Characterization of shale pore system: A case study of Paleogene Xin'gouzui Formation in the Jianghan basin, China

Zhang, Pengfei; Lu, Shuangfang; Li, Junqian; Xue, Haitao; Li, Wenhao; Zhang, Ping

doi:10.1016/j.marpetgeo.2016.10.014

Cited by 107 publications

(79 citation statements)

References 31 publications

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“…Fractures in Barnett and Woodford shales occur at a variety of scales (Gale & Holder, ; Gale, Reed, & Holder, ; Portas, ; Slatt, ) and are significant in any general investigation of shale properties, particularly those related to well‐drilling and artificial fracture treatment. The microfractures are also well developed in continental shales (J. J. Li, Wang, et al, ; J. J. Li, Yin, et al, ; P. F. Wang et al, ; M. Wang, Sherwood, et al, ; M. Wang, Wilkins, et al, ; M. Wang, Xue, et al, ; P. F. Zhang et al, ). In the SDT, the microfractures in the Jurassic shale can be divided into diagenetic microfractures and structural microfractures according to the cause of formation.…”

Section: Resultsmentioning

confidence: 97%

“…The pores can exist both in the skeletons of clay minerals and in large deposits of mineral crystals (Desbois, Urai, & Kukla, ). The scanning electron microscopy results illustrate that many clastic particles (e.g., quartz and feldspar) with both regular and irregular shapes are packaged between the sheet and plate clay minerals of the mud shale samples; these clastic particles can form pores and combine with the surrounding clay minerals (Figure a; J. J. Li, Yin, et al, ; Takehiko, Osamu, & Toshiro, ; P. F. Wang et al, ; P. F. Zhang et al, ). The diameters of these pores are larger and can reach the micron scale.…”

Section: Resultsmentioning

confidence: 98%

“…The content of brittle minerals, particularly quartz, indicates the fracability or brittleness of shale. As the shale itself is rock with a low permeability, it needs to be artificially fractured before an industrial gas rate can be obtained; fracturing shale is easier when the content of brittle minerals is higher (Jarvie, Hill, Ruble, & Pollastro, ; Ross & Bustin, , ; M. Wang, Sherwood, et al, ; M. Wang, Wilkins, et al, ; P. F. Zhang et al, ). Comparing the quartz content of the Jurassic shale of the SDT with that of Barnett Shale in the USA (with a quartz content of about 4.0–58.6%, and a mean of 39.2%; Jarvie et al, ) and the shale of the Longmaxi Formation in the Sichuan Basin, China (with a quartz content of about 19.4–81.1%, and a mean of 32.2%; S. B. Chen et al, ), shows that it is much higher and has a high potential to be artificially fractured.…”

Section: Resultsmentioning

confidence: 99%

“…OM pores are intrapores found within OM. The thermal maturation must reach an R o level of approximately 0.6% or higher before OM pores begin to develop (J. J. Li, Yin, et al, ; Robert, Robert, Stephen, & Ursula, ; P. F. Wang et al, ; M. Wang, Sherwood, et al, ; M. Wang, Wilkins, et al, ; P. F. Zhang et al, ), which, according to Dow (), is the beginning of peak oil generation. At levels of maturity less than 0.6% R o , OM pores are absent or extremely rare (Robert et al, ).…”

Section: Resultsmentioning

confidence: 99%

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Geochemical and geological characteristics of the Jurassic continental black shale in the Southwestern Depression of Tarim Basin

Jiang

Liu

et al. 2018

Geological Journal

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Although Jurassic continental black shale within the Southwestern Depression of Tarim Basin (SDT) have received renewed attention during the past few years due to their potential to be prospected for shale gas, studies on shale characteristics remain rare. In this study, 31 black shale core samples were collected from a well (Buya‐1) drilled recently in the Hetian Sag of the southern SDT, and their geochemical, petrographical, mineralogical, petrophysical, and pore structural characteristics were determined through a series of tests. The results indicate that the black shale has high and variable total organic carbon (TOC) contents ranging between 0.1% and 17.0% (average 3.2%), is dominated by Type III kerogen (gas‐prone), and is in a mature to high‐mature stage. The shale is mainly composed of quartz, clay, and feldspar with mean contents of 40.0% (range = 15.0–72.0%), 51.0% (range = 25–77%), and 5.5% (range = 1–13.0%), respectively. The pore spaces are composed of primary pores, secondary pores, and microfractures. The mean sorbed gas content of the shale is approximately 2.4 m3/t, and the TOC is significantly positively and linearly correlated with the adsorbed gas capacity. The results show that the Jurassic continental shale in the SDT is very favourable for the formation of a large shale gas play, and the middle segment of the Jurassic shale is the most favourable target layer for shale gas exploration due to its greater gas generation capacity, higher mineralogical brittleness, larger gas storage space, and greater gas sorption capacity. This study is significant in guiding subsequent shale gas exploration and development in the Jurassic, SDT, and also is a reference for identifying favourable exploration targets of shale gas resource in other continental basins.

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Section: Resultsmentioning

confidence: 97%

Section: Resultsmentioning

confidence: 98%

Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

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Geochemical and geological characteristics of the Jurassic continental black shale in the Southwestern Depression of Tarim Basin

Jiang

Liu

et al. 2018

Geological Journal

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“…5,6 In recent years, shale gas developments have played an important role in China and received increasing interest in some other countries. [7][8][9][10] In drilling engineering, shale instability has always been a challenging and costly issue. [11][12][13] Drilling shale formations with traditional WDFs may lead to series problems, such as wellbore collapse, tight holes, stuck pipes, and lost circulation.…”

Section: Introductionmentioning

confidence: 99%

A polymer microsphere emulsion as a high-performance shale stabilizer for water-based drilling fluids

Qiu

Zhao

et al. 2018

RSC Adv.

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Interest in using nanomaterials to improve shale stability during drilling operations has been increasing.Herein, a polymer microsphere emulsion (PME) as a high-performance shale stabilizer for water-based drilling fluids (WDFs) was prepared via emulsion polymerization. The particle sizes in PME in aqueous solution ranged from 90 to 320 nm. PME was found to exhibit excellent salt tolerance and temperature resistance. The plugging performance of PME was tested through pressure transmission tests. The results indicated that the polymer microspheres in PME could effectively plug shale pores and reduce shale permeability. In addition, rolling recovery tests were used to evaluate the shale hydration inhibition performance of PME. It was found that PME showed great performance for decreasing shale hydration potential. These factors make PME a promising shale stabilizer for WDFs used to drill shale formations.

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Effect of pore structure on oil‐bearing property in the third member of Paleogene Funing Formation in Subei Basin, East China

Liu

Xie

Shu

et al. 2020

Energy Science & Engineering

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Mercury injection capillary pressure (MICP) tests, nuclear magnetic resonance (NMR), (fluorescence) thin section, X-ray diffraction (XRD), and scanning electron microscope (SEM) analyses were used to describe the size and distribution of entire pore-throat structures in the sandstones of the E 1 f 3 (the third member of Paleogene Funing Formation) in the Subei Basin. The lithologies of E 1 f 3 in the Subei Basin are mainly dark-gray, very fine-grained sandstones and siltstones, interbedded with dark mudstones. The pore systems predominantly feature secondary intergranular and intragranular dissolution pores, micropores coexisting with minor amounts of intergranular pores, and microfractures. The high threshold pressure and bulk volume of irreducible fluids values and the significant variation in the NMR and MICP parameters indicate that the E 1 f 3 reservoirs are characterized by complex and heterogeneous microscopic pore structures. Microscopic pore-throat parameters are linked with macroscopic properties through the reservoir quality index (RQI). The NMR T 2 (transverse time relaxation) spectrum is unimodal or bimodal but with weak right peaks, indicating the rarity of large intergranular pores. However, large-scale pore throats, though only account for a minor part of the total pore volume, significantly contribute to the total permeability. The abundance of small-scale pore-throat systems (short T 2 components) results in high irreducible water content. Therefore, the oil saturation in E 1 f 3 sandstones is low, and the pore structure, especially the number of micropores, determines the oil-bearing property. Oil primarily occurs in the intragranular dissolution pores with minor amounts occurring in the large intergranular pores. Most of the micropores are bound by capillary water. The sandstones with chlorite clay minerals tend to be oil-wet and have high oil-bearing potential, while the abundance of detrital clay or illite contributes to a low oil-bearing grade. The combination of core and microscopic observations and the MICP and NMR analyses have allowed the determination of the pore structure characteristics and their coupling effects on oil-bearing property. |

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Characterization of shale pore system: A case study of Paleogene Xin'gouzui Formation in the Jianghan basin, China

Cited by 107 publications

References 31 publications

Geochemical and geological characteristics of the Jurassic continental black shale in the Southwestern Depression of Tarim Basin

Geochemical and geological characteristics of the Jurassic continental black shale in the Southwestern Depression of Tarim Basin

A polymer microsphere emulsion as a high-performance shale stabilizer for water-based drilling fluids

Effect of pore structure on oil‐bearing property in the third member of Paleogene Funing Formation in Subei Basin, East China

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