低渗透油藏CO2地质封存中的温度与压力分析

刘石; 余华贵; 王建宁; 郭鸿; 颜世龙

doi:10.20174/j.JUSE.2026.03.19

地下空间与工程学报 >

2026 , Vol. 22 >Issue 3: 937 - 947

DOI: https://doi.org/10.20174/j.JUSE.2026.03.19

设计、施工、监测

低渗透油藏CO₂地质封存中的温度与压力分析

刘石 ,
余华贵 ,
王建宁 ,
郭鸿 ,
颜世龙

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1.西安石油大学石油工程学院,西安 710065;
2.西安石油大学新能源学院,西安 710065;
3.西安石油大学油气田智慧能源与碳中和陕西省高校工程研究中心,西安 710065;
4.中国华油集团有限公司银川分公司,银川宁夏回族自治区 718600;
5.陕西省地质调查院水工环地质调查中心,西安 710068

刘石(1999—),男,陕西西安人,硕士生,主要研究方向为二氧化碳封存、地热开发过程中的数值模拟。E-mail:1625081095@qq.com

余华贵(1979—),女,湖北黄冈人,博士,副教授,主要从事地热开发、低渗透油田开发等领域的教学与科研工作。E-mail:yuhuagui@xsyu.edu.cn

收稿日期: 2025-10-10

网络出版日期: 2026-06-23

基金资助

国家科技重大专项基金(2024ZD1004200);国家自然科学基金(U2344226,51974254)

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Temperature and Pressure Analysis of CO₂ Geological Sequestration in Low Permeability Reservoirs

Liu Shi ,
Yu Huagui ,
Wang Jianning ,
Guo Hong ,
Yan Shilong

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1. College of Petroleum Engineering, Xi'an Shiyou University, Xi'an 710065, P. R. China;
2. College of New Energy, Xi'an Shiyou University, Xi'an 710065, P. R. China;
3. Engineering Research Center of Smart Energy and Carbon Neutral in Oil & Gas Field, Universities of Shaanxi Province, Xi'an Shiyou University, Xi'an 710065, P. R. China;
4. China Yinchuan Branch of China Huayou Group Co., Ltd., Yinchuan, Ningxia Hui Autonomous Region 718600, P. R. China;
5. Shaanxi Hygrogeology Engineering Environment Geology Survey Center, Xi'an 710068, P. R. China

Received date: 2025-10-10

Online published: 2026-06-23

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摘要

将CO₂注入地层进行永久封存是实现碳中和目标的关键技术之一,吴起油田38井区是国内首个全流程CCUS示范项目——延长石油CCUS示范项目的核心区块,2014年开始注气。CO₂注入地层后的运移状态以及封存层温度与压力动态研究对碳封存工程的安全评估至关重要。基于吴起油田CCUS示范区的岩心、地质及测试数据,利用TOUGH2/ECO2N软件平台构建三维数值模型,模拟CO₂注入地层后羽流状态以及对地层温度压力系统的影响。结果表明:CO₂倾向于封存层上部迁移,CO₂注入初期,井周温度由59.94 ℃骤降至48.2 ℃(降幅11.74 ℃),压力由12.6 MPa升至峰值15.6 MPa(增幅23.81%);停注后10年,温度逐渐恢复至原始值附近(60.2 ℃),压力回落至12.8 MPa(较初始值高1.59%);初期地层的温压变化较为显著,后期变化减缓,并最终达到一个稳定状态,注入的CO₂流体对地层整体温度和压力的影响相对有限。研究成果量化了低渗透油藏CO₂封存的温压响应阈值,揭示了超临界CO₂运移与地层能量平衡的耦合机制,可为同类储层封存方案设计及监测系统优化提供理论支撑。

关键词： CO₂封存; 数值模拟; 地层温度; 地层压力; 羽流

本文引用格式

刘石 , 余华贵 , 王建宁 , 郭鸿 , 颜世龙 . 低渗透油藏CO₂地质封存中的温度与压力分析[J]. 地下空间与工程学报, 2026 , 22(3) : 937 -947 . DOI: 10.20174/j.JUSE.2026.03.19

Abstract

Injecting CO₂ into underground formations for permanent storage is one of the key technologies for achieving carbon neutrality goals. Wellblock 38 in Wuqi Oilfield is the core area of the first domestic full-process CCUS demonstration project-the Yanchang Petroleum CCUS Demonstration Project, which has been injecting gas since 2014, now for a decade. The study of the migration state of CO₂ after injection into the formation and the dynamic changes in the temperature and pressure of the storage layer are crucial for the safety assessment of carbon storage projects. This study, based on core, geological and test data from the CCUS demonstration area in Wuqi Oilfield, utilized the TOUGH2/ECO2N software platform to construct a three-dimensional numerical model to simulate the plume state of CO₂ after injection into the formation and its impact on the temperature and pressure system of the formation. The results show that: CO₂ tends to migrate to the upper part of the storage layer. In the initial stage of CO₂ injection, the temperature around the well decreased sharply from 59.94 ℃ to 48.2 ℃ (a drop of 11.74 ℃), and the pressure increased from 12.6 MPa to a peak of 15.6 MPa (an increase of 23.81%). However, after 10 years of injection cessation, the temperature gradually returned to near the original value (60.2℃), and the pressure dropped to 12.8MPa (1.59% higher than the initial value). The temperature and pressure changes in the formation were more significant in the initial stage and gradually slowed down, eventually reaching a stable state. The impact of the injected CO₂ fluid on the overall temperature and pressure of the formation was relatively limited. This study quantified the temperature and pressure response thresholds for CO₂ storage in low-permeability oil reservoirs, revealing the coupling mechanism between the migration of supercritical CO₂ and the energy balance of the formation, providing theoretical support for the design of storage schemes and the optimization of monitoring systems in similar reservoirs.

Key words： CO₂ storage; numerical simulation; formation temperature; formation pressure; plume

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