A volumetric-smoothed particle hydrodynamics based Eulerian-Lagrangian framework for simulating proppant transport

Tang, Huiying; Wen, Zhicheng; Zhang, Liehui; Zeng, Jiang; He, Xiao; Wu, Jianfa; Zheng, Jinhai

doi:10.1016/j.petrol.2022.111129

Cited by 4 publications

(1 citation statement)

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“…Wang et al (2019) studied the factors affecting the distribution of the proppant in fracture and fracture networks using the CFD-DEM method and analyzed the effects of the fracture width and injection rate on the distribution of the proppant. For the description of particle motion, the Lagrangian method is more reasonable, but for the simulation of proppant transport at the field scale, the Euler method is more computationally efficient (Tang et al, 2023). Sun et al (2023) refined a proppant transport model based on the Euler method and analyzed the effect of fracture width on proppant transport in hydraulic fracturing.…”

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confidence: 99%

Numerical simulation study on the ultimate injection concentration and injection strategy of a proppant in hydraulic fracturing

Wu,

He,

Zeng

et al. 2024

Front. Energy Res.

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The injection volume and the distribution of a proppant inside a fracture have a direct impact on the stimulation effect of fracturing. In this study, a new proppant transport model was established based on the Euler method. In this model, the proppant plugging element allows fluid to pass through. Furthermore, the proppant plugging process was successfully simulated based on this model. The proppant transport and ultimate injection concentration under different injection modes were discussed. The numerical simulation results indicate that compared with the strategy of constant concentration, the strategy of a stepwise increasing concentration can make the proppant distribution in the fracture more uniform. The strategy of injection with a stepwise increasing concentration and a periodic injection with a stepwise increasing concentration can increase the injection volume of the proppant by 25%. In the fracture network, a 67% increase in the number of branch fractures resulted in a 17% increase in the maximum proppant injection volume. If the branch fracture width is reduced by 50%, the maximum proppant injection volume is reduced by 17%.

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confidence: 99%

Numerical simulation study on the ultimate injection concentration and injection strategy of a proppant in hydraulic fracturing

Wu,

He,

Zeng

et al. 2024

Front. Energy Res.

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A critical review of key points in temporary plugging fracturing: Materials, injection, temporary plugging, and design

Chen,

Lu,

Liu

et al. 2024

Geoenergy Science and Engineering

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Pore-Network Simulations of Gas-Water Two Phases Flow in Organic-Rich and Inorganic-Rich Shale

Wang,

Zhou,

Cai

et al. 2023

SPE/IATMI Asia Pacific Oil &Amp; Gas Conference and Exhibition

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Focused ion beam scanning electron microscopy (FIB-SEM) is an effective method to investigate the pore structure and gas flow in shale. Insufficient investigations have been carried out with regard to the distinctions between the inorganic-rich and organic-rich samples in the flow simulation. In this work, we selected an organic-rich sample and an inorganic-rich sample for high-resolution three-dimensional imaging, and the organic pores and inorganic pores were effectively extracted using an improved digital rock processing method. Subsequently, the pore network model (PNM) of the two samples were generated separately. Finally, the pore network simulation method was introduced to calculate the flow capacity of the two samples. Data analysis shows that the inorganic-rich sample have a higher pore radius and throat radius and a larger shape factor, with more irregular pores. While the organic-rich sample have a higher average coordination number and better connectivity. The absolute permeability of the inorganic-rich sample is larger, at 1.46 × 10−7μm2, while that of the organic-rich sample is 1.05 × 10−7μm2. The capillary pressure curve of the inorganic-rich sample is lower than that of the organic-rich sample, exhibiting a lower drainage pressure PT and a longer liquid-invasion segment. Compared to previous pore network flow simulation methods, we set a uniform gas-wet surface with an advanced angle of 100-110° for the organic-rich sample, and an advanced angle of 20-30° for the inorganic-rich sample. Forced water injection was used to simulate the water (fracturing fluid) injection process in the organic-rich sample. Due to the hydrophobicity of the pores, the gas flow capacity during water injection was quite poor, but it was improved during drainage process. In contrast, due to the hydrophilic of the inorganic pores, the inorganic-rich sample exhibited spontaneous water imbibition during the water injection process. However, the inorganic-rich sample demonstrated higher residual gas saturation during the drainage process, which indicates that fracturing fluid flowback in inorganic pores is more difficult. This work emphasizes the importance of studying the real pore structure of inorganic pores in FIB-SEM experiments, which provides fundamental insights for the description of shale gas reservoirs and the simulation of gas-water two phase flow.

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A volumetric-smoothed particle hydrodynamics based Eulerian-Lagrangian framework for simulating proppant transport

Cited by 4 publications

References 44 publications

Numerical simulation study on the ultimate injection concentration and injection strategy of a proppant in hydraulic fracturing

Numerical simulation study on the ultimate injection concentration and injection strategy of a proppant in hydraulic fracturing

A critical review of key points in temporary plugging fracturing: Materials, injection, temporary plugging, and design

Pore-Network Simulations of Gas-Water Two Phases Flow in Organic-Rich and Inorganic-Rich Shale

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