TX 75083-3836, U.S.A., fax 01-972-952-9435. AbstractCurrent studies of geologic storage of CO 2 , with the exception of CO 2 sequestration in coal beds, focuses on supercritical CO 2 , emphasizing the stability of the fluid, solubility of CO 2 in saline formation water and miscibility with crude oil. Likewise, with the exception of very early research, the use of CO 2 to enhance oil recovery (EOR) historically focused on supercritical CO 2 to achieve miscible conditions with crude oil. The only possibility of liquid CO 2 geologic storage is in formations with temperatures less than the critical temperature of CO 2 .Due to the naturally occurring geothermal temperature gradient, most all geologic formations currently considered for CO 2 sequestration and EOR exceed the T cCO2 .A research plan has been developed to investigate the use of depleting (mature) oil reservoirs with formation temperatures less than critical temperature of CO 2 to sequester liquid CO 2 and investigate the implications of EOR from the liquid CO 2 displacement process. Relatively higher pressures are required to attain liquid CO 2 , which translate to fracture gradients as high as 1.0 psi/ft. However, fracture stimulation data published in early literature and field data from fracture stimulation companies in the Illinois Basin show that fracture gradients of up to 1.0 psi/ft are commonly recorded in the shallower producing horizons of the Basin. Therefore, the pressure requirement may not be a detriment.Because of the liquid/gas phase changes and consequent changes in density and viscosity of CO 2 at subcritical temperatures, low temperature oil reservoirs provide a unique opportunity for liquid CO 2 storage and the application of a novel and innovative EOR-CO 2 cyclic multi-reservoir displacement process within the Illinois Basin.
David G. Morse (ISGS) led the effort to find a suitable injection site and all of the well drilling work to the casing point including the coring and open hole logging operations. Morse coordinated the Coal Characterization program and was the primary author for the coal characterization section of this report. Contributors to the coal characterization are as follows: ISGS contributors were Keith Hackley, gas chromatographic and isotopic characterization; and Christopher Korose, Geographic Information Systems and volumetrics. Laboratory experiments on coal adsorption, shrinkage, and swelling were conducted by Satya Harpalani, Southern Illinois University at Carbondale. Maria Mastalerz, Agnieszka Drobniak, and John Rupp (Indiana Geological Survey) were involved with planning, performed some desorption and gas chemistry and all maceral characterization analyses, and studied the roles of various coal macerals and coal pore size distribution in sequestration. Ivan G. Krapac (ISGS) coordinated the monitoring, verification, and accounting (MVA) program at the Tanquary site. He designed and developed the general MVA requirements of the site and worked with individual contributors towards the synergistic and collaborative effort of this program. Krapac coordinated, compiled, and edited the MVA strategy and MVA observations and discussions sections. ISGS contributors to both field efforts and data analysis and interpretation included Peter Berger (geochemical modeling), Gayathri Gopalakrishnan (GFLOW modeling), Keith Hackley (gas characterization), Donald Luman (color infrared imagery), Ed Mehnert (groundwater modeling, water well installation and development), and William Roy (geochemical modeling). Abbas Iranmanesh and Bracken Wimmer assisted with monitoring well installation and development, conducted the monthly water and gas sampling of the domestic and injection site ground water and the injection coal seam monitoring wells, and contributed to documentation of sampling methodology. ISGS well drilling crew led by Jack Aud installed groundwater monitoring wells. Bob Butsch (Schlumberger Carbon Services) completed the cased hole log analyses. Scott Frailey led the pilot planning, scheduling, and logistics of implementing the plan through post-carbon dioxide (CO 2) injection testing and ultimate abandonment of wells and reclamation of the site. Frailey designed the pressure transient tests and performed real time analyses of the data. He coordinated the numerical modeling and pressure transient analyses for analyzing the pressure and injection rate from the CO 2 and water injection periods. Frailey was the primary author for the introduction and sections on site selection; pilot site design modification and well arrangement; drilling operations, open hole tests, and casing; completion; coal seam (in situ) characterization (pre-CO 2); field observations during active CO 2 injection; interpretation, analyses, and modeling of pilot results; and conclusions. Text for these sections was also contributed by
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