深部煤层压裂液渗吸调控煤层气解吸增效机制

姚艳斌; 马如英; 孙晓晓

doi:10.11698/PED.20250319

石油勘探与开发 >

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DOI: https://doi.org/10.11698/PED.20250319

深部煤层压裂液渗吸调控煤层气解吸增效机制

姚艳斌 ,
马如英 ,
孙晓晓

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1.中国地质大学（北京）能源学院,深部探测与成像全国重点实验室,北京 100083;
2.中国地质大学（北京）深时数字地球前沿科学中心,北京 100083

姚艳斌（1978-）,男,河北邯郸人,中国地质大学（北京）能源学院教授,主要从事煤与煤层气地质及勘探开发研究与教学工作。地址：北京市海淀区学院路29号,中国地质大学（北京）能源学院,邮政编码：100083。E-mail：yyb@cugb.edu.cn

收稿日期: 2025-06-03

修回日期: 2025-11-12

网络出版日期: 2025-11-17

基金资助

国家自然科学基金企业创新发展联合基金重点项目“深部煤层流体作用与煤层气富集产出机理”（U24B2018）; 国家自然科学基金杰出青年科学基金项目“煤层气储层地质学”（42125205）

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Mechanism of enhanced coalbed methane desorption regulated by fracturing fluid imbibition in deep coal seams

YAO Yanbin ,
MA Ruying ,
SUN Xiaoxiao

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1. State Key Laboratory of Deep Earth Exploration and Imaging, School of Energy Resources, China University of Geosciences (Beijing), Beijing 100083, China;
2. Frontiers Science Center for Deep-Time Digital Earth, China University of Geosciences (Beijing), Beijing 100083, China

Received date: 2025-06-03

Revised date: 2025-11-12

Online published: 2025-11-17

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摘要

针对传统低矿化度压裂液侵入深部煤层后易导致离子迁移、润湿性改变与气体解吸效率波动等问题,以鄂尔多斯盆地大宁—吉县区块8^#煤为研究对象,通过物理模拟实验揭示矿化度梯度对“离子-煤基质-气/水”三相界面的协同控制机制及其在渗吸-解吸中的关键作用。研究表明：离子浓度升高增强煤层流体疏水性,高价离子效应显著;渗吸与离子扩散路径反向,渗吸平衡先于扩散达成,水-煤反应引发矿物溶解与沉淀双重效应;低矿化度压裂液注入含高矿化度溶液储层时,渗透压差驱动渗吸促进CH₄解吸但滤失率高,高矿化度压裂液注入含低矿化度溶液储层时,渗透压差为阻力,抑制滤失但提高返排效率。据此提出深部煤层“高—低矿化度序贯注入”策略：先注高矿化度流体构建稳定裂缝网络,后注低矿化度流体拓展渗吸区并增强CH₄解吸-扩散。同时建议采取适度焖井的措施增加渗吸体积,实现储层“保压保能”和渗吸置换等多重积极作用。

关键词： 深部煤层气; 低矿化度压裂液; 渗吸; 返排; 润湿性; 渗透压差; 压裂增产

本文引用格式

姚艳斌 , 马如英 , 孙晓晓 . 深部煤层压裂液渗吸调控煤层气解吸增效机制[J]. 石油勘探与开发, 0 : 1 -1 . DOI: 10.11698/PED.20250319

Abstract

Low-salinity fracturing fluids tend to induce ion migration, alter wettability, and cause fluctuations in gas desorption efficiency when penetrating deep coal seams. Taking the No. 8 coal from the Daning-Jixian block in the Ordos Basin as a representative example, this study employs physical simulation experiments to reveal the coupled control mechanism of salinity gradient on the ion-coal matrix-gas/water interfacial system and its key role in the imbibition-desorption process. The results show that increasing ionic concentration enhances the hydrophobicity of coal, with multivalent ions exhibiting particularly significant effects. The imbibition and ion diffusion occur in opposite directions, with imbibition equilibrium being achieved earlier than ionic equilibrium. Water-coal interactions induce both mineral dissolution and secondary precipitation. When a low-salinity fracturing fluid is injected into a high-salinity reservoir, the osmotic-pressure difference drives imbibition, promotes CH₄ desorption, but results in higher fluid loss. Conversely, injecting high-salinity fracturing fluid into a low-salinity reservoir creates a reverse osmotic gradient that suppresses leak-off while improving flowback efficiency. Based on these findings, a high-low salinity sequential injection strategy is proposed for deep coal seams: high-salinity fluid is first injected to form stable fracture networks, followed by low-salinity fluid to enlarge the imbibition zone and enhance CH₄ desorption and diffusion. In addition, moderate well soaking is recommended to increase the imbibition volume, thereby achieving multiple positive effects such as maintaining reservoir pressure, preserving formation energy, and promoting imbibition-driven displacement.

Key words： deep coalbed methane (CBM); low-salinity fracturing fluid; imbibition; flowback; wettability; osmotic pressure difference; production enhancement through hydraulic fracturing

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