Phase-field method of crack branching during SC-CO2 fracturing: A new energy release rate criterion coupling pore pressure gradient

Xu, Wenlong; Yu, Hao; Zhang, Jianing; Lyu, ChengSi; Wang, Quan; Micheal, Marembo; Wu, HengAn

doi:10.1016/j.cma.2022.115366

Cited by 27 publications

(16 citation statements)

References 90 publications

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“…The limit of the singularity of a dynamic Biot system is typically small enough at the engineering reservoir scale to allow for the construction of a quasistatic Biot system. 84 The corresponding mass conservation equations for reservoir and fractured domains are written as The fluid density, storage coefficient, Darcy velocity vector, fluid source term, Biot coefficient, permeability, and fluid viscosity are all defined in the region of type i [i = R or F, the reservoir (R) and fractured domains (F), respectively] as ρ i , S i , v i , q i , α i , k i , μ i ; ε vol is defined as the volumetric strain of Ω R (t); ε vol = ∇u; and g is the gravity vector.…”

Section: Peridynamics and Materials Point Methodmentioning

confidence: 99%

“…Experimental findings published in the literature 87 supported the use of PFM in hydraulic fracturing. The mixed-mode failure and shear strength degradation during supercritical carbon dioxide (SC−CO 2 ) fracturing were fully taken into account by Xu et al 84 Two distinct failure modes (Mode-I and Mode-II) were distinguished by spectral decomposition of strain energy, and the critical energy release rate criterion considering the pore pressure gradient was established. The crack's branching behavior is described for a wide range of fluid viscosity and injection rates, and experimental results are used to validate the model, 88 as shown in Figure 8c.…”

Section: Peridynamics and Materials Point Methodmentioning

confidence: 99%

“…However, PFM simulation has a high computational cost, particularly when a relatively sharp interface is recorded. 23,76,84,85,92 2.3.1.2.2. Damage Method.…”

Section: Peridynamics and Materials Point Methodmentioning

confidence: 99%

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Hydraulic Fracturing and Enhanced Recovery in Shale Reservoirs: Theoretical Analysis to Engineering Applications

et al. 2023

Energy Fuels

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Shale reservoirs are extensively exploited using hydraulic fracturing, which forms multiple cracks that connect with the existing natural fractures to create a continuous path for the gas stored in the kerogen to flow to the production well. Apart from the tedious nature of hydraulic fracturing, the mechanism of the storage and flow of gas is equally complex since multiple phases and scales are involved. An accurate understanding of hydraulic fracturing coupled with a strategy of analyzing the flow and overall recovery of gas is paramount to ensure efficient exploitation. In this work, a comprehensive review of the recent strategies used in analyzing the hydraulic fracturing, storage, flow, and recovery of gas is presented. To begin with, the experimental, analytical, and numerical approaches pertinent to hydraulic fracturing are deeply explored. Additionally, the flow of gas through the newly opened channels is accounted for by using a quadruple-domain approach where the mechanisms of flow in shale reservoirs at the nanoscale, microscale, mesoscale, and macroscale are considered. Furthermore, a strategy to capture the multiple phases, including gas, oil, and water, and recover both carbon dioxide and methane is explored through thermal and enhanced gas recovery approaches. This review provides a baseline for understanding how the hydraulic fracture evolves and propagates to create new channels that contribute to the flow of gas, how the gas flows through the created channels across the many scales of the shale reservoir, and how to improve recovery from shale reservoirs.

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Section: Peridynamics and Materials Point Methodmentioning

confidence: 99%

Section: Peridynamics and Materials Point Methodmentioning

confidence: 99%

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Hydraulic Fracturing and Enhanced Recovery in Shale Reservoirs: Theoretical Analysis to Engineering Applications

et al. 2023

Energy Fuels

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“…As a classical fracture problem, the fluid-driven fracture, which couples the solid deformation and fluid flow, has a wide range of applications in engineering, such as hydraulic fracturing [32][33][34][35][36][37][38][39][40][41][42][43][44][45][46][47] for the exploitation of hydrocarbons like oil, gas and so on, underground CO 2 storage, 48,49 and mining. 50 During the fracture propagation, the fracture process zone is too large compared with the fracture length to be neglected at the crack tip of the quasi-brittle materials.…”

Section: Introductionmentioning

confidence: 99%

Spatial and temporal constraints of the cohesive modeling: A unified criterion for fluid‐driven fracture

Wang

et al. 2023

Numerical Meth Engineering

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We present a unified criterion for cohesive modeling of fluid-driven fracture based on the dimensional analysis to simultaneously provide the constraint for cohesive element and time step sizes. Complicated by the nonlinear interaction between solid deformation and fluid flow, the underlying correlation between discretization and physical parameters of fluid-driven fracture is still unclear. This work studies this correlation through the dimensionless process of the governing equations that associate the cohesive element and time step sizes in a discrete regime. Three characteristic parameters (i.e., related to crack opening, fluid pressure, and fracture length) are introduced in the derivation, and two dimensionless parameters are proposed to construct the unified criterion. The criterion is validated by numerical tests of toughness-dominated fracture with various conditions including the modulus of solid, injection rate of fluid, fracture energy, and in-situ stress. The proposed criterion determines the spatial and temporal constraints of the cohesive zone model for modeling fluid-driven fracture, which is often treated empirically in previous practices.

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“…Zhang et al 27 combined XFEM and the PFM to solve discontinuous and continuous hydraulic fracturing formulations, respectively, for simulating hydraulic fracturing in a shale formation with frictional and cemented NFs. Xu et al 28 developed a modified PFM to describe crack branching behavior with a wide range of fluid viscosities and injection rates. The branching behavior of the crack is quantitatively described by a phase diagram in which tension and shear failure modes alternately dominate it, followed by the periodic fluctuation of the crack tip velocity and equivalent driving term.…”

Section: Introductionmentioning

confidence: 99%

The propagation behavior of hydraulic fracture network in a reservoir with cemented natural fractures

Zhang

Chen

Zhao³

et al. 2023

Energy Science & Engineering

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There are still some problems in the study of hydraulic fracture (HF) network evolution in cemented naturally fractured reservoirs, such as microseismic mapping showing exaggerated stimulated reservoir volume in some cases. In addition, the dominant role of natural fracture (NF) cementation strength, injection rate, in situ stress difference, NF distribution, and fracture initiation sequence of perforations in synthetically influencing fracture network formation needs to be further studied. For this purpose, a three-dimensional matrix hexahedral element global coupled 0-thickness cohesive element hydraulic fracturing model was developed. Results show that each interaction between HF

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Phase-field method of crack branching during SC-CO2 fracturing: A new energy release rate criterion coupling pore pressure gradient

Cited by 27 publications

References 90 publications

Hydraulic Fracturing and Enhanced Recovery in Shale Reservoirs: Theoretical Analysis to Engineering Applications

Hydraulic Fracturing and Enhanced Recovery in Shale Reservoirs: Theoretical Analysis to Engineering Applications

Spatial and temporal constraints of the cohesive modeling: A unified criterion for fluid‐driven fracture

The propagation behavior of hydraulic fracture network in a reservoir with cemented natural fractures

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