The effect of interbedding on shale reservoir properties

Raji, Munira; Gröcke, Darren R.; Greenwell, H. Christopher; Gluyas, Jon; Cornford, C.

doi:10.1016/j.marpetgeo.2015.04.015

Cited by 42 publications

(14 citation statements)

References 29 publications

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“…As relative pressure increases, the multilayers of adsorbed water form in the larger pores. At a high relative pressure, the capillary condensation commences in the small pores due to the ink-bottle effect 49 . The desorption curve is above the adsorption curve, and the desorption of water from the shale pores is more difficult than the adsorption of water by the shale due to the capillary forces.…”

Section: Hysteresis Behavior and Capillary Condensation The Water Vamentioning

confidence: 99%

Experimental investigation on water adsorption and desorption isotherms of the Longmaxi shale in the Sichuan Basin, China

Shen

et al. 2020

Sci Rep

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the understanding of water adsorption and desorption behavior in the shale rocks is of great significance in the reserve estimation, wellbore stability and hydrocarbon extraction in the shale gas reservoirs. However, the water sorption behavior in the shales remains unclear. In this study, water vapor adsorption/desorption isotherms of the Longmaxi shale in the Sichuan Basin, china were conducted at various temperatures (30 °C, 60 °C) and a relative pressure up to 0.97 to understand the water sorption behavior. Then the effects of temperature and shale properties were analyzed, and the water adsorption, hysteresis, saturation and capillary pressure were discussed. The results indicate that water adsorption isotherms of the Longmaxi shale exhibit the type II characteristics. The water molecules initially adsorb on the shale particle/pore surfaces at low relative pressure while the capillary condensation dominates at high relative pressure. Temperature favors the water sorption in the shales at high relative pressure, and the GAB isotherm model is found to be suitable for describe the water adsorption/desorption behavior. The high organic carbon and full bedding are beneficial to water adsorption in the shales while the calcite inhibits the behavior. There exists the hysteresis between water adsorption and desorption at the whole relative pressure, which suggests that the depletion of condensed water from smaller capillary pores is more difficult than that from larger pores, and the chemical interaction contributes to the hysteresis loop for water sorption. The capillary pressure in the shales can be up to the order of several hundreds of Mpa, and thus the desorption of water from the shales may not be as easy as the water adsorption due to the high capillary pressure, which results in water retention behavior in the shale gas reservoirs. these results can provide insights into a better understanding of water sorption behavior in the shale so as to optimize extraction conditions and predict gas productivity in the shale gas reservoirs.

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Section: Hysteresis Behavior and Capillary Condensation The Water Vamentioning

confidence: 99%

Experimental investigation on water adsorption and desorption isotherms of the Longmaxi shale in the Sichuan Basin, China

Shen

et al. 2020

Sci Rep

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“…A relatively low proportion of clay minerals (<35%) (Andrews, 2013) and high proportion of non-swelling minerals is considered to be favorable for hydraulic fracturing cutting across the layering (Jarvie, 2012(Jarvie, , 2014, depending on the in-situ stress state, and hence for potential gas extraction. High proportions of quartz or carbonates that are contiguous limit ductility and enhance the brittleness of the rock (Jarvie 2014;Raji et al, 2015). Microtextural changes across layers induce discontinuities and weak regions, producing localized stresses, and strain incompatibilities under mechanical simulations (Lan et al, 2010 ;Amann et al, 2011) which aid in the development of pathways for fracture growth.…”

Section: Contrasting Vertical Microstructural Properties In the Lowermentioning

confidence: 99%

Variability in spatial distribution of mineral phases in the Lower Bowland Shale, UK, from the mm- to μm-scale: Quantitative characterization and modelling

Fauchille

Eijnden

et al. 2018

Marine and Petroleum Geology

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“…7c, d). Therefore, the lithofacies association of argillaceous shales with silty shales interlayers shows high oil abundance with retained oil in the shales and migrated oil in the interbedded silty laminae, which has been demonstrated by the exploration practice in marine Jiaoshiba shale of Sichuan Basin, lacustrine Zhangjiatan shale of Ordos Basin and Kimmeridge Clay Formation of the North Sea (Raji et al 2015;Lei et al 2015;Guo and Zhang 2014). In addition, Zhang et al (2015) proposed that laminated calcareous shales in the study area have the high TOC content and oil abundance, good porosity and permeability, and welldeveloped pores and fractures, particularly organic pores and dissolution pores, in which oil occured (Fig.…”

Section: Advantageous Shale Lithofacies and Effective Reservoirsmentioning

confidence: 93%

Enrichment conditions of Hetaoyuan Formation shale oil in Biyang Depression, China

Shang

Xie

2018

J Petrol Explor Prod Technol

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In this paper, the data of thin section, organic petrology, geochemistry, lithology and porosity were used to investigate enrichment conditions of Hetaoyuan Formation shale oil in the Biyang Depression. The results show the shale oil is a kind of low-maturity oil with medium density and low viscosity, and main factors controlling shale oil enrichment include total organic content (TOC), formation pressure, lithofacies and effective reservoirs. Shales in the fifth organic-rich interval are developed widely with large thickness (reach up to 150 m), high TOC content (2.0-4.68%), better organic matter types (type I and II 1 ) and appropriate thermal maturity (usually larger than 0.5%), which are beneficial to generate much hydrocarbon, and volume expansion causes overpressure in source rock, especially in sections with low hydrocarbon expulsion efficiency due to less fractures. Free hydrocarbons S 1 values increase with TOC contents, and significant overpressure correlates with the larger OSI (S 1 /TOC × 100) values and porosity. Well-developed calcareous shales and argillaceous shales with silty shale interlayers have better porosity, and effective pores (throat diameters greater than 10 nm) contribute to 47.5% of the total volume.

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The effect of interbedding on shale reservoir properties

Cited by 42 publications

References 29 publications

Experimental investigation on water adsorption and desorption isotherms of the Longmaxi shale in the Sichuan Basin, China

Experimental investigation on water adsorption and desorption isotherms of the Longmaxi shale in the Sichuan Basin, China

Variability in spatial distribution of mineral phases in the Lower Bowland Shale, UK, from the mm- to μm-scale: Quantitative characterization and modelling

Enrichment conditions of Hetaoyuan Formation shale oil in Biyang Depression, China

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