A review on proppant transport in complex fracture geometries

Wen, Zhicheng; Zhang, Liehui; Tang, Huiying; Zhao, Yulong; Wu, Jianfa; Hu, Haoran

doi:10.1080/10916466.2023.2242396

Cited by 2 publications

(1 citation statement)

References 64 publications

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“…By further investigating the literature in related fields, the solution ideas of wellbore multiphase flow models can be classified into two categories: E–E (Euler–Euler approach) model and E–L (Euler–Lagrange approach) model. 8 The former focuses on an analytical approach to the control volume, with the phases viewed as an interpenetrating continuum; the latter focuses on the center of fluid mass, describing the motion process of each fluid mass point from the beginning to the end, i.e., the change patterns of position with time. The classical E–E models include the concentration model, 9 , 10 the dual-fluid model, 11 , 12 etc.…”

Section: Introductionmentioning

confidence: 99%

Numerical Modeling of Foam Carrying Sand Transport in Multifactor Horizontal Wells

Yu,

Yang,

Cheng

et al. 2024

ACS Omega

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The solution of wellbore multiphase flow models has an important position in oil−gas field development. However, the solution of multiphase flow models often involves a series of complicated situations such as interphase mass and energy transfer, surface problems, and so on. Foam carrying sand particles in the wellbore is a solid, liquid, and gas three-phase cylinder flow problem. To solve this problem, we developed a computational fluid dynamics-discrete element method model based on the traditional N−S equations to track the streamline of the foam fluid and sand particles in the wellbore. On this basis, we investigated the influence of three factors, i.e., foam and sand properties and wellbore parameters, on the sand carrying rate of foam. The results show that whether the sand mound at the bottom of wells that can be dispersed is mainly affected by the properties of foam. The location of sand deposition in the wellbore and the effectiveness of foam in sand transportation are mainly influenced by the wellbore parameters and sand properties.

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Section: Introductionmentioning

confidence: 99%

Numerical Modeling of Foam Carrying Sand Transport in Multifactor Horizontal Wells

Yu,

Yang,

Cheng

et al. 2024

ACS Omega

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Simulation and solution of a proppant migration and sedimentation model for hydraulically fractured inhomogeneously wide fractures

Peiqi,

Lin,

et al. 2024

Energy Exploration & Exploitation

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The distribution of proppant during hydraulic fracturing may directly contribute to the flow conductivity of the proppant fracture, so research on the migration and sedimentation of proppant in the fracture and the final distribution pattern is of great relevance. The mass conservation equations of proppant solids and fracturing fluid were adopted to describe the distribution of proppant migration and sedimentation in the fracture, improving the additional gravity coefficient by utilizing the density difference between proppant and fracturing fluid and the concentration of proppant, together with the proppant sedimentation velocity at different Reynolds numbers in this study. The flow coefficients were obtained by discretizing the system of equations through the finite volume method combined with the harmonic mean method and the upstream weight method. The concentration additional pressure gradient term was computed by using the Superbee format innovatively to improve the solution convergence of the model. Numerical simulations with identical parameters were compared with indoor test results, which fully verified the correctness of the model and the accuracy of the discrete solution based on the finite volume method. The effects of flow rate of fracturing fluid, ratio of injected sand, viscosity of fracturing fluid, grain size of proppant and density of proppant on proppant migration and sedimentation based on three elliptical fracture morphologies: even-wide, top-wide and bottom-narrow as well as top-narrow and bottom-wide were investigated and analyzed through comparing the rate of proppant front movement, the level of sweeping range and the degree of inhomogeneity in the range under different conditions. Findings of this study suggest that: (1) top-wide and bottom-narrow fractures are more preferable for homogenous sanding in the early stage of proppant injection, and top-narrow and bottom-wide fractures are best for sanding in the later stage; (2) the viscosity of fracturing fluid is the most influential factor on proppant migration and sedimentation, which increases in the range of 100 mPa.s to enhance the sweeping range and homogeneity of proppant sanding and therefore achieve a better fracturing effect.

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A review on proppant transport in complex fracture geometries

Cited by 2 publications

References 64 publications

Numerical Modeling of Foam Carrying Sand Transport in Multifactor Horizontal Wells

Numerical Modeling of Foam Carrying Sand Transport in Multifactor Horizontal Wells

Simulation and solution of a proppant migration and sedimentation model for hydraulically fractured inhomogeneously wide fractures

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