Distribution of sorbed water in the pore network of mudstones assessed from physisorption measurements

Lahn, Leopold; Bertier, Pieter; Seemann, Timo; Stanjek, Helge

doi:10.1016/j.micromeso.2019.109902

Cited by 25 publications

(10 citation statements)

References 44 publications

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“…Water adsorption isotherms of shales are sample‐dependent because of the variations in mineralogical composition, pore structure, and surface chemistry (Seemann et al., 2017; Lahn et al., 2020). The U. Ordovician shale, which is rich in clay minerals, has higher water uptake than the L. Silurian shale.…”

Section: Resultsmentioning

confidence: 99%

“…For other measurements, trimmed materials were used. Details about the methodology of the XRD, TOC analysis, and helium pycnometry can be found in previous publications (Gasparik et al., 2014; Lahn et al., 2020; Seemann et al., 2017), while Bertier et al. (2016) provides an in‐depth analysis of the physisorption measurement and data interpretation of isotherms of shales.…”

Section: Materials and Experimental Methodsmentioning

confidence: 99%

“…Water vapor sorption experiments have been employed to investigate the relationship between the sorption amounts and pore structure characteristic of shales (Busch et al., 2017; Lahn et al., 2020; Sang et al., 2018; Seemann et al., 2017). However, it is difficult to determine a consistent conclusion about this.…”

Section: Introductionmentioning

confidence: 99%

“…Pore structure parameters determined using low‐pressure gas adsorption are either larger or smaller than those determined from the water sorption method (Seemann et al., 2017). These are ascribed to the effects of surface chemistry and hydration mechanisms in the water sorption of shales (Lahn et al., 2020; Sang et al., 2018; Seemann et al., 2017). The behavior of water in shales is quite different from that of nonpolar gases (CH 4 , N 2 , and Ar).…”

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

Water Sorption and Transport in Shales: An Experimental and Simulation Study

Yang

Lyu

2021

Water Resources Research

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Understanding water uptake and drainage in shales has important implications for both hydrocarbon extraction and hydraulic fracturing fluid disposal. This study reports gravimetric water sorption isotherms and kinetics of water transport in shales. Moisture mass transport profiles during water uptake and drainage processes were numerically simulated. Quantitative parameters characterizing the water transport properties were calculated and their dependences on water saturation were analyzed. An approach was proposed to evaluate the permeability of shales using dynamic water sorption. The reliability of the estimated results was verified by the experimental values using gas permeability measurements.The apparent diffusion coefficients of water sorption on shales were found to be between 1.0 × 10−12 and 1.5 × 10−11 m2/s. The apparent diffusion coefficient first increases with water saturation and remains stable at a moderately saturated condition. However, this coefficient decreases for shales with high water saturation. Apparent diffusion coefficients for the sorption process are almost equal to those for the desorption process, except at the moderate saturation condition. Liquid water (including adsorbed water) contributes more than 80% to the water transport, whereas water vapor mainly contributes to shales with low water saturation. The liquid water permeability determined by water sorption is consistent with the crushed‐rock permeability measured by gas expansion. A further reasonable agreement is achieved between the analytical gas permeability, as a function of water saturation, and the experimental gas phase permeability. Water sorption kinetics provide an indirect method for assessing the water transport properties as a function of water saturation when direct measurements are not available.

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Section: Resultsmentioning

confidence: 99%

Section: Materials and Experimental Methodsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Water Sorption and Transport in Shales: An Experimental and Simulation Study

Yang

Lyu

2021

Water Resources Research

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“…Mudstone accounts for approximately two-thirds of sedimentary rocks and is widely distributed in underground strata. , Mudstone can not only act as a shale gas reservoir but also as a source and seal for oil . However, because of its low porosity and intrinsic permeability, mudstone can only retain formation water, and only when the mudstone layer is a hydrocarbon source stratum, some oil and gas can be preserved. , In the field of petroleum engineering, mudstone usually appears as a caprock, whose main function is to prevent volatile petroleum from escaping .…”

Section: Introductionmentioning

confidence: 99%

Effect of the Physicochemical Structure of Mudstone on Readsorption Behavior of Water

et al. 2020

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Mudstone can store formation water when acting as a caprock, which is a part of water sources in early oil exploitation. To improve crude oil quality, it is necessary to understand readsorption behavior of water. The behavior of water is closely related to the physicochemical structure of mudstone. Interactions between water and chemical structures are hard to detect because of the overlap of O−H infrared vibration bands (IR) in H 2 O and that in mudstone, thus D 2 O was innovatively used to interact with mudstone. In this study, mineral compositions and pore structures of mudstone were identified by X-ray diffraction, Xray fluorescence, and low-temperature N 2 adsorption/desorption, respectively. Furthermore, water retention contents at different relative humidities (RH) were investigated by comparing hysteresis loop areas at low (S 1 ) and high (S 2 ) RH based on water adsorption/desorption isotherms. Interactions between water and mudstone were investigated by studying the IR spectra changes and release of D, HD, OD, and HOD during drying of mudstones containing adsorbed D 2 O using in situ diffuse reflectance infrared Fourier transform (DRIFT) spectroscopy and thermogravimetric coupled with mass spectrometry (TG-MS), respectively. The results showed that the specific surface area (S BET ) and mineral compositions controlled S 1 , while S 2 was related to capillary pore volume. The detection of OD and HOD by in situ DRIFT at 300 °C and by TG-MS at 450 °C manifested that hydrogen bonds were formed between water and mudstone. Based on this study, we suggested that production wells should be constructed as far as possible on top of mudstone caprocks with relatively lower pore volumes and higher kaolinite contents to improve crude oil quality in early exploitation.

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