Scholarlink

<p>Siliciclastic reservoirs in the central–eastern Sirte Basin exhibit significant lithological and petrophysical heterogeneity, complicating predictions of reservoir quality and hydrocarbon distribution. Many previous studies have evaluated individual formations separately and have not fully addressed the influence of lithological architecture and structural configuration on reservoir performance. This study examines the Cambrian–Ordovician Gargaf and Upper Cretaceous Bahi formations in the RL Field using an integrated structural, lithological, and petrophysical approach to characterize reservoir heterogeneity and identify key controls on reservoir quality. The methodology integrates 3D seismic interpretation with wireline logs and core data from sixteen wells to build lithological and petrophysical models. Formation tops were mapped to analyze thickness variations and fault geometries. Lithology was interpreted from calibrated log responses and classified into quartzite, calcareous sandstone, and shale. Petrophysical properties—porosity, water saturation, and permeability—were derived from logs and core measurements. Reservoir quality was assessed using cutoffs of 8% porosity, 0.6 water saturation, and 1 mD permeability, and property distributions were modeled using Sequential Gaussian Simulation. Results indicate pronounced structural and petrophysical variability across the reservoir interval. The Gargaf Formation reaches a maximum thickness of about 253 ft (77&#xa0;m) and thins to less than 45 ft (13.7&#xa0;m), reflecting structural relief and the presence of a central paleostructural high. In contrast, the Bahi Formation is thin and discontinuous, with a maximum thickness of approximately 12 ft (3.6&#xa0;m). Porosity ranges from &lt; 8% in shale-rich zones to &gt; 20% in sandstone-dominated intervals, while permeability varies from &lt; 0.1 mD to more than 300 mD. The most favorable reservoir zones occur within sandstone-rich intervals over structural highs where porosity exceeds 20% and permeability commonly exceeds 100 mD. The proposed workflow provides a robust framework for evaluating siliciclastic reservoirs and can be applied to similar heterogeneous systems across the Sirte Basin and other North African basins to support effective reservoir management and field development.</p>

错误：搜索内容不能为空，请输入英文关键词
错误：关键词超出字数限制，请精简
高级检索

Lithology-based reservoir modeling of the Cambrian–Ordovician Gargaf and Upper Cretaceous Bahi formations in the central eastern Sirte Basin, Libya: Implications for reservoir quality

  • 期刊论文

  • 发表日期：

    2026年6月3日

查看全文
  • Muneer Abdalla,
  • Salih Mustafa,
  • Belkasem Alkaryani,
  • Kamal Faraj,
  • Firas Mustafa

摘要

Siliciclastic reservoirs in the central–eastern Sirte Basin exhibit significant lithological and petrophysical heterogeneity, complicating predictions of reservoir quality and hydrocarbon distribution. Many previous studies have evaluated individual formations separately and have not fully addressed the influence of lithological architecture and structural configuration on reservoir performance. This study examines the Cambrian–Ordovician Gargaf and Upper Cretaceous Bahi formations in the RL Field using an integrated structural, lithological, and petrophysical approach to characterize reservoir heterogeneity and identify key controls on reservoir quality. The methodology integrates 3D seismic interpretation with wireline logs and core data from sixteen wells to build lithological and petrophysical models. Formation tops were mapped to analyze thickness variations and fault geometries. Lithology was interpreted from calibrated log responses and classified into quartzite, calcareous sandstone, and shale. Petrophysical properties—porosity, water saturation, and permeability—were derived from logs and core measurements. Reservoir quality was assessed using cutoffs of 8% porosity, 0.6 water saturation, and 1 mD permeability, and property distributions were modeled using Sequential Gaussian Simulation. Results indicate pronounced structural and petrophysical variability across the reservoir interval. The Gargaf Formation reaches a maximum thickness of about 253 ft (77 m) and thins to less than 45 ft (13.7 m), reflecting structural relief and the presence of a central paleostructural high. In contrast, the Bahi Formation is thin and discontinuous, with a maximum thickness of approximately 12 ft (3.6 m). Porosity ranges from < 8% in shale-rich zones to > 20% in sandstone-dominated intervals, while permeability varies from < 0.1 mD to more than 300 mD. The most favorable reservoir zones occur within sandstone-rich intervals over structural highs where porosity exceeds 20% and permeability commonly exceeds 100 mD. The proposed workflow provides a robust framework for evaluating siliciclastic reservoirs and can be applied to similar heterogeneous systems across the Sirte Basin and other North African basins to support effective reservoir management and field development.