Density-Driven CO2 Dissolution in Depleted Gas Reservoirs with Bottom Aquifers
Abstract
:1. Introduction
2. Materials and Methods
2.1. Conservation Equations
2.2. Thermodynamic Model
2.3. Numerical Model and Characteristic Parameters
3. Results
3.1. Effect of the Capillary Transition Zone
3.1.1. CO2 Dissolution Rate
3.1.2. Sherwood Number
3.2. Effect of Residual Natural Gas Concentration
3.2.1. CO2 Dissolution Rate
3.2.2. Sherwood Number
3.2.3. Density Difference and Saturation Profile
3.2.4. Onset Time and Decay Time
3.3. Field-Scale Simulation for CO2 Injection and Storage
3.3.1. CO2 Injection Period
3.3.2. CO2 Post-Injection Period
4. Conclusions
- [1]
- The stagnant capillary zone significantly disrupts the concentration boundary layer, enhancing solubility trapping. This is evidenced by higher Sherwood numbers and maximum values in two-phase simulations compared to single-phase ones, indicating stronger convection due to the capillary zone;
- [2]
- The increased residual natural gas concentration lowers the CO2 partial pressure and solubility, reducing the density contrast between ambient and CO2-enriched brine and weakening convective mass transport. In addition, changes in gas composition alter the saturation profile in the capillary zone, further reducing the intensity of perturbations. These combined effects significantly hinder mass transport, leading to lower dissolution rates and Sherwood numbers;
- [3]
- The onset and decay times of mass transfer processes have an exponential relationship with residual natural gas concentration, highlighting the increasing impact of gas mixtures with higher residual gas levels;
- [4]
- The effective cumulative gas production increased by 16.71 × 106 m3, marking an 18.9% increase compared to depletion development. However, the presence of CH4 significantly reduces the amount of CO2 dissolution.
Author Contributions
Funding
Data Availability Statement
Conflicts of Interest
Correction Statement
References
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Parameters | Case 1 | Case 2 | Case 3 | |
---|---|---|---|---|
Domain geometry | Top depth, m | 1500 | 1191~1432 | |
Thickness, m | 50 | 181.8~291.7 | ||
Dimensions of model, - | 100 × 50 | 128 × 109 × 40 | ||
Gridblock size, m | 0.5 × 0.5 | - | ||
Fluid properties | Phases | Single-phase | Two phases | Two phases |
CO2 density, kg/m3 | f (state) | |||
Brine density, kg/m3 | f (state) | |||
CO2 viscosity, mPa·s | f (state) | |||
Brine viscosity, mPa·s | f (state) | |||
Diffusion coefficient, m2/s | 2 × 10−9 | |||
Porous media properties | Permeability, mD | 300 | 0.07~2.15 | |
Porosity, - | 0.25 | 0.005~0.054 | ||
Residual brine saturation, Swc | 0.2 | |||
Residual CO2 saturation, Sgr | 0 | |||
Salinity, ppm | 30,000 | |||
Gas end point relative permeability, krge | 1.0 | |||
Exponent of gas relative permeability, ng | 2 | |||
Exponent of water relative permeability, nw | 4 | |||
Capillary entry pressure, bar | 0.2 |
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Lyu, X.; Cen, F.; Wang, R.; Liu, H.; Wang, J.; Xiao, J.; Shen, X. Density-Driven CO2 Dissolution in Depleted Gas Reservoirs with Bottom Aquifers. Energies 2024, 17, 3491. https://doi.org/10.3390/en17143491
Lyu X, Cen F, Wang R, Liu H, Wang J, Xiao J, Shen X. Density-Driven CO2 Dissolution in Depleted Gas Reservoirs with Bottom Aquifers. Energies. 2024; 17(14):3491. https://doi.org/10.3390/en17143491
Chicago/Turabian StyleLyu, Xiaocong, Fang Cen, Rui Wang, Huiqing Liu, Jing Wang, Junxi Xiao, and Xudong Shen. 2024. "Density-Driven CO2 Dissolution in Depleted Gas Reservoirs with Bottom Aquifers" Energies 17, no. 14: 3491. https://doi.org/10.3390/en17143491