CCS and Power Systems

Carbon Storage - Geologic Storage Technologies and Simulation and Risk Assessment

Prototype and Testing a New Volumetric Curvature Tool for Modeling Reservoir Compartments and Leakage Pathways in the Arbuckle Saline Aquifer: Reducing Uncertainty in CO2 Storage and Permanence

Performer: University of Kansas Center for Research

Project No: FE0004566

Program Background and Project Benefits

The overall goal of the Department of Energy’s (DOE) Carbon Storage Program is to develop and advance technologies that will significantly improve the effectiveness of geologic carbon storage, reduce the cost of implementation, and prepare for widespread commercial deployment between 2020 and 2030. Research conducted to develop these technologies will ensure safe and permanent storage of carbon dioxide (CO2) to reduce greenhouse gas (GHG) emissions without adversely affecting energy use or hindering economic growth.

Geologic carbon storage involves the injection of CO2 into underground formations that have the ability to securely contain the CO2 permanently. Technologies being developed for geologic carbon storage are focused on five storage types: oil and gas reservoirs, saline formations, unmineable coal seams, basalts, and organic-rich shales. Technologies being developed will work towards meeting carbon storage programmatic goals of (1) estimating CO2 storage capacity +/- 30 percent in geologic formations; (2) ensuring 99 percent storage permanence; (3) improving efficiency of storage operations; and (4) developing Best Practices Manuals. These technologies will lead to future CO2 management for coal-based electric power generating facilities and other industrial CO2 emitters by enabling the storage and utilization of CO2 in all storage types.

The DOE Carbon Storage Program encompasses five Technology Areas: (1) Geologic Storage and Simulation and Risk Assessment (GSRA), (2) Monitoring, Verification, Accounting (MVA) and Assessment, (3) CO2 Use and Re-Use, (4) Regional Carbon Sequestration Partnerships (RCSP), and (5) Focus Area for Sequestration Science. The first three Technology Areas comprise the Core Research and Development (R&D) that includes studies ranging from applied laboratory to pilot-scale research focused on developing new technologies and systems for GHG mitigation through carbon storage. This project is part of the Core R&D GSRA Technology Area and works to develop technologies and simulation tools to ensure secure geologic storage of CO2. It is critical that these technologies are available to aid in characterizing geologic formations before CO2-injection takes place in order to predict the CO2 storage resource and develop CO2 injection techniques that achieve optimal use of the pore space in the reservoir and avoid fracturing the  confining zone (caprock). The program’s R&D strategy includes adapting and applying existing technologies that can be utilized in the next five years, while concurrently developing innovative and advanced technologies that will be deployed in the decade beyond. This project’s research will evaluate the effectiveness of the volume curvature seismic tool to assess geologic storage formations and structural features such as sags, flexures, and fractures. This assessment will be completed for a saline carbonate formation in Kansas, and confirmed by the installation of a horizontal test boring that intersects the predicted paleokarst compartments.

Results from the project are valuable and unparalleled consisting of a number of technically challenging, industry firsts. This is the first pre-stack depth-migrated (PSDM) 3-D seismic volume for a Kansas reservoir and likely the first VC-processed PSDM volume worldwide. The DOE-sponsored McCord-A 20H well is an industry first for an extended-reach Arbuckle/Ellenburger lateral targeting paleokarst. The extensive logging program provides a rare data set to better characterize lateral paleokarst heterogeneity.

This project will benefit carbon storage by analyzing how a new seismic tool, VC, can verify existing data for the geologic storage capacity, optimize CO2 injection rates, and develop a better understanding of CO2 plume migration, reservoir containment, and CO2 leakage risk in deep saline geologic storage formations. This proposed project will also provide a valuable data set to complement a DOE funded regional assessment of Arbuckle carbon storage potential focused on south-central Kansas, and forward the carbon storage programmatic goals of estimating CO2 storage capacity +/- 30 percent in geologic formations, demonstrating 99 percent storage permanence, and improving the efficiency of storage operations.


The goals of the project are to use the results from existing field studies as a supplement to the seismic prototype being developed at KU in order to assess multiple parameters in a saline aquifer that contains areas influenced by paleokarst. The project consists of three phases:

  • First phase (Year 1) - The objectives are to collect geologic and engineering data, reprocess seismic data, conduct VC analysis, initiate Petrel geologic modeling, and simulate and history-match performance of existing wells to verify VC-identified compartments. Field activities include drilling, logging, and testing the vertical well and sidetracked horizontal lateral.

  • Second phase (Year 2) - The objectives are to complete formation evaluation, re-interpret seismic data, optimize the VC, and model seismic attributes, followed by integration of seismic data, VC analysis, and well data into a comprehensive model.

  • Third phase (Year 3) - The objectives include simulation studies to model CO2 storage and plume movement (dispersal, leakage at compartment boundary, and attenuation over time) and thereby determine the effectiveness of VC as a tool to better estimate carbon storage capacity and permanence in saline aquifers containing localized paleokarst areas.

The project will be conducted through applied research into the theoretical and applied aspects of geophysical surveys for multiple rock types and at different conditions (environmental parameters) in a saline geologic formation.

Project Details