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Optimization and Extended Applicability of Simplified Slug Flow Model for Liquid-Gas Flow in Horizontal and Near Horizontal Pipes

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  • Tea-Woo Kim

    (Resources Engineering Plant Research Department, Korea Institute of Geoscience and Mineral Resources, 905, Yeongilman-daero, Buk-gu, Pohang-si, Gyeongsangbuk-do 37559, Korea)

  • Nam-Sub Woo

    (Resources Engineering Plant Research Department, Korea Institute of Geoscience and Mineral Resources, 905, Yeongilman-daero, Buk-gu, Pohang-si, Gyeongsangbuk-do 37559, Korea)

  • Sang-Mok Han

    (Resources Engineering Plant Research Department, Korea Institute of Geoscience and Mineral Resources, 905, Yeongilman-daero, Buk-gu, Pohang-si, Gyeongsangbuk-do 37559, Korea)

  • Young-Ju Kim

    (Resources Engineering Plant Research Department, Korea Institute of Geoscience and Mineral Resources, 905, Yeongilman-daero, Buk-gu, Pohang-si, Gyeongsangbuk-do 37559, Korea)

Abstract

The accurate prediction of pressure loss for two-phase slug flow in pipes with a simple and powerful methodology has been desired. The calculation of pressure loss has generally been performed by complicated mechanistic models, most of which require the iteration of many variables. The objective of this study is to optimize the previously proposed simplified slug flow model for horizontal pipes, extending the applicability to turbulent flow conditions, i.e., high mixture Reynolds number and near horizontal pipes. The velocity field previously measured by particle image velocimetry further supports the suggested slug flow model which neglects the pressure loss in the liquid film region. A suitable prediction of slug characteristics such as slug liquid holdup and translational velocity (or flow coefficient) is required to advance the accuracy of calculated pressure loss. Therefore, the proper correlations of slug liquid holdup, flow coefficient, and friction factor are identified and utilized to calculate the pressure gradient for horizontal and near horizontal pipes. The optimized model presents a fair agreement with 2191 existing experimental data (0.001 ≤ μ L ≤ 0.995 Pa∙s, 7 ≤ Re M ≤ 227,007 and −9 ≤ θ ≤ 9), showing −3% and 0.991 as values of the average relative error and the coefficient of determination, respectively.

Suggested Citation

  • Tea-Woo Kim & Nam-Sub Woo & Sang-Mok Han & Young-Ju Kim, 2020. "Optimization and Extended Applicability of Simplified Slug Flow Model for Liquid-Gas Flow in Horizontal and Near Horizontal Pipes," Energies, MDPI, vol. 13(4), pages 1-27, February.
  • Handle: RePEc:gam:jeners:v:13:y:2020:i:4:p:842-:d:320810
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    References listed on IDEAS

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    1. Jinho Choi & Eduardo Pereyra & Cem Sarica & Changhyup Park & Joe M. Kang, 2012. "An Efficient Drift-Flux Closure Relationship to Estimate Liquid Holdups of Gas-Liquid Two-Phase Flow in Pipes," Energies, MDPI, vol. 5(12), pages 1-13, December.
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    Cited by:

    1. Kim, Sungil & Kim, Tea-Woo & Hong, Yongjun & Kim, Juhyun & Jeong, Hoonyoung, 2024. "Enhancing pressure gradient prediction in multi-phase flow through diverse well geometries of North American shale gas fields using deep learning," Energy, Elsevier, vol. 290(C).

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