Experimental study of fluid transport processes in the matrix system of the European organic-rich shales: II. Posidonia Shale (Lower Toarcian, northern Germany)

Ghanizadeh, Amin; Amann-Hildenbrand, Alexandra; Gašparík, Matúš; Gensterblum, Yves; Krooß, Bernhard M.; Littke, Ralf

doi:10.1016/j.coal.2013.06.009

Cited by 209 publications

(116 citation statements)

References 74 publications

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“…This compares fairly well with the TOC results from Kaufhold et al (2016) (WIC 8.5 wt % TOC and HAD 5.2 wt %). The decrease in TOC is also confirmed by Gasparik et al (2014), Ghanizadeh et al (2014), Mohnhoff et al (2015) and Mathia et al (2016).…”

Section: Organic Mattersupporting

confidence: 51%

“…Recent data on the porosity, permeability and total organic carbon determination of Posidonia shale samples are compiled in Table 1. The total porosities are reported by Gasparik et al (2014), Rexer et al (2014), Ghanizadeh et al (2014), Mohnhoff et al (2015), , Klaver et al (2012Klaver et al ( , 2016 and Mathia et al (2016) vary between 9.8-17.8 % for WIC and 9.3-16 % for HAD. All studies reported consistently that the total porosity decreases from a maximum in the early mature sample WIC to a minimum in oil mature material to than rise again to an intermediate level in overmature gas window samples (HAD).…”

Section: Introductionmentioning

confidence: 99%

“…Observed image porosities (0.2-3.0 %) were significantly lower due to a lack of resolution. Helium flow-through experiments were conducted by Ghanizadeh et al (2014) and Mohnhoff et al (2015) to determine permeability coefficients in the range of 0.3-26 × 10 −20 m 2 for WIC and HAD. Goal of this study is to better understand the porosity, permeability and pore network development in shales us-ing FIB-SEM.…”

Section: Introductionmentioning

confidence: 99%

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Porosity and permeability determination of organic-rich Posidonia shales based on 3-D analyses by FIB-SEM microscopy

et al. 2016

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Abstract. The goal of this study is to better understand the porosity and permeability in shales to improve modelling fluid and gas flow related to shale diagenesis. Two samples (WIC and HAD) were investigated, both mid-Jurassic organic-rich Posidonia shales from Hils area, central Germany of different maturity (WIC R 0 0.53 % and HAD R 0 1.45 %). The method for image collection was focused ion beam (FIB) microscopy coupled with scanning electron microscopy (SEM). For image and data analysis Avizo and GeoDict was used. Porosity was calculated from segmented 3-D FIB based images and permeability was simulated by a Navier Stokes-Brinkman solver in the segmented images.Results show that the quantity and distribution of pore clusters and pores (≥ 40 nm) are similar. The largest pores are located within carbonates and clay minerals, whereas the smallest pores are within the matured organic matter. Orientation of the pores calculated as pore paths showed minor directional differences between the samples. Both samples have no continuous connectivity of pore clusters along the axes in the x, y, and z direction on the scale of 10 to 20 of micrometer, but do show connectivity on the micrometer scale. The volume of organic matter in the studied volume is representative of the total organic carbon (TOC) in the samples. Organic matter does show axis connectivity in the x, y, and z directions. With increasing maturity the porosity in organic matter increases from close to 0 to more than 5 %. These pores are small and in the large organic particles have little connection to the mineral matrix. Continuous pore size distributions are compared with mercury intrusion porosimetry (MIP) data. Differences between both methods are caused by resolution limits of the FIB-SEM and by the development of small pores during the maturation of the organic matter. Calculations show no permeability when only considering visible pores due to the lack of axis connectivity. Adding the organic matter with a background permeability of 1×10 −21 m 2 to the calculations, the total permeability increased by up to 1 order of magnitude for the low mature and decreases slightly for the overmature sample from the gas window. Anisotropy of permeability was observed. Permeability coefficients increase by 1 order of magnitude if simulations are performed parallel to the bedding. Our results compare well with experimental data from the literature suggesting that upscaling may be possible in the future as soon as maturity dependent organic matter permeability coefficients can be determined.

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Section: Organic Mattersupporting

confidence: 51%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Porosity and permeability determination of organic-rich Posidonia shales based on 3-D analyses by FIB-SEM microscopy

et al. 2016

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“…Previous experiments showed that the permeability decrease in an exponential form with the increase in the effective stress (Mckee et al, 1988;Reyes et al, 2002;Chalmers et al, 2012;Ghanizadeh et al, 2014a;2014b;Chen et al, 2015;Zhang et al, 2015a;2015b;. Change of rock effective stress can be caused by internal pressure (i.e., gas pressure) and external pressure (i.e., confining stress) variations.…”

Section: Effective Stressmentioning

confidence: 99%

Insights on the gas permeability change in porous shale

Chen

Xu³

et al. 2017

Adv. Geo-Energ. Res.

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Due to abundant nanoscale pores developed in shale, gas flow in shale presents a complex dynamic process. This paper summarized the effects from effective stress increase, shale matrix shrinkage, gas slippage and Knudsen diffusion on the gas permeability change in shale during shale gas recovery. With the reduce in gas pressure, effective stress increase leads to the decline of the permeability in an exponential form; the permeability increases due to the shale matrix shrinkage induced by gas desorption; appearances of gas slippage and Knudsen diffusion cause an additional increase in the gas permeability particularly in small pores at low pressures. In addition, some reported models evaluating the shale permeability were reviewed preliminarily. Models considering these four effects may be potentially effective to evaluate the gas permeability change in shale.

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“…Thus, permeability is a function of effective stress. Many researchers have reported that shale permeability decreases with increasing effective stress [6][7][8][9][10]. In this work, the stress-dependent permeability was determined by measuring the permeability of the samples over a range of effective stresses.…”

Section: (A) Pressure Pulse Decay Techniquementioning

confidence: 99%

Effects of rock mineralogy and pore structure on stress-dependent permeability of shale samples

Ismail¹,

Zoback²

2016

Phil. Trans. R. Soc. A.

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We conducted pulse-decay permeability experiments on Utica and Permian shale samples to investigate the effect of rock mineralogy and pore structure on the transport mechanisms using a non-adsorbing gas (argon). The mineralogy of the shale samples varied from clay rich to calcite rich (i.e. clay poor). Our permeability measurements and scanning electron microscopy images revealed that the permeability of the shale samples whose pores resided in the kerogen positively correlated with organic content. Our results showed that the absolute value of permeability was not affected by the mineral composition of the shale samples. Additionally, our results indicated that clay content played a significant role in the stressdependent permeability. For clay-rich samples, we observed higher pore throat compressibility, which led to higher permeability reduction at increasing effective stress than with calcite-rich samples. Our findings highlight the importance of considering permeability to be stress dependent to achieve more accurate reservoir simulations especially for clay-rich shale reservoirs.This article is part of the themed issue 'Energy and the subsurface'.

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Experimental study of fluid transport processes in the matrix system of the European organic-rich shales: II. Posidonia Shale (Lower Toarcian, northern Germany)

Cited by 209 publications

References 74 publications

Porosity and permeability determination of organic-rich Posidonia shales based on 3-D analyses by FIB-SEM microscopy

Porosity and permeability determination of organic-rich Posidonia shales based on 3-D analyses by FIB-SEM microscopy

Insights on the gas permeability change in porous shale

Effects of rock mineralogy and pore structure on stress-dependent permeability of shale samples

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