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This project is conducting a stacked reservoir injection pilot study to further evaluate the feasibility and efficacy of long-term CO2 storage in saline reservoirs and the use of CO2 in enhanced oil recovery (EOR) operations in the Mid-continent. The stacked pilot study will inject up to 70,000 metric tons of CO2, into multiple formations. This includes a maximum of 40,000 metric tons of CO2 into the Lower Arbuckle Group (an extensive saline aquifer) and a maximum of 30,000 metric tons into the overlying oil-bearing dolomite of the Wellington Oilfield. State-of-the art MVA (monitoring, verification, accounting, and assessment) tools and techniques to monitor and visualize the injected CO2 plume and establish best practice methodologies for MVA in shelf clastic and shelf carbonate formations are being conducted. This will help reduce storage risk by documenting the uncertainties related to these specific depositional environments and monitoring techniques. Additionally, simulation initiatives are being used to integrate multiple in situ and ex situ monitoring systems in tandem to track the location of injected CO2.
This project focuses on defining the regional opportunities for CO2 storage in carbonate and clastic saline formations and depleted oil reservoirs thus providing the foundation for larger volume projects in the Mid-continent region. Field validation of characterization, modeling, monitoring, accounting, and assessment and risk management technologies demonstrate the ability to permanently and efficiently store CO2 in these formations. Specifically, this project is conducting CO2 injection for saline storage in the Arbuckle basal sandstone and vuggy dolomite and dolomite with EOR storage in the overlying Mississippian siliceous dolomite oil reservoir at Wellington Field. Completion of the project will demonstrate safe and permanent storage of CO2.
