3D computational modeling of sand erosion in gas-liquid-particle multiphase annular flows in bends

Farokhipour, A.; Mansoori, Z.; Saffar‐Avval, Majid; Ahmadi, Goodarz

doi:10.1016/j.wear.2020.203241

Cited by 24 publications

(3 citation statements)

References 47 publications

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“…For different problems, it is necessary to consider the compressibility of fluid, the requirement of calculation accuracy, the performance of computer equipment, and the time limit to select the most suitable turbulence model. The realizable k-ε [8,17,18] turbulence model is chosen in this paper. The turbulent kinetic energy (k) and its energy dissipation rate (ε) transport equations are calculated as follows:…”

Section: Fluid Flow Field Modelingmentioning

confidence: 99%

Numerical Simulation of Elbow Erosion in Shale Gas Fields under Gas-Solid Two-Phase Flow

Hong

et al. 2021

Energies

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Erosion is one of the most common forms of material failure and equipment damage in gas transmission pipelines. Shale gas fields use hydraulic fracturing whereby solid particles are often carried in the gas flow, and the pipeline is in a high-pressure state, which is more likely to cause erosion. The prediction of particle erosion regulation in gas-solid two-phase flow is an effective means to ensure the safe operation of shale gas fields. In this paper, an integrated CFD-DPM model is established to investigate the erosion of 90° elbow in a shale gas field under gas-solid two-phase flow, employing the realizable k-ε turbulence model, discrete phase model, and erosion rate prediction model. The reliability of the proposed numerical models is verified by comparing the predicted data with the experimental data. Moreover, the effects of six important factors on maximum erosion rate are analyzed, including gas velocity, mass flow rate of sand particles, particle diameter, shape coefficient of sand particles, pipeline diameter, elbow radius of curvature. Specifically, the results indicate that the gas velocity, mass flow rate and shape coefficient of sand particles are positively correlated with the maximum erosion rate, while the pipe diameter and the elbow radius of curvature are negatively correlated with the maximum erosion rate. A new correlation was developed, which included four dimensionless groups, namely Reynolds number, diameter ratio, density ratio and particle number. The correlation can be used to predict maximum corrosion rate of elbows. This work can provide data reference and theoretical basis for mitigating the erosion rate of pipelines and managing the integrity of gas pipelines.

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Section: Fluid Flow Field Modelingmentioning

confidence: 99%

Numerical Simulation of Elbow Erosion in Shale Gas Fields under Gas-Solid Two-Phase Flow

Hong

et al. 2021

Energies

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“…Jing et al [17] held the idea that the corrosion inhibitor droplets would disperse in the pipe and adhere to the inner wall under the effect of gas flow, but the top of pipe is easily absent from the inhibitor film. In addition, Farokhipour et al [18] believed that the volume of fluid (VOF) and Euler-Euler method can be also used to simulate the distribution of corrosion inhibitor in multiphase flow in pipes. To sum up, most of the numerical simulation studies related to corrosion inhibitor distribution are mainly focused on gas pipelines; few studies have been carried out in high water-cut oil wells, and the distribution characteristics of the corrosion inhibitor in oil-water flows in the downhole tubing are still unclear.…”

Section: Introductionmentioning

confidence: 99%

Corrosion Inhibitor Distribution and Injection Cycle Prediction in a High Water-Cut Oil Well: A Numerical Simulation Study

Jing

Sun

et al. 2023

Sustainability

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The wellbore downhole strings corrosion has attracted extensive interest as most of the oilfields in China enter the high water-cut period. Injection of corrosion inhibitors, one of the most effective corrosion protection methods, is employed to mitigate the wellbore corrosion. Nevertheless, its wider application suffers from insufficient knowledge regarding the distribution of corrosion inhibitors inside the tubing, particularly with different inhibitor injection cycles. Thus, in this study, the computational fluid dynamics (CFD) method was first attempted to investigate the hydrodynamics in a tubing and the interactions between the corrosion inhibitor and produced fluid with high water-cut. Key factors including the time, wellbore heights, injection rates, oil phase velocities and corrosion inhibitor viscosities were discussed in detail as regards how they affect the corrosion inhibitor distribution inside the tubing. Feasible formulas were established for predicting the volume fraction of the corrosion inhibitor at different wellbore heights, which showed good agreement with the simulation results. It is noted that the determination of the corrosion inhibitor injection rate depends on both the film quality of the corrosion inhibitor and the stability of the annular flow. Based on the interphase diffusion effect, a new method for determining the intermittent injection cycle of corrosion inhibitor was proposed to maintain the integrity of corrosion inhibitor film at the tubing inner wall.

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“…There are many factors that affect erosion, including fluid properties, particle properties (particle shape, particle size, particle material), particle impact speed and impact angle, etc. [4,8,9]. It is a great challenge to accurately predict the erosion of particles on the pipe wall.…”

Section: Introductionmentioning

confidence: 99%

Numerical Simulation of Gas-Solid Two-Phase Erosion for Elbow and Tee Pipe in Gas Field

Hong

et al. 2021

Energies

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Erosion caused by solid particles in a pipeline is one of the main problems endangering the safety production of the oil and gas industry, which may lead the equipment to malfunction or even fail. However, most of the previous studies focused on the standard elbow, and the erosion law of right-angle elbow and blind tee is rarely reported in the literature. This work aims to investigate the erosion law of different pipeline structures including 90° elbow, right-angle pipe, and tee pipe based on the production characteristics and engineering parameters of the gas field. An integrated CFD-DPM method is established including a realizable k-ε turbulence model, discrete phase model, and erosion rate prediction model. The accuracy of the model is evaluated by a series of experimental data of flow conditions of our previous work. Further, the erosion rate, pressure distributions, and particle trajectories in 90° elbow, right-angle pipe, and tee pipe under different flow velocities, particle mass flow rate, pipe diameter are investigated by applying the presented model. The results show that the blind tee has the most obvious growth rate, and the most serious erosion is located in the blind end of the pipe wall. The maximum erosion rate of the 1.5D is greater than that of the 3D elbow as a whole, and the 1.5D elbow is more concentrated in the serious erosion area. Furthermore, the erosion rate of the bend weld is much greater than that of the straight pipe weld. This study can provide a basis for the selection of different structural pipe fittings, thereby reducing the pipeline erosion rate and improving the integrity of the management of gas pipelines.

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3D computational modeling of sand erosion in gas-liquid-particle multiphase annular flows in bends

Cited by 24 publications

References 47 publications

Numerical Simulation of Elbow Erosion in Shale Gas Fields under Gas-Solid Two-Phase Flow

Numerical Simulation of Elbow Erosion in Shale Gas Fields under Gas-Solid Two-Phase Flow

Corrosion Inhibitor Distribution and Injection Cycle Prediction in a High Water-Cut Oil Well: A Numerical Simulation Study

Numerical Simulation of Gas-Solid Two-Phase Erosion for Elbow and Tee Pipe in Gas Field

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