scholarly journals A Hierarchical Framework for CO2 Storage Capacity in Deep Saline Aquifer Formations

2022 ◽  
Vol 9 ◽  
Author(s):  
Ning Wei ◽  
Xiaochun Li ◽  
Zhunsheng Jiao ◽  
Philip H. Stauffer ◽  
Shengnan Liu ◽  
...  
Keyword(s):  
Large Scale ◽  
Storage Capacity ◽  
Co2 Storage ◽  
Assessment Method ◽  
Saline Aquifers ◽  
Data Types ◽  
Risk Regulation ◽  
Deep Saline Aquifer ◽  
Aquifer Storage ◽  
Hierarchical Framework

Carbon dioxide (CO2) storage in deep saline aquifers is a vital option for CO2 mitigation at a large scale. Determining storage capacity is one of the crucial steps toward large-scale deployment of CO2 storage. Results of capacity assessments tend toward a consensus that sufficient resources are available in saline aquifers in many parts of the world. However, current CO2 capacity assessments involve significant inconsistencies and uncertainties caused by various technical assumptions, storage mechanisms considered, algorithms, and data types and resolutions. Furthermore, other constraint factors (such as techno-economic features, site suitability, risk, regulation, social-economic situation, and policies) significantly affect the storage capacity assessment results. Consequently, a consensus capacity classification system and assessment method should be capable of classifying the capacity type or even more related uncertainties. We present a hierarchical framework of CO2 capacity to define the capacity types based on the various factors, algorithms, and datasets. Finally, a review of onshore CO2 aquifer storage capacity assessments in China is presented as examples to illustrate the feasibility of the proposed hierarchical framework.

Effect of brine salinity on CO2 plume migration and trapping capacity in deep saline aquifers

2017 ◽  
Vol 57 (1) ◽  
pp. 100 ◽  
Author(s):  
Emad A. Al-Khdheeawi ◽  
Stephanie Vialle ◽  
Ahmed Barifcani ◽  
Mohammad Sarmadivaleh ◽  
Stefan Iglauer
Keyword(s):  
Co2 Storage ◽  
Three Dimensional ◽  
Rock Properties ◽  
Saline Aquifers ◽  
Migration Distance ◽  
Deep Saline Aquifer ◽  
Plume Migration ◽  
Co2 Plume ◽  
Wet Rocks ◽  
Brine Salinity

CO2 migration and storage capacity are highly affected by various parameters (e.g. reservoir temperature, vertical to horizontal permeability ratio, cap rock properties, aquifer depth and the reservoir heterogeneity). One of these parameters, which has received little attention, is brine salinity. Although brine salinity has been well demonstrated previously as a factor affecting rock wettability (i.e. higher brine salinity leads to more CO2-wet rocks), its effect on the CO2 storage process has not been addressed effectively. Thus, we developed a three-dimensional homogeneous reservoir model to simulate the behaviour of a CO2 plume in a deep saline aquifer using five different salinities (ranging from 2000 to 200 000 ppm) and have predicted associated CO2 migration patterns and trapping capacities. CO2 was injected at a depth of 1408 m for a period of 1 year at a rate of 1 Mt year–1 and then stored for the next 100 years. The results clearly indicate that 100 years after the injection of CO2 has stopped, the salinity has a significant effect on the CO2 migration distance and the amount of mobile, residual and dissolved CO2. First, the results show that higher brine salinity leads to an increase in CO2 mobility and CO2 migration distance, but reduces the amount of residually trapped CO2. Furthermore, high brine salinity leads to reduced dissolution trapping. Thus, we conclude that less-saline aquifers are preferable CO2 sinks.

scholarly journals Maturing global CO2 storage resources on offshore continental margins to achieve 2DS emissions reductions

2019 ◽  
Vol 9 (1) ◽  
Author(s):  
P. S. Ringrose ◽  
T. A. Meckel
Keyword(s):  
Large Scale ◽  
Storage Capacity ◽  
Pore Space ◽  
Co2 Storage ◽  
Emissions Reduction ◽  
Continental Margins ◽  
Emissions Reductions ◽  
Injection Wells ◽  
Reduction Strategies

AbstractMost studies on CO2 emissions reduction strategies that address the ‘two-degree scenario’ (2DS) recognize a significant role for CCS. For CCS to be effective, it must be deployed globally on both existing and emerging energy systems. For nations with large-scale emissions, offshore geologic CO2 storage provides an attractive and efficient long-term strategy. While some nations are already developing CCS projects using offshore CO2 storage resources, most geographic regions have yet to begin. This paper demonstrates the geologic significance of global continental margins for providing broadly-equitable, geographically-relevant, and high-quality CO2 storage resources. We then use principles of pore-space utilization and subsurface pressure constraints together with analogs of historic industry well deployment rates to demonstrate how the required storage capacity can be developed as a function of time and technical maturity to enable the global deployment of offshore storage for facilitating 2DS. Our analysis indicates that 10–14 thousand CO2 injection wells will be needed globally by 2050 to achieve this goal.

scholarly journals Static and Dynamic Estimates of CO2-Storage Capacity in Two Saline Formations in the UK

SPE Journal ◽  
2012 ◽  
Vol 17 (04) ◽  
pp. 1108-1118 ◽  
Author(s):  
M.. Jin ◽  
G.. Pickup ◽  
E.. Mackay ◽  
A.. Todd ◽  
M.. Sohrabi ◽  
...  
Keyword(s):  
Input Data ◽  
Storage Capacity ◽  
Co2 Storage ◽  
Total Pore Volume ◽  
Static Method ◽  
Initial Assessment ◽  
Storage Site ◽  
Aquifer Storage ◽  
The Uk ◽  
Migration Pathways

Summary Estimation of carbon dioxide (CO2)-storage capacity is a key step in the appraisal of CO2-storage sites. Different calculation methods may lead to widely diverging values. The compressibility method is a commonly used static method for estimating storage capacity of saline aquifers: It is simple, is easy to use, and requires a minimum of input data. Alternatively, a numerical reservoir simulation provides a dynamic method that includes Darcy flow calculations. More input data are required for dynamic simulation, and it is more computationally intensive, but it takes into account migration pathways and dissolution effects, so it is generally more accurate and more useful. For example, the CO2-migration plume may be used to identify appropriate monitoring techniques, and the analysis of the trapping mechanism for a certain site will help to optimize well location and the injection plan. Two hypothetical saline-aquifer storage sites in the UK, one in Lincolnshire and the other in the Firth of Forth, were analyzed. The Lincolnshire site has a comparatively simple geology, while the Forth site has a more complex geology. For each site, both static- and dynamic-capacity calculations were performed. In the static method, CO2 was injected until the average pressure reached a critical value. In the migration-monitoring case, CO2 was injected for 15 years, and was followed by a closure period lasting thousands of years. The fraction of dissolved CO2 and the fraction immobilized by pore-scale trapping were calculated. The results of both geological systems show that the migration of CO2 is strongly influenced by the local heterogeneity. The calculated storage efficiency for the Lincolnshire site varied between 0.34% and 0.65% of the total pore-volume, depending on whether the system boundaries were considered open or closed. Simulation of the deeper, more complex Forth geological system gave storage capacities as high as 1.05%. This work was part of the CO2-Aquifer-Storage Site Evaluation and Monitoring (CASSEM) integrated study to derive methodologies for assessment of CO2 storage in saline formations. Although static estimates are useful for initial assessment when fewer data are available, we demonstrate the value of performing dynamic storage calculations and the opportunities to identify mechanisms for optimizing the storage capacity.

Numerical Simulation of Geological Carbon Sequestration in Saline Aquifers: Three Case Studies

2013 ◽  
Author(s):  
Zheming Zhang ◽  
Ramesh Agarwal
Keyword(s):  
Carbon Sequestration ◽  
Numerical Simulations ◽  
History Matching ◽  
Large Scale ◽  
Co2 Storage ◽  
Economic Feasibility ◽  
Saline Aquifers ◽  
Saline Aquifer ◽  
Geological Carbon Sequestration ◽  
Plume Migration

Geological carbon sequestration (GCS) is one of the most promising technologies to address the issue of excessive anthropogenic CO2 emissions in the atmosphere due to fossil fuel combustion for electricity generation. For GCS, the saline aquifer geological carbon sequestration is considered very attractive compared to other options because of their huge sequestration capacity in U.S. and other parts of the world. However, in order to fully exploit their potential, the injection strategies need to be investigated that can address the issues of both the CO2 storage efficiency and safety along with their economic feasibility. Numerical simulations can be used to determine these strategies before the deployment of full scale sequestration in saline aquifers. This paper presents the numerical simulations of CO2 sequestration in three large identified saline aquifers (Mt. Simon, Frio, Utsira) where the sequestration is currently underway or has recently been completed (in case of Frio). The numerical simulations are in acceptable agreement with the seismic data available for plume migration. The results of large scale history-matching simulation in Mt. Simon, Frio, and Utsira formations provide important insights in the uncertainties associated with the numerical modeling of saline aquifer GCS.

scholarly journals Integrated static modelling and dynamic simulation framework for CO2 storage capacity in upper Qishn Clastics, S1A reservoir, Yemen

2021 ◽  
Author(s):  
Ayman Mutahar AlRassas ◽  
Hung Vo Thanh ◽  
Shaoran Ren ◽  
Renyuan Sun ◽  
Nam Le Nguyen Hai ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Large Scale ◽  
Storage Capacity ◽  
Co2 Storage ◽  
Uncertainty Assessment ◽  
Alternative Measure ◽  
Modeling Framework ◽  
Significant Difference ◽  
Static Modelling ◽  
And Storage

Abstract Carbon dioxide (CO2) capture and storage (CCS) is presented as an alternative measure and promising approach to mitigate the large-scale anthropogenic CO2 emission into the atmosphere. In this context, CO2 sequestration into depleted oil reservoirs is a practical approach as it boosts the oil recovery and facilitates the permanent storing of CO2 into the candidate sites. However, the estimation of CO2 storage capacity in subsurfaces is a challenge to kick-start CCS worldwide. Thus, this paper proposes an integrated static and dynamic modeling framework to tackle the challenge of CO2 storage capacity in a clastic reservoir, S1A filed, Masila basin, Yemen. To achieve this work's ultimate goal, the geostatistical modeling was integrated with open-source code (MRST-CO2lab) for reducing the uncertainty assessment of CO2 storage capacity. Also, there is a significant difference between static and dynamic CO2 storage capacity. The static CO2 storage capacity varies from 4.54 to 81.98 million tons, while the dynamic CO2 simulation is estimated from 4.95 to 17.92 million tons. Based on the geological uncertainty assessment of three ranked realizations (P10, P50, P90), our work was found that the upper Qinshn sequence could store 15.64 Million tons without leakage. This result demonstrates that the potential of CO2 utilization is not only in this specific reservoir, but the further CO2 storage for the other clastics reservoirs is promising in the Masila Basin, Yemen.

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