页岩自封闭性与页岩气保存的微观机理研究

郭旭升; 胡东风; 俞凌杰; 卢龙飞; 何陈诚; 刘伟新; 陆现彩

doi:10.11781/sysydz202305821

页岩自封闭性与页岩气保存的微观机理研究

doi: 10.11781/sysydz202305821

郭旭升^{1, 2,},
胡东风³,
俞凌杰^{2, 4},
卢龙飞^{2, 4},
何陈诚^{2, 4},
刘伟新^{2, 4},
陆现彩⁵

1.
中国石化石油勘探开发研究院, 北京 102206
2.
页岩油气富集机理与高效开发全国重点实验室, 北京 102206
3.
中国石化勘探分公司, 成都 610041
4.
中国石化油气成藏重点实验室, 江苏无锡 214126
5.
南京大学地球科学与工程学院, 南京 210046

基金项目:

国家自然科学基金企业创新发展联合基金 U19B6003-03-06

国家自然科学基金企业创新发展联合基金 U19B6003-03-03

详细信息

作者简介:
郭旭升(1965-), 男, 中国工程院院士, 本刊主编, 从事油气勘探研究与生产管理工作。E-mail: guoxs@sinopec.com

中图分类号: TE122.2
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出版历程
- 收稿日期: 2023-07-19
- 修回日期: 2023-09-08
- 刊出日期: 2023-09-28

Study on the micro mechanism of shale self-sealing and shale gas preservation

GUO Xusheng^{1, 2
,},
HU Dongfeng³,
YU Lingjie^{2, 4},
LU Longfei^{2, 4},
HE Chencheng^{2, 4},
LIU Weixin^{2, 4},
LU Xiancai⁵

1.
SINOPEC Petroleum Exploration and Production Research Institute, Beijing 102206, China
2.
State Key Laboratory of Shale Oil and Gas Enrichment Mechanisms and Efficient Development, Beijing 102206, China
3.
SINOPEC Exploration Company, Chengdu, Sichuan 610041, China
4.
SINOPEC Key Laboratory of Petroleum Accumulation Mechanisms, Wuxi, Jiangsu 214126, China
5.
School of Earth Science and Engineering, Nanjing University, Nanjing, Jiangsu 210046, China

摘要

摘要: 为加快页岩气的勘探开发，围绕页岩自封闭性阐述了页岩气保存的微观机理。页岩层系的自封闭能力主要与其纳米喉道为主的低连通性、束缚水赋存引起的低速扩散和毛细管力封闭、埋藏条件下沿层方向的突破压力有关。基于页岩孔隙形态以及连通性分析表明，页岩有机孔以纳米喉道为主，连通性差且具有明显的滞留效应，同时顶、底板及页岩层系内部多套相对致密的封隔层叠置，有利于形成纵向自封闭。结合束缚水对基质孔隙流动能力及突破压力的实验和分子动力学模拟分析，揭示束缚水赋存使得页岩基质孔隙有效扩散能力显著下降，并可形成高的毛细管力，从而对储集于有机孔隙中的气体形成有效封闭。研究中构建了渗透率—突破压力演化关系，揭示深埋条件下页岩沿层方向层理缝有效闭合可形成高的突破压力封闭，抬升阶段相对弱的挤压环境沿层方向仍可以保持较高的封闭能力，有利于页岩气保存；而强挤压改造导致层理缝开启并沟通开启性断裂面，导致保存能力失效并使得页岩气发生较大规模的散失。该研究利用实验和分子动力学模拟等手段获取的认识，进一步阐述了页岩气保存的微观机理，可为复杂构造区海相页岩气勘探提供指导。
- 自封闭能力 /
- 润湿性 /
- 毛细管力封闭 /
- 突破压力 /
- 页岩气保存
Abstract: In order to accelerate the exploration and development of shale gas, this paper elaborates on the micro mechanism of shale gas preservation based on shale self-sealing. The self-sealing capacity of shale formations is mainly related to the low connectivity of nano-throats, low speed diffusion caused by bound water occurrence, capillary force sealing, and breakthrough pressure along the layer direction under burial conditions. Results of analysis based on shale pore morphology and connectivity show that the organic pores in shale are mainly composed of nano-throats with poor connectivity and significant retention effects. At the same time, the stacking of multiple relatively dense sealing layers within the top, bottom, and shale layers is conducive to self-sealing in longitudinal direction. Based on experimental and molecular dynamics simulation analysis of the influence of bound water on the diffusion and breakthrough pressure of the shale matrix, it is revealed that the bound water occurrence significantly reduces the effective diffusion capacity of shale matrix pores and could cause high capillary forces, leading to effective sealing of the gas stored in organic pores. In the study, the permeability-breakthrough pressure evolution relationship was constructed, revealing that under deep burial conditions, the effective closure of shale bedding fractures along the layer direction can form high breakthrough pressure sealing. During the uplift stage, under relatively weak tectonic compression, the shale could still maintain a high sealing capacity along the layer direction, which is conducive to shale gas preservation. However, under strong tectonic compression, the shale bedding fractures open and communicate with open fault surface, causing the failure of preservation capacity and large-scale loss of shale gas. This study elucidates the microscopic mechanism of shale gas preservation through experiments and molecular dynamics simulations, which could provide useful guidance for marine shale gas exploration in complex structural areas.
- self-sealing capacity /
- wettability /
- capillary force sealing /
- breakthrough pressure /
- shale gas preservation
注释:

利益冲突声明/Conflict of Interests

所有作者声明不存在利益冲突。

All authors disclose no relevant conflict of interests.

作者贡献/Authors’Contributions

郭旭升提出论文总体构思；胡东风指导机理讨论及应用；俞凌杰负责物性实验及论文的统稿与修改；卢龙飞负责润湿性分析及相关的内容编写；何陈诚负责页岩微观结构分析；刘伟新负责页岩顶底板及封存箱分析；陆现彩负责纳米喉道突破压力的模拟及分析。所有作者均阅读并同意最终稿件的提交。

GUO Xusheng proposed the overall concept of the paper. HU Dongfeng guided the discussion and application of the mechanism. YU Lingjie was responsible for conducting physical experiments and organizing the writing and revising of the paper. LU Longfei was responsible for wettability analysis and related content writing. HE Chencheng was responsible for analyzing the micro-structure of shale. LIU Weixin was responsible for the analysis of shale roof, floor and storage box. LU Xiancai was responsible for simulating and analyzing the breakthrough pressure of nano throats. All the authors have read the last version of paper and consented for submission.

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图 1 川东南地区志留系龙马溪组页岩氮气吸附—脱附曲线

Figure 1. Nitrogen adsorption and desorption curves of shale in Silurian Longmaxi Formation, southeastern Sichuan Basin

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图 2 川东南地区志留系龙马溪组页岩扫描电镜照片

a.椭圆状次生有机质孔隙，丁页4井；b.团簇状次生有机质孔隙，东页深3井；c.不规则状微—介孔有机质孔隙大量发育，普顺1井；d. 狭缝形有机质—黏土矿物孔。

Figure 2. SEM photos of shale in Silurian Longmaxi Formation, southeastern Sichuan Basin

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图 3 川东南地区志留系龙马溪组页岩氮气吸附孔径分布

Figure 3. Pore size distribution of shale in Silurian Longmaxi Formation, southeastern Sichuan Basin

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图 4 川东南D1井奥陶系五峰组—志留系龙马溪组页岩气测井曲线与异常压力封存箱

据参考文献[34]修改。

Figure 4. Logs and abnormally pressured compartments of shale gas in Ordovician Wufeng-Silurian Longmaxi formations of well D1, southeastern Sichuan Basin

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图 5 不同湿度含水条件对四川盆地志留系龙马溪组页岩扩散参数的影响

Figure 5. Influence of humidity and water content conditions on diffusion parameters of shale in Silurian Longmaxi Formation, Sichuan Basin

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图 6 基于分子动力学模拟获取的两种孔喉模型对应的突破压力曲线

Figure 6. Breakthrough pressure curves corresponding to two pore throat models obtained by molecular dynamics simulation

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图 7 川东南地区FB1井页岩接触角纵向分布

Figure 7. Longitudinal distribution of shale contact angles of well FB1, southeastern Sichuan Basin

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图 8 TEM表征川东南地区FB1井志留系龙马溪组页岩有机质石墨化程度

Figure 8. TEM characterization of graphitization degree of organic matter in shale in Silurian Longmaxi Formation of well FB1, southeastern Sichuan Basin

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图 9 四川盆地志留系龙马溪组页岩渗透率—突破压力关系曲线

Figure 9. Permeability-breakthrough pressure relationship curves of shale in Silurian Longmaxi Formation of Sichuan Basin

下载: 全尺寸图片幻灯片

图 10 不同水平挤压应力条件下四川盆地志留系龙马溪组页岩沿层方向突破压力演化特征

Figure 10. Changes of breakthrough pressure of shale in Silurian Longmaxi Formation of Sichuan Basin under different horizontal tectonic compression

下载: 全尺寸图片幻灯片

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