考虑层状非均质性对CO2在海域咸水层中迁移过程及封存量的影响

乔翔宇; 王全荣

doi:10.19509/j.cnki.dzkq.tb20240365

考虑层状非均质性对CO₂在海域咸水层中迁移过程及封存量的影响

doi: 10.19509/j.cnki.dzkq.tb20240365

乔翔宇,
王全荣^,

中国地质大学（武汉）环境学院，武汉 430074

基金项目: 国家自然科学基金优秀青年基金项目（42222704）；中国海油有限公司综合科研项目“莺琼盆地CO₂与地热能综合利用关键技术研究”；海南省院士创新平台科研项目“莺−琼盆地CO₂地质封存关键技术研究”

详细信息

作者简介:
乔翔宇：E-mail：qiaoxy@cug.edu.cn

通讯作者:
E-mail：wangqr@cug.edu.cn

中图分类号: P642.5
计量
- 文章访问数: 45
- PDF下载量: 2
- 被引次数: 0
出版历程
- 收稿日期: 2024-06-30
- 录用日期: 2024-09-19
- 修回日期: 2024-09-18
- 网络出版日期: 2025-06-27

Considering the effect of layered heterogeneity on CO₂ migration processes and sequestration in marine saline aquifers

QIAO Xiangyu,
WANG Quanrong^,

School of Environmental Studies, China University of Geosciences(Wuhan), Wuhan 430074, China

More Information

Author Bio:
E-mail：qiaoxy@cug.edu.cn

Corresponding author: E-mail：wangqr@cug.edu.cn

摘要

摘要:
数值模拟是研究咸水层中CO₂迁移机理及地质封存量的主要手段。然而，前人研究往往假设储层是规则且均质的长方体，并且关于CO₂在海域咸水层中迁移过程的数值模拟研究鲜见报道。依托南海某储集体，考虑地层的非均质性与岩性圈闭的实际位置，利用地震反射特征和钻孔资料建立了非均质地质模型，采用TOUGHREACT软件模拟了不同注入位置对CO₂在地层中迁移和封存的影响。结果表明：CO₂向上迁移过程受到泥岩的阻挡，横向迁移更加显著。对于不同的注入方案，储层压力分布存在显著差异。在储层顶部注入时储层压力可达到40.1 MPa；在储层底部注入时，储层压力最高可达到39.7 MPa；当完整井注入时，储层的压力最高可达到40.3 MPa。因此完整井注入和顶部注入方案长期实行导致的压力积聚可能破坏储盖层结构， CO₂泄露的风险更大，在储层底部和中部注入的方案更加安全。当持续注入100 a时，CO₂以超临界相为主，占总封存量的77%以上。在相同的井口注入压力下，均质模型会高估储集体的封存量，非均质模型中在储层顶部注入和中部注入比底部注入分别多55.1%和49.3%。敏感性分析结果表明孔隙度和渗透率对结果的影响比毛管压力显著。研究查明了考虑储层的层状非均质性时注入井位置对CO₂迁移机理和封存量的影响，可以为CO₂封存的布井设计提供理论依据。
- CO₂地质封存 /
- 非均质模型 /
- 数值模拟 /
- 注入位置 /
- 海域咸水层 /
- 迁移过程 /
- 封存量
Abstract: Numerical modeling is a primary tool for studying the migration mechanisms and sequestration of CO2 in saline aquifers. However, previous studies often assume that reservoirs are regular rectangular shapes and homogeneous, with few reports on numerical simulations of CO2 migration in marine saline aquifers. </sec><sec><title>Objective & Methods
This study focuses on a reservoir in the South China Sea, taking into account the heterogeneity of the formation and the actual location of the lithological traps. The study establishes a heterogeneous geological model based on seismic reflection characteristics and drilling data, using TOUGHREACT to simulate the effects of different injection locations on CO₂ migration and sequestration in the formation.
Results
The results indicate that the upward migration of CO₂ is hindered by mudstone, while lateral migration is more pronounced. For different injection scenarios, significant variations in reservoir pressure distribution were observed. The reservoir pressure reaches 40.1 MPa when injecting at the top, 39.7 MPa at the bottom, and 40.3 MPa when injecting in a complete well. Therefore, the pressure buildup from long-term implementation of complete well injection and top injection schemes may damage the reservoir cap rock, increasing the risk of CO₂ leakage. The bottom and middle injection schemes are safer. When injected continuously for 100 years, CO₂ is predominantly in the supercritical phase, accounting for more than 77% of the total sequestration, with the dissolved phase making up less than 23%. At the same wellhead injection pressure, the homogeneous model overestimates the storage volume of the reservoir. The heterogeneous model injects 55.1% and 49.3% more CO₂ at the top and middle, respectively, compared to the bottom. Sensitivity analysis results show that porosity and permeability have a more significant impact on the results than capillary pressure.
Conclusion
This study aims to investigate the impact of injection well locations on CO₂ migration mechanisms and storage capacity when considering the layered heterogeneity of the reservoir, with the aim of providing theoretical guidance for the design of well placement for CO₂ storage.
- CO₂ geological storage /
- heterogeneous model /
- numerical simulation /
- injection location /
- marine saline aquifer /
- migration process /
- sequestration

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图 1 储集体模型示意图及注入井位置（注入井1为薄处注入位置，注入井2为厚处注入位置）

Figure 1. Schematic diagram of the reservoir group model and injection well locations

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图 2 不同注入位置100 a储层气体饱和度分布

Figure 2. Distribution of gas saturation in reservoirs for different injection locations at 100th year

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图 3 不同注入深度100 a储层气体饱和度分布

Figure 3. Distribution of gas saturation in reservoirs for different injection depths at 100th year

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图 4 非均质模型不同注入方案储层压力分布

Figure 4. Distribution of reservoirs pressure for different injection options of heterogeneous model

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图 5 敏感性分析结果

Figure 5. Sensitivity analysis results

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表 1 模型中初始水化学离子浓度

Table 1. Initial water chemical ion concentrations in the model

指标	质量浓度/(mg·L⁻¹)	指标	质量浓度/(mg·L⁻¹)
矿化度	29509.89	Mn²⁺	0.54
HCO₃^-	589.00	Sr²⁺	21.88
Cl^-	17843.32	Zn²⁺	0.26
SO₄^2-	24.00	Li⁺	0.34
Ca²⁺	361.10	Br^-	0.17
K⁺	78.90	As³⁺	1.30
Mg²⁺	83.57	I^-	0.26
Na⁺	10530.00	Fe³⁺	0.18
Ba²⁺	1.61	溶解氧	0.83

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表 2 水文地质学及热力学参数

Table 2. List of hydrogeological and thermodynamic parameters

参数	砂岩	泥岩
水平渗透率/10⁻³ μm²	2.3～7	0.01
垂向渗透率/10⁻³ μm²	0.23～0.70	0.001
孔隙度	0.19～0.21	0.15
岩层热传导率/（W·m⁻¹·K⁻¹）	2.51
岩石颗粒特殊焓/（J·kg⁻¹·K⁻¹）	920.0
岩石密度/（kg·m⁻³）	2600
温度/℃	75.0
压力/MPa	25～26.7

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表 3 模型100 a封存量

Table 3. Model 100-year sequestration 10⁴ t

方案	均质模型	非均质模型
顶部注入	415.28	386.00
中部注入	402.35	371.71
底部注入	387.35	248.89
厚层注入	407.38	398.57
薄处注入	409.09	401.50

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