A comprehensive study on the impacts of rock fabric on hydrocarbon generation and pore structure evolution of shale under semi-confined condition

Song, Dongjun; Wang, Xiaoqi; Tuo, Jincai; Wu, Chenjun; Zhang, Mingfeng; Su, Long; He, Wei

doi:10.1016/j.marpetgeo.2020.104830

Cited by 16 publications

(18 citation statements)

References 65 publications

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“…affect the shale oil content through oil generation and retention capacity. Clay minerals can influence the hydrocarbon generation process and mechanism through a carbon ion mechanism and/or participate in the desorption and hydrogenation/decarboxylation of solid acids (Du et al, 2021;Song et al, 2021a). Transition group elements such as Fe, Co and V in shales impose a catalytic effect on organic matter hydrocarbon generation, which can generate more oil and gas in organic-rich shales at the early burial stage (Xi et al, 2020).…”

Section: Control Of Toc Content Oil Storage Space and Mineral Composition On Oil Retentionmentioning

confidence: 99%

“…In recent years, an increasing number of studies on shales has been performed on their evolution of hydrocarbon generation, retention and expulsion (Shao et al, 2020;Song et al, 2021a;Sun J. et al, 2021;Hou et al, 2021b;Song et al, 2021b;Stockhausen et al, 2021), oil retention mechanism (Ritter, 2003;Tian et al, 2014;Li et al, 2016;Qiu et al, 2016;Han et al, 2017;Tian et al, 2017;Hou et al, 2020), influencing factors of shale oil enrichment (Han et al, 2015;Zou et al, 2019a;Sun et al, 2019;Chen et al, 2020;Milliken et al, 2021) and geological evaluation (Lu et al, 2012;Kumar et al, 2017;Hu et al, 2018;Qian et al, 2018;Wang et al, 2019b;Li J. B. et al, 2020b;Wang B. Y. et al, 2021).…”

Section: Introductionmentioning

confidence: 99%

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Oil Retention in Shales: A Review of the Mechanism, Controls and Assessment

et al. 2021

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Shale oil is a vital alternative energy source for oil and gas and has recently received an extensive attention. Characterization of the shale oil content provides an important guiding significance for resource potential evaluation, sweet spot prediction, and development of shale oil. In this paper, the mechanism, evaluation and influencing factors of oil retention in shales are reviewed. Oil is retained in shales through adsorption and swelling of kerogen, adsorption onto minerals and storage in shale pores. Quite a few methods are developed for oil content evaluation, such as three-dimensional fluorescence quantitation, two-dimensional nuclear magnetic resonance (2D NMR), solvent extraction, pyrolysis, multiple extraction-multiple pyrolysis-multiple chromatography, logging calculation, statistical regression, pyrolysis simulation experiment, and mass balance calculation. However, the limitations of these methods represent a challenge in practical applications. On this basis, the influencing factors of the oil retention are summarized from the microscale to the macroscale. The oil retention capacity is comprehensively controlled by organic matter abundance, type and maturity, mineral composition and diagenesis, oil storage space, shale thickness, and preservation conditions. Finally, oil mobility evaluation methods are introduced, mainly including the multitemperature pyrolysis, 2D NMR, and adsorption-swelling experiment, and the influencing factors of movable shale oil are briefly discussed. The aim of this paper is to deepen the understanding of shale oil evaluation and provide a basis for further research.

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Section: Control Of Toc Content Oil Storage Space and Mineral Composition On Oil Retentionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Oil Retention in Shales: A Review of the Mechanism, Controls and Assessment

et al. 2021

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“…But the process of gas generation is conducive to the formation of small cavernous pores (Guo et al 2020). Meanwhile, some scholars point out that the formation of cavernous organic pores is not only affected by the characteristics of organic matters, but also related to gas expansion (Song et al 2021). With the increasing simulated temperatures, asphalt and liquid hydrocarbon tend to crack.…”

Section: Hydrocarbon Generation Rate and Pore Structurementioning

confidence: 99%

Exploring the coupling relationship between hydrocarbon generation of continental shale and nanopore structure evolution—A case study of Shahejie formation in Bohai Bay Basin

Zheng

Qin

et al. 2021

J Petrol Explor Prod Technol

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The nano-scale pore structure of shale is closely related to the self-generated and self-accumulated shale oil and gas. The Bohai Bay Basin is a crucial oil-bearing basin in eastern China, and the Paleogene Shahejie Formation is the most important source rock section in this area. In order to study the internal relationship between hydrocarbon generation evolution and pore structure characteristics of source rocks, we conducted hydrocarbon generation simulation tests with a closed gold tube system, and heated up original rocks from Shahejie Formation in Laizhou Bay Sag, southern Bohai Bay Basin, from 290 °C to 440°C at different heating rates. Besides, we carried out low-temperature N2 adsorption experiments on sample residues, and measured their pore structure characteristic parameters. The results show that with the increase of simulated temperature, the specific surface area and pore volume of nano-pores below 10 nm (which are mainly organic pores) decrease first and then increase, while those of nano-pores above 10 nm increase all the way. The evolution trend of total specific surface area and pore volume is mainly controlled by pores below 10 nm which are mainly organic pores, especially micropores below 2 nm. There are two main factors affecting the development of inorganic pores: (1) Dissolution of organic acids produced by pyrolysis of organic matter in hydrocarbon-generation evolution; (2) Deformation of crystal structure of mineral components under the combined action of temperature and pressure. The experimental results at different heating rates demonstrate that rapid settlement under geological conditions is not conducive to the development of nano-pores, especially micro-pores composed of organic pores.

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“…Hydrocarbon generation and expulsion simulation have been widely used as an experimental means to simulate the thermal evolution process of organic matter at long-term low temperature under actual geological conditions with short-term high temperature by using the time-temperature compensation principle (Dieckmann et al 2000;Sun et al 2015Sun et al , 2019bSong et al 2018Song et al , 2021Wu et al 2018Wu et al , 2019.…”

Section: Introductionmentioning

confidence: 99%

Response model of fluid–rock ratio to reservoir space in primary formation of shale oil during hydrous pyrolysis

Sun

Fu²,

Zhang³

et al. 2022

Earth and Environmental Science Transactions of the Royal Society of Edinburgh

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Due to the presence of geological fluid under actual geological conditions, water–rock interaction will occur between the fluid and reservoir. Thus, to analyse the influence of the water–rock interaction on storage space during the organic matter evolution stages, this study conducted a series of simulation experiments on shales by using a closed autoclave: four temperatures, 250°C, 300°C, 350°C, 400°C, and five fluid–rock ratios (FRRs), 0:20, 4:20, 10:20, 15:20, and 20:20. Low pressure N2 adsorption measurement was conducted on the solid residues. The experimental results show that the effect of temperature on the yield and pore structure of oil shale was the same as the result when the FRR was = 0:20, 4:20 and = 10:20, 15:20, 20:20, respectively. This result showed that temperature remained the main factor that affected the thermal evolution of hydrocarbon generation. Additionally, temperature was beneficial to the generation and storage of shale oil within a certain range, but only occupied the storage space of shale oils or connected a certain storage space beyond a certain range. The variation trend of shale oil yield with increasing FRR under the same simulated temperatures, 250°C and 400°C, was most affected by the FRR, but little change occurred at 300°C and 350°C. This further proved that the ratio of fluid to rock was an indirect acting factor, which affected the evolution of organic matters and then the development of pore structures. Before the oil window (350°C), the lower evolution degree, the higher water content and the more significant effect. In the higher evolution stage, the higher the water content, and the more complete the kerogen reaction, which was also more conducive to the development of pore structures. Therefore, this study promotes the establishment of linear equations on FRR to the gas adsorption capacity, which further provides a theoretical basis and guidance for the exploration and development of shale oil.

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A comprehensive study on the impacts of rock fabric on hydrocarbon generation and pore structure evolution of shale under semi-confined condition

Cited by 16 publications

References 65 publications

Oil Retention in Shales: A Review of the Mechanism, Controls and Assessment

Oil Retention in Shales: A Review of the Mechanism, Controls and Assessment

Exploring the coupling relationship between hydrocarbon generation of continental shale and nanopore structure evolution—A case study of Shahejie formation in Bohai Bay Basin

Response model of fluid–rock ratio to reservoir space in primary formation of shale oil during hydrous pyrolysis

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