Pore characterization of organic-rich Lower Cambrian shales in Qiannan Depression of Guizhou Province, Southwestern China

Tian, Hui; Pan, Lei; Zhang, Tongwei; Xiao, Xia; Meng, Zhaoping; Huang, Baojia

doi:10.1016/j.marpetgeo.2015.01.004

Cited by 193 publications

(104 citation statements)

References 58 publications

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“…These agree well with previous results from gas shales in North American basins (Chalmers and Bustin, 2008;Ross and Bustin, 2009) and Lower Silurian and Lower Cambrian shales in southwestern China (Tian et al, 2013. They both suggest that organic matters provide important spaces for micropores development in the Lower Silurian shale, which has also been reported in other shales (Milliken et al, 2013;Tian et al, 2013Tian et al, , 2015. In addition to organic matter abundance, organic matter maturity also plays an important role for micropore development, which has been reported in other shale (Chen and Xiao, 2014).…”

Section: Isotherms Of Co 2 Adsorptionsupporting

confidence: 91%

Quantitative characterization of micropore structure for organic-rich Lower Silurian shale in the Upper Yangtze Platform, South China: Implications for shale gas adsorption capacity

Chen

Jiang

Liu

et al. 2017

Adv. Geo-Energ. Res.

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The pores in shales are mainly of nanometer-scale, and their pore size distribution is very important for shale gas storage and adsorption capacity, especially micropores having widths less than 2 nm, which contribute to the main occurrence space for gas adsorption. This study is focused on the organic-rich Lower Silurian black shale from four wells in the Upper Yangtze Platform, and their total organic carbon (TOC), mineralogical composition and micropore characterization were investigated. Low pressure CO2 adsorption measurement was conducted at 273.15 K in the relative pressure range of 0.0001-0.03, and the micropore structure was characterized by Dubinin-Radushkevich (DR) equation and density functional theory (DFT) method and then the relationship between micropore structure and shale gas adsorption capacity was discussed. The results indicated that (1) The Lower Silurian shale have high TOC content in the range of 0.92-4.96%, high quartz content in the range of 30.6-69.5%, and high clays content in the range of 24.1-51.2%. The TOC content shows a strong positive relationship with the quartz content which suggests that the quartz is mainly biogenic in origin. (2) The micropore volume varies from 0.12 cm 3 /100 g to 0.44 cm 3 /100 g and micropore surface area varies from 4.97 m 2 /g to 17.94 m 2 /g. Both of them increase with increasing TOC content, indicating TOC is the key factor to control the micropore structure of the Lower Silurian shale. (3) Low pressure CO2 adsorption measurement provides the most suitable detection range (0.3-1.5 nm) and has high reliability and accuracy for micropore structure characterization. (4) The TOC content is the key factor to control gas adsorption capacity of the Lower Silurian shale in the Upper Yangtze Platform.

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Section: Isotherms Of Co 2 Adsorptionsupporting

confidence: 91%

Quantitative characterization of micropore structure for organic-rich Lower Silurian shale in the Upper Yangtze Platform, South China: Implications for shale gas adsorption capacity

Chen

Jiang

Liu

et al. 2017

Adv. Geo-Energ. Res.

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“…The permeability of the studied shales rank as LSL shale (average of 0.0016 mD) > UOW shale (average of 0.0014 mD) > LCN shale (average of 0.0012 mD) ( Table 1). The distinction of the porosity and permeability between different shales in this study is consistent with these previous studies [11,13,17], which indirectly confirms the veracity of the comparison regarding the porosity and permeability of different shales.…”

Section: Porosity and Permeabilitysupporting

confidence: 92%

“…As higher total pore volume is more advantageous for shale gas extraction [17,28], the results of the PSD analysis show that the LSL and the UOW shales are more competitive than the LCN shale. Figure 6.…”

Section: Pore Size Distribution (Psd)mentioning

confidence: 99%

Comparison of Three Key Marine Shale Reservoirs in the Southeastern Margin of the Sichuan Basin, SW China

et al. 2017

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This study performs a comprehensive comparison of three key marine shale reservoirs in the southeastern margin of the Sichuan Basin, and explains why commercial gas production was only achieved in the Lower Silurian Longmaxi (LSL) and Upper Ordovician Wufeng (UOW) formations, but not in the Lower Cambrian Niutitang (LCN) formation. The experimental methods included in situ gas content and gas composition tests, methane adsorption analysis, low-pressure N 2 adsorption, field emission scanning electron microscopy (FE-SEM), and total organic carbon (TOC) and vitrinite reflectance (R o ) analyses to evaluate the lithology, mineralogy, physical properties of the reservoir, organic geochemistry, in situ gas content and methane adsorption capacity characteristics of the three shales. The LCN shale has lower quartz and clay mineral contents and a low brittleness index, but higher contents of feldspar, pyrite and carbonate minerals than the LSL and UOW shales. The porosity and permeability of the LSL and UOW shales are higher than those of the LCN shale. The primary contributions to the high permeability in the LSL shale are its well-developed fractures and organic matter pores. In contrast, the over-mature LCN shale is unfavorable for the development of organic pores and fractures. Although the LCN shale has a higher methane sorption capacity than the LSL and UOW shales, the gas content and methane saturation of the LCN shale are distinctly lower than those of the LSL and UOW shales. This is primarily due to gas migration from the LCN shale, resulting from the activities of tectonic uplift and the unconformable contact between the LCN shale and the Dengying formation. When compared with gas shale in North America, the LSL shale is the most favorable shale reservoir out of the three Sichuan shales, while the combination of the LSL and UOW shales is also potentially productive. However, the individual single layer production of the UOW or LCN shales is still limited due to poor resource potential and/or reservoir physical characteristics in the study area.

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“…[15][16][17] Multiple techniques have been used to characterize the pore structure mainly including direct imaging and indirect fluid penetration methods. 4,18 Direct imaging methods, including transmission electron microscopy (TEM), field emission scanning electron microscopy (FE-SEM) and atomic force microscopy (AFM), can directly obtain high-resolution images of the pore structures.…”

Section: Introductionmentioning

confidence: 99%

Morphology and Fractal Characterization of Multiscale Pore Structures for Organic-Rich Lacustrine Shale Reservoirs

Wang

Zhu

et al. 2018

Fractals

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Lacustrine shale gas has received considerable attention and has been playing an important role in unconventional natural gas production in China. In this study, multiple techniques, including ¶ Corresponding author. This is an Open Access article published by World Scientific Publishing Company. It is distributed under the terms of the Creative Commons Attribution 4.0 (CC-BY) License. Further distribution of this work is permitted, provided the original work is properly cited. total organic carbon (TOC) analysis, X-ray diffraction (XRD) analysis, field emission scanning electron microscopy (FE-SEM), helium pycnometry and low-pressure N 2 adsorption have been applied to characterize the pore structure of lacustrine shale of Upper Triassic Yanchang Formation from the Ordos Basin. The results show that organic matter (OM) pores are the most important type dominating the pore system, while interparticle (interP) pores, intraparticle (intraP) and microfractures are also usually observed between or within different minerals. The shapes of OM pores are less complex compared with the other two pore types based on the Image-Pro Plus software analysis. In addition, the specific surface area ranges from 2.76 m 2 /g to 10.26 m 2 /g and the pore volume varies between 0.52 m 3 /100g and 1.31 m 3 /100g. Two fractal dimensions D 1 and D 2 were calculated using Frenkel-Halsey-Hill (FHH) method, with D 1 varying between 2.510 and 2.632, and D 2 varying between 2.617 and 2.814. Further investigation indicates that the fractal dimensions exhibit positive correlations with TOC contents, whereas there is no definite relationship observed between fractal dimensions and clay minerals. Meanwhile, the fractal dimensions increase with the increase in specific surface area, and is negatively correlated with the pore size. 1840013-1

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Pore characterization of organic-rich Lower Cambrian shales in Qiannan Depression of Guizhou Province, Southwestern China

Cited by 193 publications

References 58 publications

Quantitative characterization of micropore structure for organic-rich Lower Silurian shale in the Upper Yangtze Platform, South China: Implications for shale gas adsorption capacity

Quantitative characterization of micropore structure for organic-rich Lower Silurian shale in the Upper Yangtze Platform, South China: Implications for shale gas adsorption capacity

Comparison of Three Key Marine Shale Reservoirs in the Southeastern Margin of the Sichuan Basin, SW China

Morphology and Fractal Characterization of Multiscale Pore Structures for Organic-Rich Lacustrine Shale Reservoirs

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