Journal
MARINE AND PETROLEUM GEOLOGY
Volume 39, Issue 1, Pages 138-149Publisher
ELSEVIER SCI LTD
DOI: 10.1016/j.marpetgeo.2012.09.001
Keywords
Seal rocks; Microstructure characterization; Nitrogen Gas Adsorption; Mercury Injection Capillary Pressure; Permeability
Categories
Funding
- CAPES
- Petrobras Research Center (Cenpes)
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Porous microstructure parameters of seal rock samples originating from different depths within Brazilian geological formations were correlated to empirical models which predict the intrinsic permeability. Mercury Injection Capillary Pressure (MICP) and Nitrogen Gas Adsorption (N(2)GA) were applied in combination as complementary techniques; MICP to obtain the porosity values and the size distribution of meso- and macropores, and N(2)GA associated with the Brunauer, Emmett and Teller (BET) theory to determine the specific surface area (S-0). The Barret, Joyner and Hallenda (BJH) theory was applied to find the size distribution of the micro- and mesopores. The combination of the MICP and N(2)GA curves showed that the samples analyzed present a polymodal pore size distribution (PSD) and a total porosity ranging from 0.33 % to 10.44 %. The S-0 values measured by N(2)GA were higher than those calculated by MICP, due to the majority of the samples having a mean pore size of 20-1000 A. The intrinsic permeability could also be predicted applying the measured parameters, S-0, PSD curves and total porosity in the Carman-Kozeny and Series-Parallel models. The ranges of permeability values obtained were 4.09 x 10(-24)-4.96 x 10(-21) m(2) and 9.48 x 10(-27)-9.14 x 10(-22) m(2), respectively. These results were compared with values reported in the related literature and those obtained for four samples submitted to pressure pulse decay permeability (PDP) tests. (c) 2012 Elsevier Ltd. All rights reserved.
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