Scholarlink

<p>Integrated shale gas play evaluation in the structurally complex Southwestern Tarim Basin Piedmont reveals significant resource potential within the Middle Jurassic Yangye Formation. Comprehensive characterization combining geological surveys, core analysis, and advanced geochemical/petrophysical techniques demonstrates moderate-to-high maturity Type II<sub>1</sub> kerogen source rocks with TOC up to 2.68% (average 1.41%), hydrocarbon generation potentials (S<sub>1</sub>+ S<sub>2</sub>) reaching 4.56&#xa0;mg/g (average 1.77&#xa0;mg/g), and well-developed mesoporous reservoir systems featuring 1.18–1.47% porosity, 0.00048–0.00178 mD permeability, and &gt; 55% brittle minerals. Microstructural observations reveal that primary intergranular and intragranular pores are the dominant storage spaces. Two distinct accumulation models emerge: (1) monocline-retention type associated with structurally preserved hydrocarbon columns in updip positions; (2) syncline core type linked to overpressured basin centers. Resource estimation yields 1029.51 × 10<sup>8</sup>m<sup>3</sup> in-place gas, supporting exploration targeting in northern monocline structures and deep Jurassic intermontane basins where optimal thermal maturity windows coincide with effective preservation conditions.</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

Shale gas potential and accumulation of the Middle Jurassic Yangye Formation in the Southwestern Tarim Basin Piedmont, Northwest China

  • 期刊论文

  • 出版模式：

    开放获取

  • 发表日期：

    2025年7月18日

查看全文
  • Amina Wumaier,
  • Chao Wu,
  • Haichao Ao,
  • Mancang Yang

摘要

Integrated shale gas play evaluation in the structurally complex Southwestern Tarim Basin Piedmont reveals significant resource potential within the Middle Jurassic Yangye Formation. Comprehensive characterization combining geological surveys, core analysis, and advanced geochemical/petrophysical techniques demonstrates moderate-to-high maturity Type II1 kerogen source rocks with TOC up to 2.68% (average 1.41%), hydrocarbon generation potentials (S1+ S2) reaching 4.56 mg/g (average 1.77 mg/g), and well-developed mesoporous reservoir systems featuring 1.18–1.47% porosity, 0.00048–0.00178 mD permeability, and > 55% brittle minerals. Microstructural observations reveal that primary intergranular and intragranular pores are the dominant storage spaces. Two distinct accumulation models emerge: (1) monocline-retention type associated with structurally preserved hydrocarbon columns in updip positions; (2) syncline core type linked to overpressured basin centers. Resource estimation yields 1029.51 × 108m3 in-place gas, supporting exploration targeting in northern monocline structures and deep Jurassic intermontane basins where optimal thermal maturity windows coincide with effective preservation conditions.