Coupled Thermal-Hydraulic-Mechanism Simulation during Geological CO2 Storage in Heterogeneous Saline Aquifers
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摘要: 深入理解储层非均质性及多场耦合效应对于准确评估封存过程中CO2运移、转化及封存机制具有重要意义.本文综合考虑了气-水两相流动机制、储层孔渗结构的动态演化及非等温条件下温度对CO2物性的影响，构建了热-水-气-力耦合模型，旨在探讨非均质咸水层中CO2的迁移动态与封存效率.模拟结果表明，储层非均质性对平均孔隙压力的积聚具有显著影响，低孔隙度地层中孔隙压力增幅约为1.96 MPa，而较高孔隙度地层中仅约为1.64 MPa，进而影响了CO2的物性参数与运移路径.同时，热锋的最大迁移距离仅约为161 m，而CO2羽流的最大横向迁移距离可达1 782 m.在CO2注入过程中，储层渗透率和孔隙度分别以1.01~1.13的比率和2.10%~12.8%的幅度变化，且低渗储层的孔渗结构对压力扰动更为敏感.在低渗非均质储层中，CO2最大封存效率系数约为0.88，显著高于高渗储层，证明了在此类地层中保持低于岩石破裂压力的注气速率有助于提升CO2的有效封存能力与长期稳定性.Abstract: A deep understanding of reservoir heterogeneity and multi-field coupling effects is important for assessing CO2 flow and migration behavior during geological CO2 storage. This study comprehensively considers the two-phase flow mechanism, the dynamic evolution of reservoir porosity and permeability structures, and the influence of temperature on the physical properties of CO2 under non-isothermal conditions. A thermal-hydraulic-gas-mechanical (THGM) coupled model is developed to investigate CO2 migration behavior and storage efficiency behavior in heterogeneous saline aquifers. Simulation results indicate that reservoir heterogeneity significantly influences average pressure build-up within the reservoir. In low-porosity reservoirs, the increase in pore pressure is approximately 1.96 MPa, whereas in higher-porosity reservoirs, it is only approximately 1.64 MPa, thereby affecting the physical properties and migration pathways of injected CO2. Additionally, the maximum migration distance of the thermal front is only approximately 161 m, while the maximum lateral migration distance of the CO2 plume can reach approximately 1 782 m. The permeability and porosity within the reservoir vary at a ratio of approximately 1.01-1.13 and an amplitude of 2.10%-12.8% during CO2 injection, respectively. The porosity and permeability of low-permeability reservoirs is more sensitive to pressure disturbances. The maximum CO2 storage efficiency factor reached approximately 0.88 in low-permeability heterogeneous reservoirs, significantly higher than those in high-permeability reservoirs, demonstrating that maintaining an injection rate below the rock fracture pressure in such formations helps enhance the effective storage capacity and long-term stability of CO2.
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图 1 CO2深部咸水层封存概念模型示意
Fig. 1. Schematic diagram of the conceptual model for CO2 storage in deep saline aquifers
图 2 本研究所提出数值模型与Buckley and Leverett (1942)解析模型的含气饱和度曲线对比
Fig. 2. Comparison of the gas saturation curves of the numerical model proposed in this study with the analytical model of Buckley and Leverett (1942)
图 3 具有不同孔渗分布特征的非均质咸水层
a.孔隙度分布特征；b. 渗透率分布特征；y轴放大5倍
Fig. 3. Heterogeneous saline aquifers with different cases of porosity and permeability distributions
图 4 不同非均质条件下1 500 d时超临界CO2饱和度的分布
y轴放大5倍
Fig. 4. Gas saturation distribution of CO2 at 1 500 days for different heterogeneous conditions
图 5 不同非均质条件下储层平均压力和沿顶部边界CO2饱和度的变化
a. 低渗情况；b.高渗情况
Fig. 5. Variations in the average pressure and CO2 saturation along the top boundary for different heterogeneous conditions
图 6 不同非均质条件下热锋的空间变化
y轴放大5倍
Fig. 6. Spatial variation in the thermal front for different heterogeneous conditions
图 7 1 500 d时储层孔隙度的空间变化
y轴放大5倍
Fig. 7. Spatial variation of porosity of the reservoir at 1 500 days
图 8 1 500 d时储层渗透率的空间变化
y轴放大5倍
Fig. 8. Spatial variation of permeability of the reservoir at 1 500 days
图 9 不同非均质条件下咸水层封存效率系数($ \epsilon $)的时间变化
Fig. 9. Temporal variation in the storage efficiency coefficient ($ \epsilon $) of the saline aquifer for different het- erogeneous conditions
表 1 本研究中数值模型使用的参数
Table 1. Parameters used in the numerical model in this study
参数 取值 参数 取值 注入速率($ {M}_{inj} $) 0.02 kg/m/s 水相粘度($ {\mu }_{w} $) 0.001 Pa·s 残余水饱和度($ {s}_{wr} $) 0.1 水相热导率($ {\lambda }_{w} $) 0.59 W/(m·K) 残余气饱和度($ {s}_{gr} $) 0.05 固相密度($ {\rho }_{r} $) 2 600 kg/m3 储层长度(L) 5 000 m 固相比热容($ {C}_{pr} $) 874 J/(kg·K) 储层厚度(H) 100 m 固相热导率($ {\lambda }_{r} $) 1.5 W/(m·K) 储层上边界温度($ {T}_{0} $) 313.15 K 孔隙大小分布指数($ \lambda $) 2 储层上边界压力($ {p}_{0} $) 10 MPa 储层孔隙压缩系数($ {c}_{\varphi } $) 1×10-8 Pa-1 水相密度($ {\rho }_{w} $) 1 000 kg/m3 储层渗透率压缩系数($ {c}_{k} $) 1×10-8 Pa-1 水相比热容($ {C}_{pw} $) 4 200 J/(kg·K) 注入温度($ {T}_{inj} $) 288.15 K 注：参数来源： Pavan et al.（2024） ；魏子俊和高科（2025）；Wei et al.（2025 ）.
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表 2 本研究构建的3种非均质场景及参数范围
Table 2. Four heterogeneous scenarios and parameter ranges constructed in this study
案例 平均孔隙度 渗透率范围(mD) 平均渗透率(mD) L(a) 0.25 2.32~79.4 26.40 L(b) 0.30 6.16~102 36.80 H(a) 0.25 1.12~534 92.70 H(b) 0.30 6.64~788 160.0
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