Swelling of Kimmeridge kerogen by normal-alkanes, naphthenes and aromatics

Huang, Liang; Khoshnood, Atefeh; Firoozabadi, Abbas

doi:10.1016/j.fuel.2020.117155

Cited by 36 publications

(24 citation statements)

References 41 publications

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“…They find that the thermal pretreatment of a sample may affect swelling . Recently Liang et al have conducted swelling measurements in different hydrocarbon liquids in a kerogen sample. The results show that in normal alkanes swelling decreases as the chain length increases.…”

Section: Introductionmentioning

confidence: 99%

Kerogen Swelling in Light Hydrocarbon Gases and Liquids and Validity of Schroeder’s Paradox

Firoozabadi

2021

J. Phys. Chem. C

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Kerogen is often the organic part of the shale and provides the pore space for a large part of the hydrocarbons in place. Kerogen molecules are flexible like polymer molecules, and may swell when in contact with specific solvents. The difference in swelling of a polymer when exposed to a pure liquid versus its saturated vapor is known as Schroeder’s paradox, which has a long history of controversy. To the best of our knowledge, kerogen swelling induced by a hydrocarbon in both gas and liquid states has not been investigated. We investigate the sorption of gaseous and liquid propane, normal butane, and normal pentane in kerogen and kerogen swelling at various pressures. A flexible kerogen matrix is created using molecular dynamics simulations. The large pores are created and maintained with a dummy particle and nailed atoms, respectively. The hydrocarbon sorption and kerogen swelling induced by the sorption of hydrocarbon gases and liquids are investigated by the hybrid molecular dynamics-grand canonical Monte Carlo simulations. Results show that smaller hydrocarbon molecules in both gas and liquid states have higher sorption and induce higher swelling and structural changes in the kerogen matrix. Hydrocarbon liquids have higher sorption and induce higher kerogen swelling than the corresponding gases at saturation pressure in agreement with Schroeder’s paradox. Hydrocarbon gases lead to the moderate kerogen swelling from expansion of large pores; hydrocarbon liquids swell the kerogen more significantly not only by expanding the large pore but also by creating new pores and throats. Liquid-inducing kerogen swelling is accompanied by hydrocarbon dissolution in the kerogen matrix altering significantly the pore surface area, porosity, and pore size distribution. The work sets the stage for further studies considering the effect of production on shale volumetric strain.

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Section: Introductionmentioning

confidence: 99%

Kerogen Swelling in Light Hydrocarbon Gases and Liquids and Validity of Schroeder’s Paradox

Firoozabadi

2021

J. Phys. Chem. C

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“…Coal seam is mainly composed of coal matrix, coal cleat, and coal fracture. Different from conventional natural gas, CBM mainly exists in coal matrix in the adsorption state, and the adsorption gas content can reach 90~95 % of the total gas, much higher than that in shale kerogen (Huang et al 2020;Sun et al 2020). Under the original reservoir conditions, the cleats and fractures of coal seam are filled with a large amount of free water and only a small amount of free gas.…”

Section: Key Problems In Co-production Of Cbm and Tight Sandstone Gasmentioning

confidence: 99%

Controlling factors towards co-production performance of coalbed methane and tight sandstone gas reservoirs

Huang

Wang²

2021

Arab J Geosci

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Multi-layer superposition of coal seams and tight sandstone layers is common in Chinese major coal-bearing basins, which possesses huge resource potential. Co-production of coalbed methane (CBM) and tight sandstone gas reservoirs is still in the stage of engineering test in China; the control factors towards the co-production performance remain to be clarified. Based on discussion on the key problems involved in co-production of coal seams and tight sandstone layers, the main control factors governing the co-production performance of CBM and tight sandstone gas are analyzed. Taking well X in Ordos Basin as an example, a co-production numerical model is established. The co-production characteristics of well X are analyzed. The optimization of co-production sequence and hydraulic fracturing parameters of tight sandstone formation is carried out. The results show that the early drainage in coal seams and the reasonable control of bottom-hole flowing pressure are the keys to achieve good development benefits. The co-production is mainly controlled by reservoir permeability, water saturation of sandstone formation, formation-desorption pressure difference of coal seam, reservoir pressure gradient, and surrounding rock properties. Under the optimized co-production sequence of perforating coal seam first and the tight sandstone layer, the tight sandstone layer has a low recovery degree, which may be targeted for later reservoir reconstruction. The recovery degree of tight sandstone layer can be improved by optimizing the hydraulic fracturing parameters such as the fracture halflength and the fracture conductivity. For well X, the fracture half-length and the fracture conductivity are optimized to be 150 m and 300 mD•m. The findings of this study can be applicable to evaluating the adaptability of geological conditions for multi-layer co-production in coal-bearing basins. Also, the findings can provide theoretical guides for the optimization of production sequence and hydraulic fracturing to improve the co-production benefits.

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“…As the concentration of elemental sulfur in the sour gas exceeds the critical dissolved concentration during the development of sour gas reservoirs, sulfur deposition may occur in the formation. The characteristics of sulfur dissolution, like hydrocarbon dissolution in organic matter (Huang et al, 2020;Huang et al, 2021), are crucial in the analysis of elemental sulfur deposition limit and deposition amount (Smith et al, 1970;Brunner and Woll, 1980;Brunner et al, 1988). Thus, many researchers have been devoted to the study on the elemental sulfur solubility in sour gas from experiment (Kennedy and Wieland, 1960;Roof, 1971;Swift and Manning, 1976;Brunner and Woll, 1980;Brunner et al, 1988;Davis et al, 1993;Gu et al, 1993;Sun and Chen, 2003;Zeng et al, 2005;Yang et al, 2009;Bian et al, 2010;Serin et al, 2010;Cloarec et al, 2012), thermodynamic model (Karan et al, 1998;Heidemann et al, 2001;Cézac et al, 2007;Cézac et al, 2008), semi empirical model (Chrastil, 1982;Eslamimanesh et al, 2011a;Hu et al, 2014;Guo and Wang, 2016), artificial intelligence algorithm (Mohammadi and Richon, 2008;Mehrpooya et al, 2010;Aminian, 2011;Bian et al, 2018;Fu et al, 2019;Bemani et al, 2020;Chen et al, 2020) and molecular simulation (Kadoura et al, 2013;Chen et al, 2019).…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on the Elemental Sulfur Solubility in Sour Gas Mixtures

Zhang

Huang

et al. 2021

Front. Earth Sci.

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The investigation of elemental sulfur solubility plays critical roles on sour gas reservoir development. In this paper, the solubility of elemental sulfur was directly measured by static method with gas samples from well M1 of a sour gas reservoir in Sichuan Basin. The results show that the solubility of elemental sulfur ranges from 0.001 g/cm3 to 0.968 g/cm3 at 40–98.9 MPa and 15–49.8 MPa. The elemental sulfur solubility increases with increasing temperature and pressure, especially when the pressure is greater than 30 MPa. Moreover, the H2S content in sour gas mixtures is also an important factor affecting elemental sulfur solubility. The elemental sulfur solubility increases with increasing H2S content of the sour gas mixtures. The experimental data in this paper display a consistent trend with the reported experimental data. Based on the experimental results, the chrastil-type model, Robert’s model and Hu’s model were investigated and compared. The results show that the chrastil-type model by fitting experimental data in this paper has less error and higher accuracy in calculating elemental sulfur solubility in M gas reservoir. The chrastil-type models proposed in the literature, meanwhile, are only based on the regression of specific gas components and experimental conditions, which lead to a large error in the calculation of elemental sulfur solubility of sour gas samples in this research. The research results provide important basic data and technical support for the development of M gas reservoir.

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Swelling of Kimmeridge kerogen by normal-alkanes, naphthenes and aromatics

Cited by 36 publications

References 41 publications

Kerogen Swelling in Light Hydrocarbon Gases and Liquids and Validity of Schroeder’s Paradox

Kerogen Swelling in Light Hydrocarbon Gases and Liquids and Validity of Schroeder’s Paradox

Controlling factors towards co-production performance of coalbed methane and tight sandstone gas reservoirs

Experimental Study on the Elemental Sulfur Solubility in Sour Gas Mixtures

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