CO2 Storage and Enhanced Oil Recovery: Sugar Creek Oil Field Test Site, Hopkins County, Kentucky

Abstract

The Midwest Geological Sequestration Consortium (MGSC) carried out a small-scale carbon dioxide (CO 2 ) injection test in the Jackson sandstone (Mississippian System Big Clifty Sandstone Member) in order to gauge the large-scale CO 2 storage that might be realized from enhanced oil recovery (EOR) of mature Illinois Basin oil fields via immiscible liquid CO 2 flooding.As part of the MGSC's Validation Phase (Phase II) studies, the small injection pilot test was conducted at the Sugar Creek Field in Hopkins County, western Kentucky, which was chosen for the project on the basis of site infrastructure as well as reservoir conditions. Geologic data on the target formation were limited, but core analysis reports permitted the estimation of porosity and permeability, and geophysical logs were used to define the structure and architecture of the target formation. A geocellular model of the reservoir was constructed to improve understanding of CO 2 behavior in the subsurface.At the time of site selection, the field was under secondary recovery through water injection. A water injection well surrounded by four nearby producing wells was converted to CO 2 injection, and several additional production and observation wells were instrumented to collect temperature and pressure response information. The CO 2 injection period lasted from May 13, 2009, through May 26, 2010, and was punctuated by multiple interruptions, which ranged from a few days to several weeks in length. These lapses were caused by line leaks and supply interruptions due to winter weather. A total of 6,560 tonnes (7,230 tons) of CO 2 were injected into the reservoir at rates that generally ranged from 18.2 to 27.3 tonnes (20 to 30 tons) per day. Injection pressure decreased slowly with time. The CO 2 injection was followed by more than a year of water injection and continued monitoring.Pressure changes and elevated CO 2 levels in response to injection (breakthrough) occurred at five production wells during the one-year injection period, all within the first five months. The first breakthrough occurred one week after commencement of CO 2 injection, which was sooner than expected based on modeling; this difference was attributed to a previously undetected fracture network.A monitoring, verification, and accounting (MVA) program was set up to document the fate of injected CO 2 . Extensive sampling of brine, groundwater, and wellhead gas was carried out, beginning before CO 2 injection and continuing through the waterflooding period. Samples were gathered at Sugar Creek Field production and observation wells, newly constructed groundwater monitoring wells, and nearby domestic and agricultural wells. Samples underwent geochemical and isotopic analysis to reveal any CO 2 -related changes. Groundwater and kinetic modeling and mineralogical analysis were also employed to better understand long-term dynamics of CO 2 in the reservoir. No CO 2 leakage into groundwater was detected, and analysis of brine and gas chemistry made it possible to track the path of pl...

An Assessment of Geological Carbon Storage Options in the Illinois Basin: Validation Phase

“…The MGSC carried out a pilot project to test storage of carbon dioxide (CO 2 ) in the Jackson sandstone (Mississippian System, Big Clifty Sandstone Member) in order to gauge the potential for EOR and concomitant large-scale CO 2 storage via immiscible CO 2 flooding in mature Illinois Basin oil fields (Frailey, 2012c).…”

CO₂ Storage and Enhanced Oil Recovery: Bald Unit Test Site, Mumford Hills Oil Field, Posey County, Indiana

“…For Phase II (2005II ( -2011, four small-scale field tests were conducted. They included testing the ability to adsorb gaseous CO 2 (Frailey et al 2012a) in a deep, unminable coal seam and the ability to store CO 2 and enhance oil production in mature oil fields (Frailey et al 2012b). Each of these field tests had an extensive monitoring program for sampling air, shallow groundwater, and fluids from the injection zone, as well as geophysical and cased-hole logging and monitoring of pressure changes to understand the fate of injected CO 2 at the test sites.…”