A review and research on comprehensive characterization of microscopic shale gas reservoir space

Yang, Yong; Liu, Xiaochen; Hui, Zhang; Zhai, Gangyi; Zhang, Jiao-dong; Hu, Zhifang; Bao, Shujing; Zhang, Cong; Wang, Xianghua; Xiao, Yang; Liu, Zheng-zhuang; Xie, Ting; Chen, Juan; Fang, Li-yu; Qin, Lijuan

doi:10.31035/cg2018116

Cited by 6 publications

(9 citation statements)

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“…This wide range presents a challenge to the use of a single measurement method to fully characterize the pore size distribution and pore structure of shale reservoirs . Currently, the pore structure of shale reservoirs is primarily examined through imaging and quantitative tests. − The main imaging methods include high-resolution focused ion beam scanning electron microscopy (FIB–SEM), transmission electron microscopy, atomic force microscopy (AFM), small-angle X-ray scattering, and nanocomputed tomography (CT). − FIB–SEM, known for its high-resolution capabilities, can be used to image nanopores and is primarily employed in two-dimensional (2D) observations. , High-resolution CT can be used for nondestructive scanning and three-dimensional (3D) reconstruction of nanopores in samples. However, CT scans over a wide field of view have low accuracy due to instrument limitations .…”

Section: Microstructural Characterization Tecniques For Shale Reservoirsmentioning

confidence: 99%

“…High-pressure mercury intrusion porosimetry (MIP), low-temperature nitrogen (N 2 ) adsorption, carbon dioxide (CO 2 ) adsorption, and nuclear magnetic resonance (NMR) are among the techniques commonly used to quantify pore-size distribution. ,− MIP involves the injection of mercury into pores under a high pressure up to 350 MPa and has a 3.7 nm (pore radius) detection precision. However, the saturation of mercury injected into a shale sample is generally low, and the high pressure required for the process can deform and damage the pores .…”

Section: Microstructural Characterization Tecniques For Shale Reservoirsmentioning

confidence: 99%

“…Full-range pore-size distribution curves were generated by combining the quantitative measurements obtained using the high-pressure MIP, low-temperature N 2 adsorption, and CO 2 adsorption techniques. Pores smaller than 2 nm, 2–50 nm, and larger than 50 nm in diameter were measured using the CO 2 adsorption, low-temperature N 2 adsorption, and high-pressure MIP techniques, respectively. , Analysis of the full-range pore-size curves (Figure ) reveals that the pores in the shale in this well primarily consist of mesopores (2–50 nm in diameter, 51.85–73.08% average: 63%) and, to a smaller extent, micropores (<2 nm in diameter, 11.9–25.3%, average: 15%).…”

Section: Microstructural Characterization Tecniques For Shale Reservoirsmentioning

confidence: 99%

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Multiple Gas Seepage Mechanisms and Production Development Research for Shale Gas Reservoirs from Experimental Techniques and Theoretical Models

Duan

Chang

et al. 2023

ACS Omega

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Shale gas seepage theory provides a scientific basis for dynamically analyzing the physical gas flow processes involved in shale gas extraction and for estimating shale gas production. Conventional experimental techniques and theoretical methods applied in seepage research are unable to accurately illustrate shale gas mass transfer processes at the micro-and nanoscale. In view of these scientific issues, the knowledge of seepage mechanisms and production development design was improved from the perspective of experimental techniques and theoretical models in the paper. First, multiple techniques (e.g., focused ion beam scanning electron microscopy and a combination of mercury intrusion porosimetry and adsorption measurement techniques) were integrated to characterize the micro-and nanopore distribution in shales. Then, molecular dynamics simulations were carried out to analyze the microscale distribution of gas molecules in nanopores. In addition, an upscaled gas flow model for the shale matrix was developed based on molecular dynamics simulations. Finally, the coupled flow and productivity models were set up according to a long-term production physical simulation to identify the production patterns for adsorbed and free gas. The research results show that micropores (diameter: <2 nm) and mesopores (diameter: 2−50 nm) account for more than 70% of all the pores in shales and that they are the primary space hosting adsorbed gas. Molecular simulations reveal that microscopic adsorption layers in organic matter nanopores can be as thick as 0.7 nm and that desorption and diffusion are the main mechanisms behind the migration of gas molecules. An apparent permeability model that comprehensively accounts for adsorption, diffusion, and seepage was developed to address the deficiency of Darcy's law in characterizing gas flowability in shale reservoirs. The productivity model results for a certain gas well show that the production in the first three years accounts for more than 50% of its estimated ultimate recovery and that adsorbed gas contributes more to the annual production than free gas in the eighth year. These research results provide theoretical and technical support for improving the theoretical understanding of shale gas seepage and optimizing shale gas extraction techniques in China.

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Section: Microstructural Characterization Tecniques For Shale Reservoirsmentioning

confidence: 99%

Section: Microstructural Characterization Tecniques For Shale Reservoirsmentioning

confidence: 99%

Section: Microstructural Characterization Tecniques For Shale Reservoirsmentioning

confidence: 99%

See 1 more Smart Citation

Multiple Gas Seepage Mechanisms and Production Development Research for Shale Gas Reservoirs from Experimental Techniques and Theoretical Models

Duan

Chang

et al. 2023

ACS Omega

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“…Owing to the complex properties of reservoirs, it is difficult to predict and develop large‐scale oil and gas resources. The lithofacies types and micropore characteristics of shale are closely related to the formation, migration, and storage of shale gas (Ko et al, 2016; Z. Li, Song, et al, 2021; M. Li, Tan, et al, 2021; Liu et al, 2020; Lu et al, 2015; Pommer & Milliken, 2015; P. Wang et al, 2018; J. Zhang, Li, et al, 2015; Q. Zhang, Liu, et al, 2015; P. Zhao et al, 2021). The study of shale lithofacies has important theoretical and practical significance for reflecting the heterogeneity of fine‐grained sedimentary rocks, restoring the palaeogeographic environment, and guiding the exploration of oil and gas.…”

Section: Introductionmentioning

confidence: 99%

“…The lithofacies influence the micro‐ reservoir characteristics, which further influence the prediction of favourable reservoirs and the development plan of shale gas (Asante‐Okyere et al, 2021; Chalmers et al, 2009; S. Chen et al, 2016; L. Chen et al, 2018; Curtis, Cardott, et al, 2012; Curtis, Sondergeld, et al, 2012; Zou et al, 2011). At present, there are many reports on the shale of the Longmaxi and Wufeng formations in the Sichuan Basin, China (Guo et al, 2016; C. Liang et al, 2012; Sun et al, 2016; Y. Wang et al, 2016; Z. Wang, Chen, & Chen, 2020; H. Wang, Shi, et al, 2020; Xiao, 2010; Xu et al, 2021; Q. Zhang et al, 2016; J. Zhang, Li, et al, 2015; Q. Zhang, Liu, et al, 2015; J. Zhao et al, 2016), while the shale gas exploration in the Western Hunan‐Hubei Region is still in the preliminary evaluation stage. The Middle Yangtze Region of China has a great potential for shale gas exploration, and several sets of source rocks are developed in the Doushantuo, Niutitang, Longmaxi, and Ziliujing formations (X. Chen et al, 2015; K. Li et al, 2016; L. Liang et al, 2009; Mei et al, 2010; Nie et al, 2018; Qiu et al, 2013; J. Wang & Wang, 2021).…”

Section: Introductionmentioning

confidence: 99%

Pore structure characteristics of different lithofacies of the Longmaxi shale, Western Hunan‐Hubei Region, China: Implications for reservoir quality prediction

et al. 2023

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Lithofacies and micropore characteristics of shale reservoir directly affect the exploration and development of natural gas. To determine the development potential of shales of the Longmaxi Formation in the Western Hunan‐Hubei Region, the lithofacies types and micropore structure characteristics of the Longmaxi Formation shales have been systematically studied in this paper, based on ordinary thin sections, argon ion polishing–scanning electron microscopy, physical property testing, x‐ray diffraction whole‐rock and clay mineral analysis, isothermal nitrogen, and carbon dioxide adsorptions. According to the principle of ‘laminar structure + total organic carbon (TOC) + mineral composition of felsic, clay, and carbonate minerals’, eight types of shale lithofacies were identified. The effective porosity of the Longmaxi shale ranges from 1.8% to 14.4%, with a peak range from 3% to 6%, while the permeability ranges from 0.001 to 1.27 mD, with an average of 0.106 mD. Combined with the isothermal adsorption experiments, the proportion of mesopores is the largest in the Longmaxi shale, followed by macropores and micropores. Moreover, the pore diameters of mesopores are concentrated between 3 and 10 nm, while those of micropores are concentrated between 0.4 and 0.9 nm. The pore volume of shale is most developed when the content of brittle felsic minerals is 50% ~ 75% and the content of clay minerals is 25% ~ 50%, and the TOC content is positively correlated with the pore volume and specific surface area. There are significant differences in the pore development characteristics of different lithofacies. The shale reservoir space analysis indicates that micropores are controlled by TOC content and clay minerals, while the macropores are controlled by depositional intergranular pores, TOC content, and felsic content, as well as diagenetic pyrite mould pores, microfractures pores, and intercrystalline pores. On the other hand, mesopores are related to a mix of depositional and diagenetic factors with dominant contribution of intergranular pores, intercrystalline pores, organic pores, and intergranular shrinkage fractures pores. It is found that the pore development of massive organic‐rich siliceous shale lithofacies has the best reservoir quality, including well‐connected intergranular pores, intercrystalline pores, organic pores, and shrinkage fractures. Therefore, the massive organic‐rich siliceous shale lithofacies is the dominant fine‐grained reservoir lithofacies in the studied area. Based on understating the pore characteristics of different lithofacies, this study can provide a scientific basis for the prediction of favourable sweet spots of shale gas reservoir in the Longmaxi Formation, western Hunan‐Hubei Region.

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Characterization and classification of the microporosity in the unconventional carbonate reservoirs: A case study from Hanifa Formation, Jafurah Basin, Saudi Arabia

Abouelresh

Mahmoud

Radwan

et al. 2022

Marine and Petroleum Geology

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A review and research on comprehensive characterization of microscopic shale gas reservoir space

Cited by 6 publications

References 0 publications

Multiple Gas Seepage Mechanisms and Production Development Research for Shale Gas Reservoirs from Experimental Techniques and Theoretical Models

Multiple Gas Seepage Mechanisms and Production Development Research for Shale Gas Reservoirs from Experimental Techniques and Theoretical Models

Pore structure characteristics of different lithofacies of the Longmaxi shale, Western Hunan‐Hubei Region, China: Implications for reservoir quality prediction

Characterization and classification of the microporosity in the unconventional carbonate reservoirs: A case study from Hanifa Formation, Jafurah Basin, Saudi Arabia

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