence of natural fractures (NFs) on stress distribution and stress inversion sensitive factors are studied. NFs in the model are equivalent to physical models controlled by tension and shear bonds. The proposed model can deal with any number of NFs, which greatly improves the computational efficiency of the model. Then PKN analytic solution and Abaqus software results were used to verify the correctness of our model. The results show that the NF will make the reservoir stress show strong heterogeneity after fracturing, and the prominent feature is the regional stress mutation. The sudden change of stress shows the sudden increase or decrease in stress; with the increase in the initial stress difference, the stress inversion becomes more difficult. When the stress difference exceeds 3 MPa, the stress inversion area is almost 0. The stress interference increases with the decrease in cluster spacing. The stress inversion region between HFs decreases, while the external stress inversion region increases; Biot coefficient has great influence on stress and stress inversion. With the decrease in Biot coefficient, stress inversion region will decrease obviously. When the Biot coefficient is 0.4, there is no stress inversion area in the whole reservoir. Poisson's ratio has little influence on stress inversion. When Poisson's ratio changes between 0.1 and 0.3, the change range of stress is within 1 MPa, and the stress inversion area is almost unchanged. Our results can be helpful for understanding the stress distribution after hydraulic fracturing in fractured‐porous media.

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Section: Coupling Model Of Fluid and Geomechanicsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Study on induced stress of hydraulic fracturing in fractured‐porous elastic media

Wang

Zhao

et al. 2020

Energy Science & Engineering

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“…Variations of fracture height, width, and SRV with Q are studied, as shown in Figure 11. When the pump rate increases, the net pressure in hydraulic fractures will increase, resulting in more evident perturbation of formation stress and more fracturing fluid leak-off [55][56][57], and the stimulated reservoir volume will increase. Our statistical results highlight that the injection rate is the most significant factor towards SRV, which is consistent with other researches [34,58,59].…”

Section: Effect Of the Injection Ratementioning

confidence: 99%

Uncertainty Analysis of Factors Influencing Stimulated Fracture Volume in Layered Formation

et al. 2019

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Hydraulic fracture dimension is one of the key parameters affecting stimulated porous media. In actual fracturing, plentiful uncertain parameters increase the difficulty of fracture dimension prediction, resulting in the difficulty in the monitoring of reservoir productivity. In this paper, we established a three-dimensional model to analyze the key factors on the stimulated reservoir volume (SRV), with the response surface method (RSM). Considering the rock properties and fracturing parameters, we established a multivariate quadratic prediction equation. Simulation results show that the interactions of injection rate (Q), Young’s modulus (E) and permeability coefficient (K), and Poisson’s ratio (μ) play a relatively significant role on SRV. The reservoir with a high Young’s modulus typically generates high pressure, leading to longer fractures and larger SRV. SRV reaches the maximum value when E1 and E2 are high. SRV is negatively correlated with K1. Moreover, maintaining a high injection rate in this layered formation with high E1 and E2, relatively low K1, and μ1 at about 0.25 would be beneficial to form a larger SRV. These results offer new perceptions on the optimization of SRV, helping to improve the productivity in hydraulic fracturing.

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“…“Horizontal well + segmented multi‐cluster perforation + large‐displacement hydraulic fracturing” has led to the commercial development of unconventional reservoirs, especially of shale gas . The main and branch fractures formed during fracturing are the tensile fractures of the shale reservoir, whereas the secondary fractures are the shear misalignment fractures,all the fracture surfaces are rough .…”

Section: Introductionmentioning

confidence: 99%

Influence factors of unpropped fracture conductivity of shale

Gou

et al. 2020

Energy Science & Engineering

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Hydraulic fracture is widely performed to enhance oil and gas production in the development of unconventional reservoirs. This paper proposes a numerical model for the calculation of the unpropped fracture conductivity of shale. This numerical model consists of three basic models, namely, the numerical reconstruction model of fracture morphology, fracture deformation model under closed stress, and fluid flow model. The numerical model can be used to analyze the influencing factors of the unpropped fracture conductivity of shale quantitatively. The results demonstratethat the fracture misalignment of shale is a prerequisite for unpropped fractures with conductivity at high closed stress. Furthermore, the unpropped fracture conductivity of shale decreases exponentially with the increase in closed stress. Moreover, closed stress is the factor having the most significant influence on the unpropped fracture conductivity of shale, followed by roughness and fracture morphology. The negative effect of closed stress can be reduced by increasing the fracture morphology during the fracturing operation. K E Y W O R D Sclosed stress, conductivity, fracture morphology, shale, unpropped fracture | 2025 LU et aL.

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Stimulated reservoir volume estimation for shale gas fracturing: Mechanism and modeling approach

Cited by 59 publications

References 20 publications

Study on induced stress of hydraulic fracturing in fractured‐porous elastic media

Study on induced stress of hydraulic fracturing in fractured‐porous elastic media

Uncertainty Analysis of Factors Influencing Stimulated Fracture Volume in Layered Formation

Influence factors of unpropped fracture conductivity of shale

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