CO2深部咸水层封存羽流演变与储盖层完整性影响因素研究——以神华CCS项目为例

doi:10.13809/j.cnki.cn32-1825/te.2024496

Abstract

Abstract:

The plume evolution in long-term CO₂ storage can cause changes in formation pore pressure, which may lead to caprock integrity failure in severe cases, posing leakage risks. Current studies on CO₂ plume evolution and reservoir/caprock integrity mostly rely on single engineering and geological parameters, lacking research on the influencing factors of CO₂ leakage rate, plume evolution, and reservoir/caprock integrity. Taking the Ordos onshore saline aquifer storage project as an example, and combining it with actual engineering and geological parameters, a model for analyzing CO₂ long-term storage plume evolution and formation pressure was established. CO₂ gas saturation, leakage rate, pore pressure, and the Mohr-Coulomb criterion were used to evaluate plume evolution and reservoir/caprock integrity. Sensitivity analysis of injection parameters and reservoir/caprock physical properties was conducted using the control variable method, clarifying the primary factors affecting plume evolution and reservoir/caprock integrity. The results showed that the main influencing factors of plume lateral and vertical migration ranges were injection rate and caprock permeability, respectively. A good caprock with permeability below 0.01×10^-3 μm² could effectively prevent continuous vertical migration of CO₂. Reservoir permeability primarily affected the speed of plume migration, with a relatively high-permeability reservoir of 40×10^-3 μm² allowing the CO₂ plume to reach a steady-state migration range within 15 years. The primary factor influencing CO₂ leakage along the caprock was caprock permeability, with values exceeding 1.25×10^-3 μm² leading to leakage rates exceeding 1% specified by the Intergovernmental Panel on Climate Change (IPCC). When reservoir permeability was below 5×10^-3 μm² or injection rate was above 30×10⁴ t/a, there was a risk of reservoir rock failure. The reservoir/caprock integrity was crucial for ensuring long-term stable operation of geological storage projects. A good reservoir/caprock combination and an appropriate injection scheme could reduce the leakage rate to below 1% and decrease pressure accumulation by approximately 50%. The research findings can provide references for the selection of target formations and the design of injection schemes for geological storage projects in China.

Key words: CO₂ geological storage, pressure accumulation, plume evolution, leakage rate, reservoir/caprock integrity

CLC Number:

TE822

WANG Nenghao,LIAN Wei,LI Jun, et al. Study on plume evolution and influencing factors of reservoir and caprock integrity in CO₂ deep saline aquifer storage: A case study of Shenhua CCS project[J]. Petroleum Reservoir Evaluation and Development, 2026, 16(1): 128-140.

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储盖组合	岩石密度/（kg/m³）	盐度/%	孔隙度/%	渗透率/10^-3 μm²	相对渗透率参数				毛管压力参数
储盖组合	岩石密度/（kg/m³）	盐度/%	孔隙度/%	渗透率/10^-3 μm²	λ	S_lr/%	S_ls/%	S_gr/%	λ	S_lr/%	S_ls/%	p₀/kPa
盖层	2 600	3.2	5	0.01	0.457	30	99.9	5	0.457	15	99.9	3 100.0
储层	2 400	3.2	10	20	0.457	30	99.9	5	0.457	15	99.9	19.6
上下部岩层	2 500	3.2	10	0.10	0.457	30	99.9	5	0.457	15	99.9	3 100.0

Study on plume evolution and influencing factors of reservoir and caprock integrity in CO₂ deep saline aquifer storage: A case study of Shenhua CCS project

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持续注入速率/（10⁴ t/a）	间歇注入周期		盖层渗透率/10^-3 μm²	储层渗透率/10^-3 μm²
持续注入速率/（10⁴ t/a）	注入/d	停注/d	盖层渗透率/10^-3 μm²	储层渗透率/10^-3 μm²
10	7	15	0.01	5
20	7	20	0.10	10
30	7	25	1.00	20
40	5	25	10.00	40

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Study on plume evolution and influencing factors of reservoir and caprock integrity in CO2 deep saline aquifer storage: A case study of Shenhua CCS project

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Study on plume evolution and influencing factors of reservoir and caprock integrity in CO₂ deep saline aquifer storage: A case study of Shenhua CCS project