Effect of lithofacies on shale reservoir and hydrocarbon bearing capacity in the Shahejie Formation, Zhanhua Sag, eastern China

Su, Siyuan; Jiang, Zhenxue; Shan, Xuanlong; Ning, Chuanxiang; Zhu, Yunfeng; Wang, Xiaoyong; Li, Zheng; Zhu, Rixiang

doi:10.1016/j.petrol.2018.11.048

Cited by 19 publications

(8 citation statements)

References 13 publications

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“…Furthermore, laminae are widely developed sedimentary structures in shales, representing the directional arrangement of organic matter or inorganic minerals. Shales containing laminae exhibit a high hydrocarbon generation ability, and shales containing fine laminae formed via biochemical deposition exhibit a more pronounced hydrocarbon generation ability (Zeng et al, 2017;Su et al, 2019). The interbedding of micron-to centimeter-scale laminae composed of different components reflects the microscale source-reservoir configuration of shales (Han et al, 2021;Liu B. et al, 2021).…”

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

confidence: 99%

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%

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

et al. 2021

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“…This material has been widely accepted as a high-quality source rock ). Research has revealed that clay, quartz, and calcite are the dominant minerals, while clastic limestone and lime mudstone are the main rock types in Es 3 l in the Zhanhua Sag Su et al, 2019). Horizontally bedded structures were identified through the changes in the mineral composition, layer thickness, and color, and the material was divided into that with a massive structure (no bedded structure), a layered structure (thickness of a single layer more than 1 mm), and a lamellar structure (thickness of a single layer less than 1 mm) (Liu et al, 2012;.…”

Section: Geological Settingsmentioning

confidence: 99%

Effect of Shale Reservoir Characteristics on Shale Oil Movability in the Lower Third Member of the Shahejie Formation, Zhanhua Sag

Ning

Jiang

et al. 2020

Acta Geologica Sinica (Eng)

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To reveal the effect of shale reservoir characteristics on the movability of shale oil and its action mechanism in the lower third member of the Shahejie Formation (Es3l), samples with different features were selected and analyzed using N2 adsorption, high‐pressure mercury injection capillary pressure (MICP), nuclear magnetic resonance (NMR), high‐speed centrifugation, and displacement image techniques. The results show that shale pore structure characteristics control shale oil movability directly. Movable oil saturation has a positive relationship with pore volume for radius > 2 μm, as larger pores often have higher movable oil saturation, indicating that movable oil is present in relatively larger pores. The main reasons for this are as follows. The relatively smaller pores often have oil‐wetting properties because of organic matter, which has an unfavorable effect on the flow of oil, while the relatively larger pores are often wetted by water, which is helpful to shale oil movability. The rich surface provided by the relatively smaller pores is beneficial to the adsorption of immovable oil. Meanwhile, the relatively larger pores create significant pore volume for movable oil. Moreover, the larger pores often have good pore connectivity. Pores and fractures are interconnected to form a complex fracture network, which provides a good permeability channel for shale oil flow. The smaller pores are mostly distributed separately; thus, they are not conducive to the flow of shale oil. The mineral composition and fabric macroscopically affect the movability of shale oil. Calcite plays an active role in shale oil movability by increasing the brittleness of shale and is more likely to form micro‐cracks under the same stress background. Clay does not utilize shale oil flow because of its large specific surface area and its block effect. The bedding structure increases the large‐scale storage space and improves the connectivity of pores at different scales, which is conducive to the movability of shale oil.

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“…For example, the Hetaoyuan Formation mudstone of Paleogene in the Biyang Depression (Chen et al, 2011), the Mesozoic Haynesville Shale from the Louisiana Basin (Ross et al, 2009), etc. However, due to the small size, complex sources of components (Cao et al, 2015;Yang et al, 2017;Wu et al, 2019), large variation of rock composition (Yan et al, 2018;Zhao et al, 2018;Su et al, 2019;Zou et al, 2019) and strong heterogeneity (Yuan et al, 2015;Pu et al, 2016;Huang et al, 2018; of fine-grained sedimentary rocks, there is still a lack of systematic and scientific criteria for the petrological classification of them (Jiang et al, 2013;Zhu et al, 2017).…”

Section: Introductionmentioning

confidence: 99%

Lithofacies and Pore Structure of Fine‐grained Sedimentary Rocks of Qing‐1 Member of Cretaceous in the Southern Songliao Basin

Lin

Liu

et al. 2021

Acta Geologica Sinica (Eng)

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Fine-grained sedimentary rocks often contain hydrocarbon and mineral resources. Compared with coarse-grained sedimentary rocks, fine-grained sedimentary rocks are less studied. To elucidate the lithofacies and pore structure of lacustrine fine-grained rocks, the 340.6 m continuous core of Cretaceous Qing-1 Member from five wells in the southern central depression of the Songliao Basin was analyzed using X-ray diffraction, Rock-Eval pyrolysis, low-temperature nitrogen adsorption, high-pressure mercury injection, argon ion polishing-field emission scanning electron microscopy, and laser scanning confocal microscopy. Based on mineral compositions, organic matter abundance and sedimentary structure, lacustrine fine-grained rocks in the study area were divided into ten lithofacies, with their spatial distributions mainly influenced by tectonic cycle, climate cycle and provenance. Furthermore, pore structure characteristics of different lithofacies are summarized. (1) The siliceous mudstone lithofacies with low TOC content and the laminated/layered claybearing siliceous mudstone lithofacies with medium TOC content have the highest proportion of first-class pores (diameter > 100 nm), making it the most favourable lithofacies for the accumulation of shale oil and shale gas. (2) The massive claybearing siliceous mudstone lithofacies with low TOC content has the highest proportion of second-class pores (diameter ranges from 10 to 100 nm), making it a favourable lithofacies for the enrichment of shale gas. (3) The massive clay-bearing siliceous mudstone lithofacies with high TOC content has the highest proportion of third-class pores (diameter < 10 nm), making it intermediate in gas storage and flow. Laser confocal oil analysis shows that the heavy component of oil is mainly distributed in the clay lamina, while the light part with higher mobility is mainly concentrated in the silty lamina.

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Effect of lithofacies on shale reservoir and hydrocarbon bearing capacity in the Shahejie Formation, Zhanhua Sag, eastern China

Cited by 19 publications

References 13 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

Effect of Shale Reservoir Characteristics on Shale Oil Movability in the Lower Third Member of the Shahejie Formation, Zhanhua Sag

Lithofacies and Pore Structure of Fine‐grained Sedimentary Rocks of Qing‐1 Member of Cretaceous in the Southern Songliao Basin

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