鄂尔多斯盆地奥陶系盐下深层马二、马三段成藏地质特征及有利勘探方向

陈朝兵; 段晨阳; 严锐锋; 高建荣; 白莹; 张延兵; 徐旺林; 张月巧

doi:10.11781/sysydz2025051049

鄂尔多斯盆地奥陶系盐下深层马二、马三段成藏地质特征及有利勘探方向

doi: 10.11781/sysydz2025051049

陈朝兵^1,2,
段晨阳^1,2, ,,
严锐锋³,
高建荣⁴,
白莹⁴,
张延兵⁵,
徐旺林⁴,
张月巧⁴

1. 西安石油大学地球科学与工程学院, 西安 710065;
2. 陕西省油气成藏地质学重点实验室, 西安 710065;
3. 中国石油长庆油田分公司第三采气厂, 西安 710020;
4. 中国石油勘探开发研究院, 北京 100083;
5. 川庆钻探长庆钻井总公司, 西安 710021

基金项目:

深地国家科技重大专项(2025ZD1010507)、国家科技重大专项(2011ZX05044)和陕西省自然科学基础研究计划(2024JC-YBMS-227)联合资助。

详细信息

作者简介:
陈朝兵(1984—)，男，博士，副教授，从事储层形成机理研究。E-mail:zbchen@xsyu.edu.cn。

通讯作者:
段晨阳(1996—)，男，硕士，从事沉积与储层地质学研究。E-mail:982518419@qq.com。

中图分类号: TE122.3
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出版历程
- 收稿日期: 2024-11-29
- 修回日期: 2025-06-29
- 刊出日期: 2025-09-28

Geological characteristics of accumulation and favorable exploration directions of the second and third members in Ordovician Majiagou Formation of deep subsalt layers, Ordos Basin

1. School of Earth Science and Engineering, Xi'an Shiyou University, Xi'an, Shaanxi 710065, China;
2. Shaanxi Key Laboratory of Petroleum Accumulation Geology, Xi'an, Shaanxi 710065, China;
3. No. 3 Gas Production Plant, Changqing Oilfield Company, PetroChina, Xi'an, Shaanxi 710020, China;
4. Research Institute of Petroleum Exploration and Development, PetroChina, Beijing 100083, China;
5. Changqing Drilling Company, CNPC Chuanqing Drilling Engineering Company Limited, Xi'an, Shaanxi 710021, China

摘要

摘要: 鄂尔多斯盆地奥陶系盐下深层马家沟组马二、马三段的天然气成藏地质条件复杂，有利勘探方向不明确，导致盐下勘探暂未取得较大突破。为明确盐下深层天然气成藏地质特征，寻找新的勘探潜力区，通过钻井、地震、测井及分析测试资料，系统分析盐下深层成藏地质条件，揭示盐下试气效果不佳的地质原因，提出盐下深层天然气勘探的有利方向及成藏模式。结果表明：烃源岩、储层及断裂是影响盐下天然气分布的主要因素。盐下深层马二、马三段具有分区供烃特征，其中盆地东部以下古海相油型气供烃为主，甲烷碳同位素偏轻(-41.6‰)；盆地中部以下古海相油型气和上古煤成气混合供烃为主，甲烷碳同位素值居中(-35.9‰)；中央古隆起东侧可分为盆地西北部和盆地西南部，其中盆地西北部以下古海相油型气和上古煤成气混合供烃为主，甲烷碳同位素值居中(-38.7‰)，而盆地西南部以上古煤成气供烃为主，甲烷碳同位素明显偏重(-32.2‰)。盐下储层类型较多，主要受古地貌、沉积相带控制，具有明显的区带性，优质储层以膏模孔、溶洞、颗粒滩孔等为主；断裂对于盐下天然气的运移和输导作用相对有限，马二、马三段普遍发育的膏盐层，塑性强、易形变，一定程度上阻塞降低了天然气在垂向、横向上的运移输导能力，导致盐下深层天然气丰度整体较低。综合分析提出了中央古隆起东侧侧向供烃、盆地东部自生自储型、盆地中部源储—断裂有效匹配等三个有利勘探方向，并建立了对应的成藏模式。
- 盐下深层 /
- 成藏地质特征 /
- 勘探方向 /
- 奥陶系 /
- 鄂尔多斯盆地
Abstract: The geological conditions for natural gas accumulation in the deep subsalt layers of the second and third members of the Ordovician Majiagou Formation (Ma 2 and Ma 3) in the Ordos Basin are complex, and favorable exploration directions in this area remain unclear. These disadvantages result in a lack of major breakthroughs in subsalt exploration. To clarify the geological characteristics of deep subsalt natural gas accumulation and to identify new exploration potential zones, a systematic analysis of the geological conditions was conducted using drilling, seismic, logging, and analytical testing data. The geological causes for poor gas testing performance in subsalt layers were revealed, and favorable exploration directions and accumulation models for deep subsalt natural gas were proposed. The results indicated that source rocks, reservoirs, and faults were the main factors controlling the distribution of deep subsalt natural gas. The Ma 2 and Ma 3 members in the deep subsalt layers exhibited spatial differences in hydrocarbon supply characteristics. In the eastern part of the basin, the hydrocarbon supply was mainly derived from Lower Paleozoic marine oil-type gas, with a relatively higher carbon isotope value in methane (-41.6‰). In the central part of the basin, the supply was a mixture of Lower Paleozoic marine oil-type gas and Upper Paleozoic coal-derived gas, with moderate amounts of carbon isotope in methane (-35.9‰). On the eastern side of the central paleo-uplift, the basin could be further divided into the northwestern and southwestern parts. In the northwestern part, the hydrocarbon supply was a mixture of Lower Paleozoic oil-type gas and Upper Paleozoic coal-derived gas, with an intermediate carbon isotope value in methane (-38.7‰). In the southwestern part, the supply was primarily from Upper Paleozoic coal-derived gas, with a significantly higher carbon isotope value in methane (-32.2‰). The deep subsalt reservoirs are diverse in types, mainly controlled by paleo-geomorphology and sedimentary facies zones, with evident zoning characteristics. High-quality reservoirs mainly develop gypsum mold pores, caves, and shoal pores. The role of faults in facilitating the migration and conduction of subsalt natural gas is relatively limited. The widely developed gypsum salt layers in Ma 2 and Ma 3 members exhibit strong plasticity and are prone to deformation, which to some extent obstructed and reduced the vertical and lateral migration capacity of natural gas. This resulted in the overall low abundance of deep subsalt natural gas. Based on the comprehensive analysis, three favorable exploration directions were proposed: lateral hydrocarbon supply on the eastern side of the central paleo-uplift, self-generated and self-stored reservoirs in the eastern basin, and effective source, reservoir and fault matching zones in the central basin. Corresponding accumulation models were established.
- deep subsalt layer /
- geological characteristics of accumulation /
- exploration direction /
- Ordovician /
- Ordos Basin

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参考文献(41)

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