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Shales Leaching Modelling for Prediction of Flowback Fluid Composition

Author

Listed:
  • Andrzej Rogala

    (Department of Process Engineering and Chemical Technology, Faculty of Chemistry, Gdansk University of Technology, Narutowicza 11/12, 80-233 Gdansk, Poland)

  • Karolina Kucharska

    (Department of Process Engineering and Chemical Technology, Faculty of Chemistry, Gdansk University of Technology, Narutowicza 11/12, 80-233 Gdansk, Poland)

  • Jan Hupka

    (Department of Process Engineering and Chemical Technology, Faculty of Chemistry, Gdansk University of Technology, Narutowicza 11/12, 80-233 Gdansk, Poland)

Abstract

The object of the paper is the prediction of flowback fluid composition at a laboratory scale, for which a new approach is described. The authors define leaching as a flowback fluid generation related to the shale processing. In the first step shale rock was characterized using X-ray fluorescence spectroscopy, X-ray diffractometry and laboratory analysis. It was proven that shale rock samples taken from the selected sections of horizontal well are heterogeneous. Therefore, the need to carry a wide range of investigations for highly diversified samples occurred. A series of leaching tests have been conducted. The extracts were analyzed after leaching to determine Total Organic Carbon and selected elements. For the results analysis significant parameters were chosen, and regression equations describing the influence of rocks and fracturing fluid parameters on the flowback fluid composition were proposed. Obtained models are described by high values of determination coefficients with confidence coefficients above 0.99 and a relatively low standard deviation. It was proven that the proposed approach regarding shale leaching can be properly described using shale models at a laboratory scale, however scaling up requires further investigations.

Suggested Citation

  • Andrzej Rogala & Karolina Kucharska & Jan Hupka, 2019. "Shales Leaching Modelling for Prediction of Flowback Fluid Composition," Energies, MDPI, vol. 12(7), pages 1-21, April.
    • Handle: RePEc:gam:jeners:v:12:y:2019:i:7:p:1404-:d:221949
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    References listed on IDEAS

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    1. Honghua Tao & Liehui Zhang & Qiguo Liu & Qi Deng & Man Luo & Yulong Zhao, 2018. "An Analytical Flow Model for Heterogeneous Multi-Fractured Systems in Shale Gas Reservoirs," Energies, MDPI, vol. 11(12), pages 1-19, December.
    2. Hesham Abdulelah & Syed M. Mahmood & Sameer Al-Hajri & Mohammad Hail Hakimi & Eswaran Padmanabhan, 2018. "Retention of Hydraulic Fracturing Water in Shale: The Influence of Anionic Surfactant," Energies, MDPI, vol. 11(12), pages 1-15, November.
    3. Jian Zhou & Luqing Zhang & Anika Braun & Zhenhua Han, 2017. "Investigation of Processes of Interaction between Hydraulic and Natural Fractures by PFC Modeling Comparing against Laboratory Experiments and Analytical Models," Energies, MDPI, vol. 10(7), pages 1-18, July.
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