Microstructural investigation of gas shales in two and three dimensions using nanometer-scale resolution imaging

Curtis, Mark E.; Sondergeld, Carl H.; Ambrose, Raymond; Rai, Chandra

doi:10.1306/08151110188

Cited by 559 publications

(272 citation statements)

References 2 publications

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“…12, 13 and 14. They all have exponential decay trend similar to pore-size distribution presented by (Curtis et al 2012;Chen et al 2013). The results of subsample analysis for Eagle Ford parallel indicated varying range of pore volume distribution.…”

Section: Pore Volume Characterisationsupporting

confidence: 70%

“…We compare our results with other available data estimated using other destructive numerical approaches such as Focus Ion Beam (FIB) milling and Scanning Electron (FIBSEM). The average porosity estimated using our non-destructive micro-CT scanning approach for the Eagle ford parallel was 0.173%, while Curtis et al (2012) and Shabro et al (2014) reported 0.4 and 13.2%, respectively, using destructive FIBSEM approach. These differences in the computed porosities cannot be exclusively attributed to differences in the imaging techniques; as Curtis et al (2012) reported, a porosity of 0.4% calculated from 125 lm 3 3D domain at a resolution of 10 nm, while Shabro et al (2014) reported a porosity of 13.2% for a 4.4 lm 3 domain sample volume at a lower resolution of 6 nm.…”

Section: Analysis Of Computed Porosity and Comparison With Other Methodsmentioning

confidence: 85%

“…These parameters depend on knowing the details of how shape or size grains (Milner et al 2010), pore throats (Curtis et al 2012) and tortuosity (Bai et al 2013;Katsube et al 1991) are distributed. Several studies have reported the complex microstructure of the shale rocks (Curtis et al 2012), heterogeneity of shale rocks (Chen et al 2013) as well as microcracks (Bai et al 2013) without necessarily quantifying the degree of heterogeneity. Extensive research into the effects of particle shape and polydispersity on flow through porous media using synthetic models has shed more light on how pore geometry and complexity of different porous media affect porosity and permeability (Mota et al 2005;Garcia et al 2009).…”

Section: Introductionmentioning

confidence: 99%

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Pore-scale analyses of heterogeneity and representative elementary volume for unconventional shale rocks using statistical tools

Adeleye

Akanji

2017

J Petrol Explor Prod Technol

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A statistical technique for the pore-scale analyses of heterogeneity and representative elemental volume (REV) in unconventional shale rocks is hereby presented. First, core samples were obtained from shale formations. The images were scanned using microcomputed tomography (micro-CT) machine at 6.7 lm resolution with voxels of 990 9 990 9 1000. These were then processed, digitised, thresholded, segmented and features captured using numerical algorithms. This allows the segmentation of each sample into four distinct morphological entities consisting of pores, organic matter, shale grains and minerals. In order to analyse the degree of heterogeneity, Eagle Ford parallel sample was further cropped into 96 subsamples. Descriptive statistical approach was then used to evaluate the existence of heterogeneity within the subsamples. Furthermore, the Eagle Ford parallel and perpendicular samples were analysed for volumetric entities representative of the petrophysical variable, porosity, using corner point cropping technique. The results of porosity REV for Eagle ford parallel and perpendicular indicated sample representation at 300 lm voxel edge. Both pore volume distribution and descriptive statistical analyses suggested that a wide variation of heterogeneity exists at this scale of investigation. Furthermore, this experiment allows for adequate extraction of necessary information and structural parameters for pore-scale modelling and simulation. Additional studies focusing on re-evaluation at higher resolution are recommended.

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Section: Pore Volume Characterisationsupporting

confidence: 70%

Section: Analysis Of Computed Porosity and Comparison With Other Methodsmentioning

confidence: 85%

Section: Introductionmentioning

confidence: 99%

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Pore-scale analyses of heterogeneity and representative elementary volume for unconventional shale rocks using statistical tools

Adeleye

Akanji

2017

J Petrol Explor Prod Technol

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“…The mineral composition of tight reservoir, the composition and properties of fluids (oil, gas, water) and 3D distribution of pore-throat system of tight reservoir can be understood by making full use of various technologies (Loucks et al, 2009;Lau et al, 2012;Curtis et al, 2012. Through the analysis of the mud logging data, logging information and oil production testing data, lower limits and grading evaluation criteria of tight reservoir can be determined using the six methods mentioned below.…”

Section: Lower Limits and Grading Criteria Evaluation Of Tight Reservoirmentioning

confidence: 99%

Lower Limits and Grading Evaluation Criteria of Source Rocks and Reservoirs of Tight Oil and Gas

Huang

et al. 2015

Acta Geologica Sinica - English Edition

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“…By using these imaging methods, it is possible to receive a solid idea of a shale's internal (micro) structure and pore geometry (e.g., [6][7][8][9][10][11]). BIB milling in combination with SEM imaging delivers direct information about pore sizes, their morphology and spatial distribution, rock microstructure, and potential anisotropy as well as core damage due to sample handling (e.g., [3,[12][13][14][15][16][17][18][19][20][21][22][23][24][25]). Additionally, in combination with energy dispersive X-ray spectroscopy (EDX), BIB-SEM enables the identification of individual grains [26,27].…”

Section: Introductionmentioning

confidence: 99%

Using BIB-SEM Imaging for Permeability Prediction in Heterogeneous Shales

et al. 2017

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Organic-rich shale samples from a lacustrine sedimentary sequence of the Newark Basin (New Jersey, USA) are investigated by combining Broad Ion Beam polishing with Scanning Electron Microscopy (BIB-SEM). We model permeability from this 2D data and compare our results with measured petrophysical properties. Three samples with total organic carbon (TOC) contents ranging from 0.7% to 2.9% and permeabilities ranging from 4 to 160 nD are selected. Pore space is imaged at high resolution (at 20,000x magnification) and segmented from representative BIB-SEM maps. Modeled permeabilities, derived using the capillary tube model (CTM) on segmented pores, range from 2.3 nD to 310 nD and are relatively close to measured intrinsic permeabilities. SEM-visible porosities range from 0.1% to 1.8% increasing with TOC, in agreement with our measurements. The CTM predicts permeability correctly within one order of magnitude. The results of this work demonstrate the potential of 2D BIB-SEM for calculating transport properties of heterogeneous shales.

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Microstructural investigation of gas shales in two and three dimensions using nanometer-scale resolution imaging

Cited by 559 publications

References 2 publications

Pore-scale analyses of heterogeneity and representative elementary volume for unconventional shale rocks using statistical tools

Pore-scale analyses of heterogeneity and representative elementary volume for unconventional shale rocks using statistical tools

Lower Limits and Grading Evaluation Criteria of Source Rocks and Reservoirs of Tight Oil and Gas

Using BIB-SEM Imaging for Permeability Prediction in Heterogeneous Shales

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