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Volume 36 Issue 6
Dec 2025
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Journal of Earth Science  > 2025  >  36(6): 2579-2597.
Mahaman Salifou Issoufou Aboubacar, Heng Zhang, Boukari Issoufou Ousmane, Jie Li, Zhongxian Cai. An Integrated Approach for Improved Permeability and Reservoir Quality Prediction in Multiporosity Systems, Tahe Ordovician Naturally Fractured Vuggy Carbonates. Journal of Earth Science, 2025, 36(6): 2579-2597. doi: 10.1007/s12583-022-1728-8
Citation: Mahaman Salifou Issoufou Aboubacar, Heng Zhang, Boukari Issoufou Ousmane, Jie Li, Zhongxian Cai. An Integrated Approach for Improved Permeability and Reservoir Quality Prediction in Multiporosity Systems, Tahe Ordovician Naturally Fractured Vuggy Carbonates. Journal of Earth Science, 2025, 36(6): 2579-2597. doi: 10.1007/s12583-022-1728-8
shu

An Integrated Approach for Improved Permeability and Reservoir Quality Prediction in Multiporosity Systems, Tahe Ordovician Naturally Fractured Vuggy Carbonates

doi: 10.1007/s12583-022-1728-8
  • 1.

    Faculté des Sciences et Techniques, Département de Géologie, Université Dan Dicko Dankoulodo de Maradi, BP-465 Maradi, Niger

  • 2.

    Hubei Key Laboratory of Oil and Gas Exploration and Development Theory and Technology, China University of Geosciences (Wuhan), Wuhan 430074, China

  • 3.

    Key Laboratory of Tectonics and Petroleum Resources, Ministry of Education, China University of Geosciences (Wuhan), Wuhan 430074, China

  • 4.

    Faculté des Sciences et Techniques, Département de Géologie, Université Abdou Moumouni, BP 10662 Niamey, Niger

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    Abstract

  • Carbonates present complex pore systems that strongly influence the physical properties and their interrelationships. This study proposes a new approach to establish pore-type mixing-based permeability transforms by integrating well-log and core data. We investigate the influence of pore-structure heterogeneity on permeability and velocity through the rock-frame flexibility factors (γ and γµ), derivable using standard sonic and density logs. We derive permeability transforms, with correlation coefficients, R of 0.8 to 0.9, from core measurements and pore-structure variations-dependent physical parameters, namely the porosity exponent (m), Poisson's ratio (σ), velocity deviation log (VDL), and velocity ratio (VR). Through extrapolation using log-data, the m- and VDL-based correlations provide significantly better permeability estimates, with the highest accuracy attained with the m-based correlation, whereas the VR- and σ-based correlations lead to permeability overestimation for high porosities. We plotted log-derived porosity vs. permeability, obtained applying the m-based correlation, to generate consistent porosity-permeability relationships, which account for pore-structure heterogeneity, by sorting the scattering points into distinct groups/trends by considering the variations of pore-structure types and abundance of a specific porosity. For the studied oilfield, three porosity-permeability relationships are identified, with correlation coefficients approaching 0.9, thus validating the approach and supporting its application in petrophysically similar reservoirs.

     

    • Electronic Supplementary Materials: Supplementary Materials: Supplementary materials (ESM A, B, Figures S1–S2, Table S1) are available in the online version of this article at https://doi.org/10.1007/s12583-022-1728-8.
    Conflict of Interest
    The authors declare that they have no conflict of interest.
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    • References(122)
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