Paul C. Hackley Celeste D. Lohr 2018 <p><span>This work used mercury injection capillary pressure (MICP) analyses of the Tuscaloosa Group in Mississippi, including the Tuscaloosa marine shale (TMS), to assess their efficacy and sealing capacity for geologic carbon dioxide (CO</span><sub>2</sub><span>) sequestration. Tuscaloosa Group porosity and permeability from MICP were evaluated to calculate CO</span><sub>2</sub><span>&nbsp;column height retention. TMS and Lower Tuscaloosa shale samples have, respectively, Swanson permeability values less than 0.003 md and 0.00245 md; porosity from 3.86% to 9.86% and 1.34% to 7.96%; median pore throat sizes from 0.00342 to 0.0111 μm and 0.00311 to 0.017 μm; and pore radii from 0.0130 to 0.152 μm and 0.0132 to 0.149 μm. Mercury entry pressures for the TMS and Lower Tuscaloosa range from 4.9 to 57.1 MPa and 5.0 to 56.3 MPa, respectively. Calculated CO</span><sub>2</sub><span>&nbsp;column heights that the TMS sample set can retain in the reservoir range from 23 to 255 m when the TMS is near 100% water saturation. Potential top seal leakage is more likely to be influenced by the numerous well penetrations through the confining system of the TMS rather than capillary failure. Results of this study demonstrate desirable sealing capacity of the TMS for geologic CO</span><sub>2</sub><span>&nbsp;sequestration in reservoir sandstones of the Lower Tuscaloosa and could provide an analogue to other potential CO</span><sub>2&nbsp;</sub><span>sequestration top seals.</span></p> application/pdf 10.1016/j.ijggc.2018.09.006 en Elsevier Using mercury injection pressure analyses to estimate sealing capacity of the Tuscaloosa marine shale in Mississippi, USA: Implications for carbon dioxide sequestration article