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    Comparison of Hydrocarbon Potentials of New Albany Shale And Maquoketa Group in Indiana, USA
    (Jacobs Publishing, 2015-12) Akar, Cagla; Drobniak, Agnieszka; Mastalerz, Maria; Schimmelmann, Arndt
    Organic petrographic (maceral composition and vitrinite reflectance, Ro) and geochemical methods (Rock-Eval pyrolysis and total organic carbon, TOC) were used to compare hydrocarbon potentials of New Albany Shale (Middle Devonian to Lower Mississippian) and Maquoketa Group (Upper Ordovician) based on 51 samples from 5 drill cores from the Illinois Basin. New Albany Shale is an effective source rock due to its organic matter content and character (Type I and Type II kerogen) and its dominant placement in the oil window. The considerably higher thermal maturity of underlying strata has drawn attention to Maquoketa Shale as a possible source rock. Our results show that although Maquoketa Shale (Rock-Eval Tmax = 435 to 445 °C) is more mature than New Albany Shale (Tmax = 427 to 442 °C), the relatively higher organic matter content in New Albany Shale with up to 13.80 wt. % TOC supports a higher hydrocarbon potential than Maquoketa Shale’s TOC values between 0.09 to 1.32 wt. %. New Albany Shale’s notable differences between directly measured vitrinite reflectance values and calculated Ro values from Tmax are probably caused by suppression of vitrinite reflectance. Correction for suppression of Ro values would place New Albany Shale more favorably into the oil window.
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    Variations in Gas Content in Organic Matter-Rich Low Maturity Shale; Example from the New Albany Shale in the Illinois Basin
    (Jacobs Publishing, 2016-05) Drobniak, Agnieszka; Hampton, LaBraun; Karayigit, Ali; Mastalerz, Maria
    This paper investigates controls on gas content in the Upper Devonian to Lower Mississippian New Albany Shale, specifically addressing the influence of organic matter content and porosity on the desorbed and residual gas contents. The shale samples studied come from Daviess County, Indiana, where the entire New Albany Shale thickness of 40 m (~120 ft) was cored. Gas content was measured by canister desorption and volumetric displacement apparatus, and porosimetric techniques included He adsorption (total porosity) and low-pressure N2 (mesopore characteristics) and CO2 (micropore characteristics) adsorption techniques. Other techniques included organic petrographic analysis, TOC and S analysis, and SEM. Total porosity of the shales ranges from 2.9 to 10.3 %, BET surface area from 4.1 to 9.1 m2/g, BJH mesopore volume 0.0125 to 0.0243 cm3/g, and micropore volume 0.0080 to 0.0197 cm3/g. Our data demonstrate that organic matter content is a good predictor of gas content, and micro-pores present in organic matter are the main storage sites not only for residual but also desorbed gas. The role of larger pores in gas storage in these shales is limited.
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    Guide to Indiana Caverns
    (Indiana. Department of Conservation., 1939) Indiana. Division of Geology.; Simmons (Commissioner), V.M.; Esarey (State Geologist), Ralph