Pore structure characteristics of coal-bearing organic shale in Yuzhou coalfield, China using low pressure N 2 adsorption and FESEM methods

Pan, Jienan; Peng, Chao; Wan, Xiaoqiang; Zheng, Deshun; Lv, Runsheng; Wang, Kai

doi:10.1016/j.petrol.2017.03.043

Cited by 63 publications

(34 citation statements)

References 28 publications

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“…Figure 7(b) reveals a certain degree of positive correlative trend between clay minerals and specific surface area, which means the clay minerals play an important role in contributing to pore surface area and volume (Figure 6(a) and (c)). This relationship has also been found in other coal-bearing shales of marine-continental transitional environment (Pan et al, 2017;Wang et al, 2015a). In summary, the interparticle pores of clay minerals constitute major contributors to mesapores in the Longtan shales in this study.…”

Section: Shale Gas Reservoir Characterizationsupporting

confidence: 82%

Evaluation of coal and shale reservoir in Permian coal-bearing strata for development potential: A case study from well LC-1# in the northern Guizhou, China

Sang

Yang

et al. 2018

Energy Exploration & Exploitation

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Indentifying reservoir characteristics of coals and their associated shales is very important in understanding the co-exploration and co-production potential of unconventional gases in Guizhou, China. Accordingly, comprehensive experimental results of 12 core samples from well LC-1# in the northern Guizhou were used and analyzed in this paper to better understand their vertical reservoir study. Coal and coal measured shale, in Longtan Formation, are rich in organic matter, with postmature stage of approximately 3.5% and shales of type III kerogen with dry gas generation. All-scale pore size analysis indicates that the pore size distribution of coal and shale pores is mainly less than 20 nm and 100 nm, respectively. Pore volume and area of coal samples influenced total gas content as well as desorbed gas and lost gas content. Obvious relationships were observed between residual gas and BET specific surface area and BJH total pore volume (determined by nitrogen adsorption). For shale, it is especially clear that the desorbed gas content is negatively correlated with BET specific surface area, BJH total pore volume and clay minerals. However, the relationships between desorbed gas and TOC (total

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Section: Shale Gas Reservoir Characterizationsupporting

confidence: 82%

Evaluation of coal and shale reservoir in Permian coal-bearing strata for development potential: A case study from well LC-1# in the northern Guizhou, China

Sang

Yang

et al. 2018

Energy Exploration & Exploitation

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“…According to the slope of the curves, most of the pores of sandstones were larger than 50 nm, while the mudstones were dominated by pores less than 50 nm. These results agree with those of previous studies (Ross and Bustin, 2007;Nelson, 2009;Chalmers et al, 2012;Pan et al, 2017).…”

Section: Mercury Porosimetrysupporting

confidence: 94%

Geological Controls on High Production of Tight Sandstone Gas in Linxing Block, Eastern Ordos Basin, China

Meng

et al. 2020

Acta Geologica Sinica (Eng)

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Tight sandstone gas in the Linxing Block, eastern Ordos Basin, has been successfully exploited. The high performance is mainly a result of the special geological conditions. The key geological controls for high production have been discussed on the basis of seismic data, field observation, sample features, mercury porosimetry, mechanical properties, and basin modeling. Firstly, the coal measures have good gas generation potential, not only because of the existence of coalbeds and organic‐rich shales, but also because coal laminae and microbial mats in the shales significantly increase their total organic carbon (TOC) contents. Secondly, except for the uplifted zone of the Zijinshan complex and the eastern fault zone, rare large faults develop in the Carboniferous–Permian sequence, ensuing the sealing capacity of cap rock. Small fractures generally concentrated in the sandstones rather than the mudstones. Thirdly, gas accumulation in the Linxing Block was controlled by the tectonic, burial and thermal histories. Gas accumulation in the Linxing Block started in the Late Triassic, followed by three short pauses of thermal maturation caused by relatively small uplifts; the maximum hydrocarbon generation period is the Early Cetaceous as a combined result of regional and magmatic thermal metamorphisms. Field profiles show abundant fractures in sandstone beds but rare fractures in mudstone beds. Mechanical properties, determined by lithostratigraphy, confine the fractures in the sandstones, increasing the permeability of sandstone reservoirs and retaining the sealing capacity of the mudstone cap rocks. The modern ground stress conditions favor the opening of predominant natural fractures in the NNW–SSE and N–S directions. These conclusions are useful for exploring the potential tight sandstone gas field.

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“…The curves generally show an increasing adsorption of nitrogen with increasing pressure in all the samples. All the samples demonstrate some level of adsorption at relative low pressure (P/Po < 0.01), signifying micropores existence [45,46]. A critical look at the hysteresis loops of the samples reveals that the samples have Type H3 with non-appearance of plateaus at relative high pressure (P/Po > 0.95) [47].…”

Section: Gas Adsorption Characteristicsmentioning

confidence: 94%

Mineralogical and pore structure of organic-rich deltaic shales and sub-bituminous coals from early Maastrichtian Mamu Formation, Anambra Basin, Nigeria

Faboya

Sonibare

et al. 2020

SN Appl. Sci.

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The Mamu Formation source rocks in the Anambra Basin are targets for shale gas reservoir. However, fundamental data on the critical pore structures for assessing the shale reservoir capabilities are lacking. In this study, the source rocks were investigated for their mineralogical compositions and pore structure characteristics by X-ray diffraction, accelerated surface area and porosimetry and field emission scanning electron microscopy (FE-SEM). The bulk mineralogy of the samples is dominated by kaolinite and quartz with average percentage composition of 52.0 and 41.5, respectively, suggesting that the rocks are potential candidates for fracking. The total average pore volume and specific surface area in the samples are 0.0421 cm 3 /g and 22.43 m 2 /g, respectively. The shale samples show higher amounts of total pore volumes relative to the sub-bituminous coals. No obvious organic pore is observed in the shale samples, but some inherited primary organic matter pores of plant origin exist in the sub-bituminous coals. Therefore, inorganic minerals pores are the major contributors to the pore development in the immature shales. The FE-SEM results reveal that the pore network in the shales is dominated by intraparticle pores and fractures. The observed well-developed fractures within the Mamu shales that may have resulted from tectonic events are capable of positively influencing the petrophysical properties of shales in the basin and by extension assist in shale gas exploration and development in the entire Lower Benue Trough.

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Pore structure characteristics of coal-bearing organic shale in Yuzhou coalfield, China using low pressure N 2 adsorption and FESEM methods

Cited by 63 publications

References 28 publications

Evaluation of coal and shale reservoir in Permian coal-bearing strata for development potential: A case study from well LC-1# in the northern Guizhou, China

Evaluation of coal and shale reservoir in Permian coal-bearing strata for development potential: A case study from well LC-1# in the northern Guizhou, China

Geological Controls on High Production of Tight Sandstone Gas in Linxing Block, Eastern Ordos Basin, China

Mineralogical and pore structure of organic-rich deltaic shales and sub-bituminous coals from early Maastrichtian Mamu Formation, Anambra Basin, Nigeria

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