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<p>In petroliferous sedimentary basins, the interplay between CO<sub>2</sub> and hydrocarbons exerts a notable influence on hydrocarbon generation and accumulation. This research focuses on the Huangqiao oil and gas reservoir, which is known for hosting the largest CO<sub>2</sub> reserves in China. U–Pb isotopic dating of calcite veins in fractures, carbon and oxygen isotope analyses, along with rare earth element (REE) analysis were applied to elucidate the chronology and origin of inorganic and organic fluids in the studied area. Petrographic observations revealed the presence of various components of fluid inclusions, including gaseous CO<sub>2</sub>, gaseous CH<sub>4</sub>, CH<sub>4</sub>-CO<sub>2</sub> mixtures, and hydrocarbon fluids. Besides, through Raman quantitative measurements and thermodynamic simulations, the density, composition, pressure, and temperature characteristics of CH<sub>4</sub> and CO<sub>2</sub> bearing fluid inclusions were calculated. Based on the entrapment conditions of fluid inclusions and U–Pb dating results, two stages of hydrocarbon charging were identified: an early-Jurassic stage (approximately 200–185&#xa0;Ma) characterized by mid-maturity oil and CH<sub>4</sub> and an early-Eocene stage (approximately 61–41&#xa0;Ma) marked by high-maturity oil and CH<sub>4</sub>. CO<sub>2</sub> accumulation events were divided into two stages: high-density CO<sub>2</sub> fluid activity during the early Eocene (approximately 59–39&#xa0;Ma) and low-density CO<sub>2</sub> fluid activity during the Tertiary-Quaternary (approximately 23–4&#xa0;Ma). Moreover, deep fluid influx into reservoirs led to hydrothermal alteration, as evidenced by anomalously high homogenization temperatures and vitrinite reflectance. CO<sub>2</sub> has an extraction effect on crude oil, where its late entry primarily results in the removal of lighter components, especially CH<sub>4</sub>. When high-temperature hydrothermal CO<sub>2</sub> fluid enters the oil reservoir, it accelerates the cracking of crude oil and alters the fluid’s composition. This thermal event also speeds up the source rock’s thermal evolution, leading to extraction, pyrolysis, and gas displacement throughout the reservoir’s development process. This study presents a comprehensive approach for quantitatively studying geological fluids in petroliferous basins of this nature.</p>

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Tracking CO2 migration and accumulation in the Subei Basin using geochronology and fluid inclusion quantitative analysis

  • 期刊论文

  • 出版模式：

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  • 发表日期：

    2025年3月4日

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  • Yanlong Hu,
  • Ruyue Wang,
  • Yahao Huang,
  • Jing Luo,
  • Shaojie Li,
  • Zhigang Wen,
  • Xiaowen Guo,
  • Ze Tao,
  • Yukun Liu,
  • Yan Yi

摘要

In petroliferous sedimentary basins, the interplay between CO2 and hydrocarbons exerts a notable influence on hydrocarbon generation and accumulation. This research focuses on the Huangqiao oil and gas reservoir, which is known for hosting the largest CO2 reserves in China. U–Pb isotopic dating of calcite veins in fractures, carbon and oxygen isotope analyses, along with rare earth element (REE) analysis were applied to elucidate the chronology and origin of inorganic and organic fluids in the studied area. Petrographic observations revealed the presence of various components of fluid inclusions, including gaseous CO2, gaseous CH4, CH4-CO2 mixtures, and hydrocarbon fluids. Besides, through Raman quantitative measurements and thermodynamic simulations, the density, composition, pressure, and temperature characteristics of CH4 and CO2 bearing fluid inclusions were calculated. Based on the entrapment conditions of fluid inclusions and U–Pb dating results, two stages of hydrocarbon charging were identified: an early-Jurassic stage (approximately 200–185 Ma) characterized by mid-maturity oil and CH4 and an early-Eocene stage (approximately 61–41 Ma) marked by high-maturity oil and CH4. CO2 accumulation events were divided into two stages: high-density CO2 fluid activity during the early Eocene (approximately 59–39 Ma) and low-density CO2 fluid activity during the Tertiary-Quaternary (approximately 23–4 Ma). Moreover, deep fluid influx into reservoirs led to hydrothermal alteration, as evidenced by anomalously high homogenization temperatures and vitrinite reflectance. CO2 has an extraction effect on crude oil, where its late entry primarily results in the removal of lighter components, especially CH4. When high-temperature hydrothermal CO2 fluid enters the oil reservoir, it accelerates the cracking of crude oil and alters the fluid’s composition. This thermal event also speeds up the source rock’s thermal evolution, leading to extraction, pyrolysis, and gas displacement throughout the reservoir’s development process. This study presents a comprehensive approach for quantitatively studying geological fluids in petroliferous basins of this nature.