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Geochemistry of Liquid Hydrocarbons and Natural Gases Combined with 1D Basin Modeling of the Oligocene Shale Source Rock System in the Offshore Nile Delta, Egypt
ACS Omega ( IF 3.7 ) Pub Date : 2024-02-27 , DOI: 10.1021/acsomega.3c09245 Mohamed M El-Said 1 , Ali M A Abd-Allah 1 , Mohamed H Abdel-Aal 1 , Mohammed Hail Hakimi 2 , Aref A Lashin 3 , Ahmed Abd-El-Naby 1
ACS Omega ( IF 3.7 ) Pub Date : 2024-02-27 , DOI: 10.1021/acsomega.3c09245 Mohamed M El-Said 1 , Ali M A Abd-Allah 1 , Mohamed H Abdel-Aal 1 , Mohammed Hail Hakimi 2 , Aref A Lashin 3 , Ahmed Abd-El-Naby 1
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The current study aims to integrate the geochemical characteristics of the Oligocene shale source rock system, oil, condensate, and natural gas samples in the Oligocene sandstone reservoirs from three exploration wells located in the offshore Nile Delta, East Mediterranean Sea, using organic geochemistry and a 1D basin modeling scheme. The Tineh shales exhibit total organic carbon values ranging between 0.90 and 1.89 wt %, along with hydrogen index values in the range of 54–240 mg hydrocarbon/g rock. The geochemical characterization suggests that the shale intervals of the Oligocene Tineh Formation contain type II–III and type III kerogens and, thereby, could be regarded as promising oil- and gas-prone source rocks with high contributions of gas generation potential. The study also reconstructs the 1D thermal and burial history models, showing that the Oligocene Tineh source rock system is in the main oil and wet gas generation phases from the late Miocene to the present time. The simulated basin models reveal the transformation (TR) of 10–50% kerogen to oil during the late Miocene–early Pliocene period and that the Oligocene Tineh source rock system has larger oil generation and expulsion competency, with a TR value of up to 65% during the early Pliocene–Pleistocene time period. The thermogenic gas was also formed during this time and continued to the present day. This study also investigated the presence of oil and condensate in the Oligocene sandstone reservoir samples and revealed that they were generated from mature source rock, ranging from moderately to highly mature stages. This source rock unit was deposited in fluvial to fluvial-deltaic environments under oxic mixed organic conditions and accumulated during the Tertiary time, as evidenced by the presence of the oleanane biomarker dating indicator. The molecular and isotope compositions of natural gases revealed that most of the natural gases in the Oligocene sandstone reservoir are mainly thermogenic methane gases that were generated from mainly mixed organic matter. The thermogenic methane gases were formed mainly from secondary cracking of oil and gas, with small contributions of primary kerogen cracking. The properties of natural gases together with oil and condensate in the Oligocene reservoir rocks suggest that most of the thermogenic methane gases and associated liquid hydrocarbons are derived primarily from the Oligocene shale source rock system and formed by primary kerogen cracking and secondary oil and oil/gas cracking in different thermal maturity stages. Therefore, the Oligocene Tineh Formation can be regarded as self-source generation and self-reservoir rock; hence, an intensive oil exploration and production program can be recommended whenever the Tineh source rock system is is well developed and deeply buried.
中文翻译：
埃及尼罗河三角洲近海渐新世页岩烃源岩系统液态烃和天然气地球化学与一维盆地模拟相结合
目前的研究旨在利用有机地球化学和方法，整合位于东地中海尼罗河三角洲近海三个探井的渐新统页岩烃源岩系统、石油、凝析油和天然气样品的地球化学特征。一维盆地建模方案。 Tineh 页岩的总有机碳值介于 0.90 至 1.89 wt% 之间，氢指数值介于 54–240 mg 碳氢化合物/g 岩石之间。地球化学特征表明，渐新统Tineh组页岩层段含有II-III型和III型干酪根，因此可以被视为具有良好生油潜力和产气潜力的有前景的油气源岩。研究还重建了一维热史和埋藏史模型，表明渐新世Tineh烃源岩系统处于晚中新世至今主要的石油和湿气生成阶段。模拟盆地模型揭示了中新世晚期—上新世早期10%~50%的干酪根向石油的转化（TR），渐新世Tineh烃源岩系统具有较大的生排油能力，TR值高达65上新世早期至更新世时期的百分比。产热气体也在这段时间内形成并持续至今。这项研究还调查了渐新世砂岩储层样品中石油和凝析油的存在情况，并揭示它们是从成熟的烃源岩中生成的，从中度到高度成熟阶段不等。 该烃源岩单元沉积在含氧混合有机条件下的河流至河流三角洲环境中，并在第三纪期间积累，齐墩果烷生物标记测年指标的存在证明了这一点。天然气的分子和同位素组成表明，渐新世砂岩储层中的大部分天然气主要是由混合有机质产生的热成因甲烷气体。热成因甲烷气体主要由油气二次裂解形成，干酪根初次裂解贡献较小。渐新统储层中天然气、石油和凝析油的性质表明，大部分热成因甲烷气体和伴生液态烃主要来源于渐新统页岩烃源岩系统，由原生干酪根裂解和次生石油和油气形成。不同热成熟阶段的开裂。因此，渐新统Tineh组可视为自生自储岩；因此，只要Tineh烃源岩系统发育良好且埋藏较深，就可以建议实施密集的石油勘探和生产计划。
更新日期：2024-02-27
中文翻译：
埃及尼罗河三角洲近海渐新世页岩烃源岩系统液态烃和天然气地球化学与一维盆地模拟相结合
目前的研究旨在利用有机地球化学和方法，整合位于东地中海尼罗河三角洲近海三个探井的渐新统页岩烃源岩系统、石油、凝析油和天然气样品的地球化学特征。一维盆地建模方案。 Tineh 页岩的总有机碳值介于 0.90 至 1.89 wt% 之间，氢指数值介于 54–240 mg 碳氢化合物/g 岩石之间。地球化学特征表明，渐新统Tineh组页岩层段含有II-III型和III型干酪根，因此可以被视为具有良好生油潜力和产气潜力的有前景的油气源岩。研究还重建了一维热史和埋藏史模型，表明渐新世Tineh烃源岩系统处于晚中新世至今主要的石油和湿气生成阶段。模拟盆地模型揭示了中新世晚期—上新世早期10%~50%的干酪根向石油的转化（TR），渐新世Tineh烃源岩系统具有较大的生排油能力，TR值高达65上新世早期至更新世时期的百分比。产热气体也在这段时间内形成并持续至今。这项研究还调查了渐新世砂岩储层样品中石油和凝析油的存在情况，并揭示它们是从成熟的烃源岩中生成的，从中度到高度成熟阶段不等。 该烃源岩单元沉积在含氧混合有机条件下的河流至河流三角洲环境中，并在第三纪期间积累，齐墩果烷生物标记测年指标的存在证明了这一点。天然气的分子和同位素组成表明，渐新世砂岩储层中的大部分天然气主要是由混合有机质产生的热成因甲烷气体。热成因甲烷气体主要由油气二次裂解形成，干酪根初次裂解贡献较小。渐新统储层中天然气、石油和凝析油的性质表明，大部分热成因甲烷气体和伴生液态烃主要来源于渐新统页岩烃源岩系统，由原生干酪根裂解和次生石油和油气形成。不同热成熟阶段的开裂。因此，渐新统Tineh组可视为自生自储岩；因此，只要Tineh烃源岩系统发育良好且埋藏较深，就可以建议实施密集的石油勘探和生产计划。
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