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<p>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 (<i>γ</i> and <i>γ</i><sub>μ</sub>), derivable using standard sonic and density logs. We derive permeability transforms, with correlation coefficients, <i>R</i> of 0.8 to 0.9, from core measurements and pore-structure variations-dependent physical parameters, namely the porosity exponent (<i>m</i>), Poisson’s ratio (<i>σ</i>), velocity deviation log (VDL), and velocity ratio (VR). Through extrapolation using log-data, the <i>m</i>- and VDL-based correlations provide significantly better permeability estimates, with the highest accuracy attained with the <i>m</i>-based correlation, whereas the <i>VR</i>- and <i>σ</i>-based correlations lead to permeability overes-timation for high porosities. We plotted log-derived porosity vs. permeability, obtained applying the <i>m</i>-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.</p>

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

  • 期刊论文

  • 发表日期：

    2025年12月10日

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  • Mahaman Salifou Issoufou Aboubacar,
  • Heng Zhang,
  • Boukari Issoufou Ousmane,
  • Jie Li,
  • Zhongxian Cai

摘要

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 overes-timation 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.