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<p>Buried hill condensate gas reservoirs, critical to global energy exploration, are characterized by complex tectonics and weathering that create multi-scale fracture systems with pronounced dual-media heterogeneity, including permeability variations spanning 2–3 orders of magnitude and an anisotropy coefficient of 3.8. To elucidate the intricate flow mechanisms under such conditions, a novel digital core–microfluidics cross-scale method was developed. High-resolution CT reconstruction enabled the creation of a digital fracture network model for depletion experiments. Real-time CT and microfluidic imaging delineated a three-stage condensate evolution process—nucleation in microfractures, capillary-driven migration, and residual trapping—driven by pore structure and capillary-inertial forces. Findings reveal that porous media elevate dew point pressure to 43&#xa0;MPa through adsorption and condensation effects. Fracture morphology significantly influences saturation: Large fractures exhibit 9.86% saturation at 30&#xa0;MPa, while smaller fractures retain higher saturation (12.22%) in discrete forms. A critical pore threshold of 1.90&#xa0;μm alters condensate volume distribution and reduces capillary resistance. Migration behavior hinges on the fracture-pore synergy coefficient (K), with <i>K</i> &gt; 0.017 facilitating continuous film flow and <i>K</i> &lt; 0.015 resulting in trapping. Optimized pressure drop rates correlate with pore size, while self-organized fracture networks enhance local saturation. These insights advance the understanding of condensate flow dynamics, offering practical guidance for reservoir management and informing future research into complex fracture systems.</p>

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Probing the Phase Change and Fluid Flow in the Complex Fracture Network of Buried Hill Condensate Gas Reservoirs

  • 期刊论文

  • 发表日期：

    2026年3月8日

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  • Yunlong Gao,
  • Congcong Li,
  • Hao Gao,
  • Hai Liu,
  • Liangliang Jiang,
  • Shuoliang Wang

摘要

Buried hill condensate gas reservoirs, critical to global energy exploration, are characterized by complex tectonics and weathering that create multi-scale fracture systems with pronounced dual-media heterogeneity, including permeability variations spanning 2–3 orders of magnitude and an anisotropy coefficient of 3.8. To elucidate the intricate flow mechanisms under such conditions, a novel digital core–microfluidics cross-scale method was developed. High-resolution CT reconstruction enabled the creation of a digital fracture network model for depletion experiments. Real-time CT and microfluidic imaging delineated a three-stage condensate evolution process—nucleation in microfractures, capillary-driven migration, and residual trapping—driven by pore structure and capillary-inertial forces. Findings reveal that porous media elevate dew point pressure to 43 MPa through adsorption and condensation effects. Fracture morphology significantly influences saturation: Large fractures exhibit 9.86% saturation at 30 MPa, while smaller fractures retain higher saturation (12.22%) in discrete forms. A critical pore threshold of 1.90 μm alters condensate volume distribution and reduces capillary resistance. Migration behavior hinges on the fracture-pore synergy coefficient (K), with K > 0.017 facilitating continuous film flow and K < 0.015 resulting in trapping. Optimized pressure drop rates correlate with pore size, while self-organized fracture networks enhance local saturation. These insights advance the understanding of condensate flow dynamics, offering practical guidance for reservoir management and informing future research into complex fracture systems.