Enhancing CO2 Injectivity in High-Salinity and Low-Permeability Aquifers: A Case Study of Jianghan Basin, China
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摘要: 注入性是关系CO2地质储存成功与否的一个关键的技术和经济问题, 评价与提高CO2在中国陆相沉积盆地普遍存在的低渗储层中的注入能力对于碳捕集与封存技术在中国的应用与推广具有重要意义.以江汉盆地江陵凹陷为例, 通过数值模拟的方法开展高盐低渗储层CO2注入能力评估与提高方案研究.结果表明: 预注入淡水和低盐度的微咸水溶液均可不同程度地缓解注入井周围的盐沉淀问题; 预注入CO2饱和溶液或稀盐酸溶液, 可显著提高注入井周围的孔渗值, 提高CO2注入性, 但由于储层本身的低渗性, 迁移距离有限, 短时间内较难实现CO2注入速率的大幅度提高.采取水力压裂措施可显著提高低渗储层中CO2的注入性, 其提升能力取决于压裂裂缝的半长度以及压裂程度.对于单个垂直井, 通过水力压裂对储层加以改造, 并采取多层注入的方式, 在低渗储层中实现数十万吨的年注入量是可能的.Abstract: Injectivity is a crucial technical and economical issue for CO2 geological storage projects due to large volumes of CO2 to be stored. Assessment and enhancement of CO2 injectivity in ubiquitous low-permeability reservoirs in the continental sedimentary basins of China is of great significance to the application and development of carbon capture and storage (CCS) in China. Numerical simulation was carried out to investigate the potential and enhancement of CO2 injectivity in high-salinity and low-permeability aquifers by taking Jiangling depression of Jianghan basin as the study area. The results show that pre-injection of freshwater and low-salinity saline water can effectively mitigate salt precipitation around the CO2 injection well at different levels; pre-injection of CO2-saturation solution and diluted HCl solution can significantly improve the porosity and permeability values and enhance CO2 injectivity. However, it is difficult to achieve a significant increase in CO2 injection rate in a short time due to the limited migration distance resulted from the low-permeability nature. Hydraulic fracturing measures can significantly increase CO2 injectivity and the improved capacity largely depends on fracturing half-length and fracturing degree. Therefore, for a single vertical well, it is possible to achieve the injection of hundreds of thousands of tons of CO2 per year to low-permeability reservoirs by adopting hydraulic fracturing measures and multi-layer injection.
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Key words:
- CO2 injectivity /
- high salinity /
- low-permeability aquifer /
- enhancement measure /
- hydrogeology
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图 1 江汉盆地地理位置、构造单元及柱状图(李国玉和吕鸣岗，2002)
Fig. 1. Location, geological units and stratum histogram of Jianghan basin
图 2 鄂深4井(ES-4)深部砂岩孔渗物性(a)和矿物组成(b)随埋深的变化
Fig. 2. Variation in porosity, permeability, shaliness (a) and mineral composition (b) of sandstone with depth from ES-4 drilling
图 5 2D与3D模型CO2注入速率结果对比
Fig. 5. Comparison of CO2 injection rate(QCO2) based on 2D and 3D model
图 6 预注入10d淡水、1%盐度微咸水和5%盐度咸水后直接注入CO2注入速率随时间的演化
Fig. 6. Time evolution of CO2 injection rate after 10d pre-injection of freshwater, 1% salinity and 5% salinity saline water (no pressure recovery)
图 7 预注入10d淡水、1%盐度和5%盐度咸水压力恢复20d后再注入CO2注入速率随时间的演化
Fig. 7. Time evolution of CO2 injection rate after 10d pre-injection of freshwater, 1% salinity and 5% salinity saline water (after pressure recovery)
图 8 预注入30d CO2饱和溶液(a)和1mol/L盐酸溶液(b)对井孔周围孔隙度和渗透率的改造
Fig. 8. Improvement of porosity and permeability after 30d pre-injection of CO2 saturated solution (a) and 1mol/L HCl solution (b)
图 9 预注入30d CO2饱和溶液(a)和1mol/L盐酸溶液(b)井孔周围石膏和方解石的体积变化
Fig. 9. Volume change of anhydrite and calcite after 30d pre-injection of CO2 saturated solution (a) and 1mol/L HCl solution (b)
图 10 预注入30d CO2饱和溶液和稀盐酸溶液后直接注入CO2注入速率随时间的演化
Fig. 10. Time evolution of CO2 injection rate after 30d pre-injection of CO2-saturated solution and 1mol/L HCl solution (no pressure recovery)
图 11 预注入30d CO2饱和溶液和稀盐酸溶液后恢复压力30d后再注入CO2注入速率随时间的演化
Fig. 11. Time evolution of CO2 injection rate after 30d pre-injection of CO2-saturated solution and 1mol/L HCl solution (after pressure recovery)
图 12 裂缝半长度50m、100m、200m、300m、500m CO2注入速率随时间的演化
Fig. 12. Time evolution of CO2 injection rate under fracture half-length of 50m, 100m, 200m, 300m and 500m
表 1 直接注入、预注入淡水或微咸水、CO2饱和溶液或稀盐酸以及水力压裂具体实施方案
Table 1. Schemes of direct injection, pre-injection of freshwater or brackish water, pre-injection of CO2-saturated solution or diluted HCl solution and hydraulic fracturing
方案代号 方案内容 基础方案：直接注入CO2模型的影响 0-1-a、0-1-b 3D模型不考虑盐沉淀的影响(0-1-a)、考虑盐沉淀的影响(0-1-b) 0-2-a、0-2-b 2D模型不考虑盐沉淀的影响(0-2-a)、考虑盐沉淀的影响(0-2-b) 提升方案1：预注入淡水、微咸水溶液(3D模型) 1-1-a、1-1-b、1-1-c 预注入10d淡水、1%盐度微咸水、5%盐度弱咸水后直接注入CO2 1-2-a、1-2-b、1-2-c 预注入10d淡水、1%盐度微咸水、5%盐度弱咸水后等待压力恢复20d后再注入CO2 提升方案2：预注入CO2饱和溶液、稀盐酸溶液(2D模型) 2-1-a、2-1-b 预注入30d CO2饱和溶液、1mol/L稀盐酸溶液后直接注入CO2 2-2-a、2-2-b 预注入30d CO2饱和溶液、1mol/L稀盐酸溶液后等待压力恢复30d后再注入CO2 提升方案3：水力压裂(3D模型) 3-1-a至3-1-e 压裂长度的影响：X方向压出一条半长度50m、100m、200m、300m、500m的垂直裂缝 3-1-f 压裂数目的影响：X方向和Y方向各压裂出一条半长度为100m的垂直裂缝 3-1-g、3-1-h 压裂程度的影响：以半长度100m裂缝为例，将裂缝渗透率提高至2倍和5倍，考察压裂程度的影响 
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表 2 基础方案中水文地质参数和热力学参数设置
Table 2. Hydrogeological and thermo dynamical properties used in the base-case simulations
岩性 孔隙度(%) 渗透率(10-15 m2) 岩石颗粒密度(g/cm3) 岩石热传导率(W/m℃) 岩石颗粒特焓(J/kg℃) 压缩系数(Pa-1) 盐度(%) 残余水饱和度Slr 残余气饱和度Sgr Van Genuchten参数λ 压强系数(MPa) 砂岩 12 3.81 2.6 2.51 920 4.5E-10 20 0.30 0.05 0.46 0.02
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表 3 模型中原生矿物体积分数以及可能的次生矿物
Table 3. Initial mineral volume fractions and possible secondary mineral phases used in the simulations
原生矿物 化学组成 体积分数 次生矿物 化学组成 体积分数 石英 SiO2 0.70 高岭石 Al2Si2O5(OH) 0 方解石 CaCO3 0.20 钙蒙脱石 Ca0.145Mg0.26Al1.77Si3.97O10(OH)2 0 钠长石 NaAlSi3O8 0.01 钠蒙脱石 Na0.290Mg0.26Al1.77Si3.97O10(OH)2 0 石膏 CaSO4 0.03 铁白云石 CaMg0.3Fe0.7(CO3)2 0 伊利石 K0.6Mg0.25Al1.8(Al0.5Si3.5O10)(OH)2 0.03 片钠铝石 NaAlCO3(OH)2 0 绿泥石 Mg2.5Fe2.5Al2Si3O10(OH)8 0.01 白云石 CaMg(CO3)2 0 赤铁矿 Fe2O3 0.01 菱镁矿 MgCO3 0 钾长石 KAlSi3O8 0.01 菱铁矿 FeCO3 0 黄铁矿 FeS2 0
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表 4 地层水初始溶解组分浓度
Table 4. Initial concentrations of the formation water at reservoir conditions of 90℃ and 2.25×107 Pa
成分 浓度(mol/kg H2O) 成分 浓度(mol/kg H2O) 成分 浓度(mol/kg H2O) pH 6.9 K 3.439×10-2 S 6.273×10-2 Ca 6.350×10-2 Fe 1.477×10-6 Al 1.768×10-8 Mg 4.567×10-4 SiO2(aq) 1.016×10-3 Cl 4.000 Na 4.002 C 7.013×10-3 O2(aq) 1.447×10-5
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