Carbon Storage
Simulation and Risk Assessment Focus Area
The Simulation and Risk Assessment Focus Area is an integrated effort to develop advanced simulation models of the subsurface and integrate the results into a risk assessment that includes both technical and programmatic risks. As the simulation models are refined with new data, the uncertainty surrounding the identified risks decreases, which in turn provides a more accurate risk assessment and mitigation plan for each project site. Both qualitative and quantitative protocols will be developed to ensure the safe and permanent storage of carbon dioxide (CO2). Results from the simulation models will be incorporated into risk assessments on a project-by-project basis and on a larger basin-scale. As carbon capture and storage (CCS) becomes deployed in major basins, macro model results will be needed to manage reservoirs for pressure management, plume migration, and potential risks of multiple CO2 injection projects across the basin.
Specifically, simulation models also can be used to: (1) predict the thermal impacts and hydrologic flow of CO2 in the target formation; geochemical and thermal changes that may occur in the storage formation; (2) geomechanical effects on the target formation, seals, and release pathways, such as faults, fractures, and wellbores; and (3) the effect of biological responses in the presence of supercritical CO2.
A risk assessment is often performed at the early stages of a project to help in site selection, communicating project goals and procedures to the public, and aiding regulators in permitting for the project. Risk assessment is also necessary in identifying potential issues with a storage site and developing mitigation procedures so that immediate action can be implemented should an issue arise. Risk assessment and management for CO2 storage efforts generally include two primary aspects: (1) programmatic risks (including resource and management risks) that may inhibit project progress or costs, and (2) storage (technical) risks inherent to the scientific and engineering objectives of a storage project. Calculation of risk profiles is a common approach to assessing the predicted performance of large-scale projects. These also help determine long-term project costs and potential liabilities in support of decisions on decommissioning and long-term stewardship.
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Schematic Risk Profile for A CO2 Storage Project (Benson, 2007; WRI Presentation) |
Simulation and Risk Assessment Technologies
Simulation is a critical step in the systematic development of a monitoring program for a geologic CO2 storage project because the selection of an appropriate measurement method and/or instrument is based on whether the method or instrument can provide the data necessary to address a particular technical issue related to CO2 storage. Effective monitoring can confirm that the project is performing as expected from predictive models. The linkage between model results and monitoring data can be complicated if monitoring programs are not designed to address which parameters should be monitored to match with model parameters. These parameters include timing, location, spatial scale, and resolution of measurements. Monitoring data collected early in a project are often used to refine and calibrate the predictive model, improving the basis for predicting the longer term performance of the project. Simulations are utilized to predict the following:
- Temporal and spatial migration of the injected CO2 plume.
- Effect(s) of geochemical reactions on CO2 trapping and long-term porosity and permeability.
- Assess caprock and wellbore integrity.
- Impact of thermal andcompositional gradients in the reservoir.
- Pathways of CO2 out of the reservoir.
- Importance of secondary barriers.
- Effect(s) of unplanned hydraulic fracturing.
- Extent of upward migration of CO2 along the outside of the well casing
- Impacts of cement dissolution.
- Consequences of wellbore failure.
A significant amount of work has been completed by industry and academia to develop simulators for CO2 that couple thermal, hydrologic, mechanical, chemical, and biological (THMCB) impacts of CO2 injection. Several different models (independent and coupled) are currently being used in many field projects to validate laboratory observations. Current research in this focus area includes refinement and coupling of models that can represent these processes for this focus area:
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- A number of two- and three-dimensional numerical codes for simulating coupled groundwater and heat flow that are capable of modeling CO2 flow though porous and fractured media are currently being developed. These models are critical to predicting the performance and informing the project developer of risk and operational design of CCS projects.
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- Improve limited research focus of existing models to improve coupling of thermal and hydrologic processes.
- Improve regional hydrologic modeling of flow for basin-scale CCS operations that account for variances in depositional environments.
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- Chemical modeling for CCS can take several forms and ideally should include processes such as aqueous speciation, dissolution/precipitation, redox processes, ion-exchange between solutions and minerals, and surface chemical reactions occurring at phase interfaces.
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- Improve reaction kinetics.
- Examine effects on porosity and permeability.
- Examine effects on geomechanical processes.
- Research coupling with transport and multiphase flow and reaction.
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- Geomechanical processes include the effects of fluid pressure, elastic and non-recoverable deformation, fracturing and larger-scale faulting in a geologic setting. Simulation algorithms have shown extremely rapid advances over the past two decades, including sophisticated gridding techniques and mathematical optimization methods.
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- Improve coupling of hydrologic and mechanical models for impacts on faults, fractures, and wellbores.
- Examine the impact of regional pressure increases on basin-scale seismicity.
- Examine the scaling of pore-scale models to predict project and regional impacts of mechanical processes that might impact hydrologic flow and risks.
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- The influence that microorganisms have in the subsurface underscores the importance of understanding how CO2 storage will affect microbial activity. This information may be used to prevent or mitigate negative consequences associated with CO2 injection. Furthermore, understanding CO2 reservoir microbiology may offer opportunities to enhance CO2 retention.
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- Assess the impacts to microbial communities.
- Examine the effects on permeability to reduce risks of release.
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- Risk assessment is the systematic identification of features, events, or processes (FEPs) which might pose a potential risk to the operations or impacts from a CCS project. Understanding these risks is critical to the design, optimization, permitting, and implementation of CCS projects. In addition to identification of potential migration pathways, the identification of specific consequences relating to a release of CO2 is equally important.. For geologic storage, some potential consequences that have been identified in laboratory studies include brine contamination of USDWs, unintended migration of CO2 into petroleum resources or other infringement on mineral rights, and long-term CO2 seepage into the atmosphere. Building upon field operation experience and simulation modeling will support the development of rigorous risk assessment modeling for CCS.
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- Develop standard processes for risk assessment.
- Develop risk assessment databases for FEPs to predict risk and impacts in different types of geologic formations.
- Compare the predictive methods against observations to demonstrate reliability and accuracy as well as to reduce uncertainties.
- Integrate risk assessment with simulation, operation design, and monitoring activities to optimize performance.
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Information on active simulation and risk assessment projects receiving DOE funds that aim to obtain the Carbon Storage Program's goals are provided in the following table.
Project Name |
Performer |
Funding Source |
Analytical-Numerical Sharp-Interface Model of CO2 Sequestration & Application to Illinois Basin |
New Mexico Institute of Mining and Technology |
Base |
Basin-Scale Leakage Risks from Geologic Carbon Sequestration: Impact on CCS Energy Market Competitiveness |
Princeton University |
Base |
Comprehensive, Quantitative Risk Assessment of CO2 Geologic Sequestration |
Headwaters Technology Innovation Group |
Base |
Development of a Software Framework for System Level Carbon Sequestration Risk Assessment |
GoldSim Technology Group |
Base |
Geomechanical Simulation of CO2 Leakage and Cap Rock Remediation |
Missouri University of Science and Technology (Miners Circle) |
Base |
Geomechanical Simulation of Fluid-Driven Fractures |
University of Minnesota |
ARRA |
High Fidelity Computational Analysis of CO2 Sorption at Pore Scales in Coal Seams |
University of Texas at El Paso |
ARRA |
Modeling and Risk Assessment of CO2 Sequestration at the Geologic-Basin Scale |
Massachusetts Institute of Technology |
ARRA |
Molecular Simulation of Dissolved Inorganic Carbons for Underground Brine CO2 Sequestration |
California Institute of Technology |
ARRA |
Monitoring and Numerical Modeling of Shallow CO2 Injection, Greene County, Missouri |
Missouri State University |
ARRA |
Numerical Modeling of Geomechanical Processes Related to CO2 Injection within Generic Reservoirs |
Missouri University of Science and Technology (Miners Circle) |
ARRA |
Risk Assessment and Monitoring of Stored CO2 in Organic Rocks Under Non-Equilibrium Conditions |
Southern Illinois University |
ARRA |
Simulation Framework for Regional Geologic CO2 Storage Infrastructure Along Arches Province |
Battelle Memorial Institute |
Base |
Simulation of Couple Processes of Flow, Transport and Storage of CO2 in Saline Aquifers |
Colorado School of Mines |
Base |
The Coal-Seq III Consortium: Advancing the Science of CO2 Sequestration in Coal Seam and Gas Shale Reservoirs |
Advanced Resources International |
Base |
The Potential Risks of Freshwater Aquifer Contamination with Geosequestration |
Duke University |
ARRA |
Training and Research on Probabilistic Hydro-Thermo-Mechanical Modeling of Carbon Dioxide Geological Sequestration in Fractured Porous Rocks |
Colorado School of Mines |
ARRA |
Training Graduate and Undergraduate Students in Simulation and Risk Assessment for Carbon Sequestration |
Colorado School of Mines |
ARRA |
Training Students to Analyze Spatial and Temporal Heterogeneities in Reservoir and Seal Petrology, Mineralogy, and Geochemistry: Implications for CO2 Sequestration Prediction, Simulation,
and Monitoring |
Purdue University |
ARRA |
Web-Based CO2 Subsurface Modeling |
San Diego State University |
ARRA |
Actualistic and Geomechanical Modeling of Reservoir Rock, CO2 and Formation Fluid Interaction, Citronelle Oil Field, Alabama |
West Virginia University |
ARRA |
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