Modeling adsorption–desorption hysteresis in shales: Acyclic pore model

Zapata, Yuliana; Sakhaee‐Pour, A.

doi:10.1016/j.fuel.2016.05.002

Cited by 26 publications

(6 citation statements)

References 31 publications

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“…However, lognormal [30,31], Weibull [32,33], or mixed Gaussian [34] distribution might be a more accurate representation in some porous media. There are also some rocks whose porethroat size distributions do not conform to any type of probability density functions [35][36][37][38][39]. In addition, Eq.…”

Section: Objectivesmentioning

confidence: 99%

Scale-dependent permeability and formation factor in porous media: Applications of percolation theory

Esmaeilpour

Ghanbarian

Liang

et al. 2021

Fuel

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Section: Objectivesmentioning

confidence: 99%

Scale-dependent permeability and formation factor in porous media: Applications of percolation theory

Esmaeilpour

Ghanbarian

Liang

et al. 2021

Fuel

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“…In addition, if there are many large-sized pores (>6 nm), the adsorption amount would significantly increase when the P/P0 > 0.9 (Figures 5 and 7). At this pressure stage, N2 condensation begins and the adsorption amount is controlled by the [37,38,45]. Adapted with permission from Ref.…”

Section: Experimental Adsorption and Desorption Isothermsmentioning

confidence: 99%

“…In addition, when studying the pore system of shale, the pore connectivity and gas phase state in the pore space are also important [36]. In order to systematically analyze the pore structure of shale, molecular simulations are used to help analyze the N 2 adsorption/desorption isotherms to obtain the pore structure in shale [37,38].…”

Section: Introductionmentioning

confidence: 99%

Pore Structure in Shale Tested by Low Pressure N2 Adsorption Experiments: Mechanism, Geological Control and Application

et al. 2022

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The N2 adsorption experiment is one of the most important methods for characterizing the pore structure of shale, as it covers the major pore size range present in such sediments. The goal of this work is to better understand both the mechanisms and application of low-pressure nitrogen adsorption experiments in pore structure characterization. To achieve this, the N2 adsorption molecular simulation method, low-pressure N2 adsorption experiments, total organic carbon (TOC) analysis, X-ray diffraction (XRD) analysis, scanning electron microscopy (SEM), and a total of 196 shale samples from the Wufeng–Longmaxi formations in the Sichuan basin have been employed in this study. Based on the analytical data and the simulations, two parameters, the connectivity index and the large pore volume index, are proposed. These parameters are defined as the connectivity of the pore system and the volume of large nanopores (>10 nm) respectively, and they are calculated based on the N2 adsorption and desorption isotherms. The experimental results showed that TOC content and clay minerals are the key factors controlling surface area and pore volume. However, in different shale wells and different substrata (divided based on graptolite zonation), the relative influences of TOC content and clay minerals on pore structure differ. In three of the six wells, TOC content is the key factor controlling surface area and pore volume. In contrast, clay minerals in samples from the W202 well are the key factors controlling pore volume, and with an increase in the clay mineral content, the pore volume increases linearly. When the carbonate content exceeds 50%, the pore volume decreases with an increase in carbonate content, and this may be because in the diagenetic process, carbonate cement fills the pores. It is also found that with increasing TOC content the connectivity index increases and SEM images also illustrate that organic pores have better connectivity. Furthermore, the connectivity index increases as quartz content increases. The large pore volume index increases with quartz content from 0 to 40% and decreases as quartz increases from 40% to 100%. By comparing the pore structure of shale in the same substrata of different shale gas wells, it was found that tectonic location significantly affects the surface area and pore volume of shale samples. The shale samples from wells that are located in broad tectonic zones, far from large-scale faults and overpressure zones, have larger pore volumes and surface areas. On the contrary, the shale samples from shale gas wells that are located in the anticline region with strong tectonic extrusion zones or near large-scale faults have relatively low pore volumes and surface areas. By employing large numbers of shale samples and analyzing N2 adsorption mechanism in shale, this study has expanded the application of N2 adsorption experiment in shale and clarifies the effects of sedimentary factors and tectonic factors on pore structure.

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“…Zapata et al and Yang et al obtained nitrogen adsorption isotherms by studying nitrogen adsorption isotherms. The influence of the properties of adsorbents and adsorbates was discussed [14,15]. Keluo et al described the relationship between the surface area, the pore volume, and the pore type by analyzing the nitrogen adsorption capacity [16].…”

Section: Introductionmentioning

confidence: 99%

Study on Pore Structure of Shale Reservoir by Low Temperature Nitrogen Adsorption Method

Guo

2022

Geofluids

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Shale gas is one of the most actively explored unconventional sources of natural gas. There are several types of pores in the shale reservoir, and their structural characteristics are complex. Evaluating the characteristics of the shale pore structure is the basis for understanding the shale reservoir performance and the oil and gas migration mechanism. In this paper, the micro- and nanopores of shale samples from the Yanchang Formation, Hunan basin, are studied by applying the low-temperature nitrogen adsorption method. Several pore structure parameters such as the specific surface area, the pore volume, and the pore size distribution of the analyzed samples are calculated. The predominant characteristics of nanopores that influence hydrocarbon accumulation and control the development of pores are discussed. The results indicate that the shale reservoir rocks from the study area are mainly mesoporous with an average pore size distribution between 2 and 50 nm. A small number of micropores (less than 2 nm) and macropores (more than 50 nm) are also present in the pore network. The development of micropores and mesopores in the shale samples is associated with organic matter content, while the development of macropores is linked to clay minerals content. Total organic carbon (TOC) content is the key element to control the nanopore volume and the specific surface area of the reservoir rocks from the study area. At the same time, the organic matter-enriched pore network also provides extensive space for the accumulation of shale gas.

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Modeling adsorption–desorption hysteresis in shales: Acyclic pore model

Cited by 26 publications

References 31 publications

Scale-dependent permeability and formation factor in porous media: Applications of percolation theory

Scale-dependent permeability and formation factor in porous media: Applications of percolation theory

Pore Structure in Shale Tested by Low Pressure N2 Adsorption Experiments: Mechanism, Geological Control and Application

Study on Pore Structure of Shale Reservoir by Low Temperature Nitrogen Adsorption Method

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