Changes in the pore characteristics of shale during comminution

Li, Jing; Zhou, Shengyang; Fu, Deliang; Li, Yuanju; Ma, Yu; Yang, Ya‐Nan; Li, Chengcheng

doi:10.1177/0144598716656064

Cited by 9 publications

(15 citation statements)

References 30 publications

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“…For this reason, the identification and representation of shale porosity and pore size distribution becomes one of the key parameters for commercial evaluation of shale (Chalmers et al., 2012; Furmann et al., 2014; Loucks et al., 2009; Mastalerz et al., 2013; Milliken et al., 2013; Ross and Bustin, 2009). Domestic and foreign scholars have adopted many qualitative means (including field emission scanning electron microscope (SEM), focused ion beam-SEM and atomic force SEM (Bernard et al., 2012; Zhang et al., 2016; Ji et al, 2016) and quantitative means (including high-pressure mercury intrusion porosimetry, low-temperature N 2 /CO 2 gas adsorption method (Chalmers et al., 2012; Yang et al., 2014), nano-CT scanning and image 3D reconstruction (Bai et al., 2013; Zhang et al., 2016), low-pressure nitrogen adsorption and helium porosity measurements can use to investigate the evolution of shale pore characteristics during comminution (Li et al., 2016)). In general, SEM is used to directly identify the type, shape, and size of pores (Bernard et al., 2012; Chalmers et al., 2012; Curtis et al., 2012; Kelly et al., 2015; Milliken et al., 2013; Tiwari et al., 2013), but it cannot identify mesopore and micropore (Zhang et al., 2015), with poor representativeness when measuring size distribution and geometry of pores (Zhu et al., 2016).…”

Section: Introductionmentioning

confidence: 99%

Pore characteristics and controlling factors of the Lower Cambrian Hetang Formation shale in Northeast Jiangxi, China

Wang

Sang

Zhu

et al. 2017

Energy Exploration & Exploitation

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To identify the microscopic pore characteristics and controlling factors of Hetang Formation Shale in the Lower Yangtze Region, the pore types, pore size distribution characteristics, and controlling factors of the Lower Cambrian Hetang Formation (" 1 h) marine shale in Northeast Jiangxi were analyzed by using low-temperature liquid nitrogen, X-ray diffraction, scanning electron microscope, mercury intrusion porosimetry, isothermal adsorption experiment, and geochemical indicator test system. The research results show that the pore size distribution curve of Hetang Formation Shale is characterized by ''two peaks'' and dominated by micropore (2 nm) and mesopore (47-82 nm). The hysteresis loop shows that the open parallel-plate pore and slit pores are the main pore types in shales. The pore volume of Hetang Formation Shale is only positively related to total organic carbon, without obvious correlation with mineral composition and thermal evolution degree. The controlling factors of pore structure characteristics of Hetang Formation Shale are rather complicated. Further analysis shows that diagenesis and excessive thermal evolution are the two main controlling factors restricting the microscopic pore characteristics. Due to great burial depth, organic matter generates numerous micropores during pyrolysis and hydrocarbon generation, and clay minerals generate a lot of micropores and mesopores during conversion from montmorillonite to illite. On the other hand, the development of mesopore and macropore is far better than that of nanoscale pore, because rigid quartz mineral is the dominant composition of shale and the strong compaction resistance of quartz can increase macropore volume with the increase of shale burial depth. It can be inferred that Hetang

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Section: Introductionmentioning

confidence: 99%

Pore characteristics and controlling factors of the Lower Cambrian Hetang Formation shale in Northeast Jiangxi, China

Wang

Sang

Zhu

et al. 2017

Energy Exploration & Exploitation

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“…Figure shows the NMR-C spectra distribution of the bulk cylindrical shale sample, the PSD from NAM of the pulverized shale sample, and the PSD of the six sub-ROIs from different locations of this bulk sample using PNM. The transverse relaxation time (T2) of NMR-C can be translated into an equivalent pore size, and NMR T2 spectra distributions can also reflect the corresponding PSD. ,, The peaks of PSD from NMR-C and NAM are well matched in Figure A, which shows the NMR-C method has good credibility compared with the common method. However, the total porosity from NAM seems larger than that from NMR-C.…”

Section: Resultsmentioning

confidence: 93%

“…The thermal maturity of the organic matter of the ancient shales in the Sichuan Basin is higher than that of the Barnett, Marcellus, and Haynesville formations in North America, implying a lower degree of development of the pores in the organic matter . Previous studies have indicated that shale pore structure has a strong influence in controlling the shale gas content and storage and transport mechanisms. − In particular, pores in organic matter provide the main storage space for absorbed gas in shale. ,,, Hence, a correct understanding of the 2D and 3D pore structure is the foundation for shale gas exploration, development, and research. , …”

Section: Introductionmentioning

confidence: 99%

“…10,11,2,12 Hence, a correct understanding of the 2D and 3D pore structure is the foundation for shale gas exploration, development, and research. 9,13 As a typical low permeability reservoir, shale is a fine-grained, compact sedimentary rock comprising pores and fractures at a variety of scales. The 2D and 3D pore morphology, size distribution, and other features of shale have been investigated by many imaging methods.…”

Section: Introductionmentioning

confidence: 99%

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Quantitative Analysis of Nanopore Structural Characteristics of Lower Paleozoic Shale, Chongqing (Southwestern China): Combining FIB-SEM and NMR Cryoporometry

et al. 2017

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Characterizing nanopore structure is one of the most important factors in understanding gas storage and transport in shale reservoirs, but remains a significant challenge. In this work, we combine the benefits of Focused Ion Beam Scanning Electron Microscopy (FIB-SEM) and Nuclear Magnetic Resonance Cryoporometry (NMR-C) to characterize the nanopore structure of lower Paleozoic shales from Chongqing, southwestern China. Mineral composition is qualified through X-ray Energy Dispersive Spectroscopy (EDS) and Field-Emission Scanning Electron Microscopy (FE-SEM). Voids in 2D micrographs are classified into types of meso- and/or microfractures, inter particle pores (InterP pores), intraparticle pores (IntraP pores), and pores in organic matter (OM pores). An Otsu thresholding algorithm and an edge detection algorithm (in Avizo) are used to segment OM, InterP, and IntraP pores and to establish 3D pore structure for pore-network modeling (PNM). The pore size distribution (PSD) is measured via PNM and compared to the PSD recovered from NMR-C. Results indicate that the small OM pores have favorable potential for storing adsorbed gas because of their apparent interconnectivity and higher porosity; conversely, InterP and IntraP pores are mostly isolated and with low porosity. The peaks of the PSD, recovered from PNM, are in the ranges 10–20 nm and 60–120 nm and are in good agreement with the peaks of the PSD recovered from NMR-C. This suggests that the NMR signals in these discontinuous ranges are due to OM, InterP, and IntraP pores. This indirectly demonstrates that the probe liquid in the NMR-C experiments (i.e., water) may indeed enter the nanoscale pores in the shale during centrifugal saturation. Comparison of the PSD from PNM and NMR-C also shows that NMR-C has a higher sensitivity and accuracy in detecting nanopores. Combining FIB-SEM and NMR-C is a promising technique in detecting and characterizing the nanoporosity of shales.

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“…The literature shows that other methods can be developed to draw information on the porous media of shales. Among these techniques, we find that the Horvath-Kawazoe method [137] allows users to obtain the distribution of the micropores for slit shape pores [138][139][140]. The method was later modified to work on cylindrical pores as well as on spherical pores [141,142].…”

Section: Other Methodsmentioning

confidence: 99%

Use of Gas Adsorption and Inversion Methods for Shale Pore Structure Characterization

Medina-Rodriguez

Alvarado

2021

Energies

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The analysis of porosity and pore structure of shale rocks has received special attention in the last decades as unconventional reservoir hydrocarbons have become a larger parcel of the oil and gas market. A variety of techniques are available to provide a satisfactory description of these porous media. Some techniques are based on saturating the porous rock with a fluid to probe the pore structure. In this sense, gases have played an important role in porosity and pore structure characterization, particularly for the analysis of pore size and shapes and storage or intake capacity. In this review, we discuss the use of various gases, with emphasis on N2 and CO2, for characterization of shale pore architecture. We describe the state of the art on the related inversion methods for processing the corresponding isotherms and the procedure to obtain surface area and pore-size distribution. The state of the art is based on the collation of publications in the last 10 years. Limitations of the gas adsorption technique and the associated inversion methods as well as the most suitable scenario for its application are presented in this review. Finally, we discuss the future of gas adsorption for shale characterization, which we believe will rely on hybridization with other techniques to overcome some of the limitations.

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Changes in the pore characteristics of shale during comminution

Cited by 9 publications

References 30 publications

Pore characteristics and controlling factors of the Lower Cambrian Hetang Formation shale in Northeast Jiangxi, China

Pore characteristics and controlling factors of the Lower Cambrian Hetang Formation shale in Northeast Jiangxi, China

Quantitative Analysis of Nanopore Structural Characteristics of Lower Paleozoic Shale, Chongqing (Southwestern China): Combining FIB-SEM and NMR Cryoporometry

Use of Gas Adsorption and Inversion Methods for Shale Pore Structure Characterization

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