Experimental investigation of mechanical compaction on the physical and elastic properties of synthetic shales

Gong, Fei; Di, Bangrang; Wei, Jianxin; Teng, Lidong

doi:10.1016/j.jappgeo.2018.12.011

Cited by 5 publications

(6 citation statements)

References 33 publications

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“…On the one hand, the intergranular and dissolution pores become fewer due to the compaction. 60 On the other hand, clay minerals were transformed into illite with increasing depth (Figure 3a), which further decreased the pore size and porosity as discussed before. Marsh shale has a lower relative content of illite and high quartz content, and the decreasing trend of porosity with depth is weaker than shale of other microfaices (Figure 11b).…”

Section: Experimental Results and Analysissupporting

confidence: 56%

“…Therefore, with increasing burial depth, the porosity of Shahezi shale reservoir exhibits a decreasing trend (Figure b). On the one hand, the intergranular and dissolution pores become fewer due to the compaction . On the other hand, clay minerals were transformed into illite with increasing depth (Figure a), which further decreased the pore size and porosity as discussed before.…”

Section: Experimental Results and Analysissupporting

confidence: 53%

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Comparison of Marine and Continental Shale Gas Reservoirs and Their Gas-Bearing Properties in China: The Examples of the Longmaxi and Shahezi Shales

Xiao

Shao

et al. 2021

Energy Fuels

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Following the marine shale gas, the continental shale gas also presents great exploration potential in China. However, few studies focused on the high-over-mature stage (HOMS) continental shale gas in terms of mineral composition, pore structure, and gas-bearing properties, as well as their comparisons with successfully marine shale gas in the same mature stage, which restricts its better potential evaluation and “sweet spots” suggestion. In this paper, the lower Cretaceous Shahezi Formation in Xujiaweizi fault depression, and the lower Silurian Longmaxi Formation in Pengshui Area, were selected as the target areas for the study of continental and marine shale gas in the HOMS. By means of thin sections, scanning electron microscopy, nitrogen adsorption, high-pressure mercury injection, and methane isothermal adsorption, a systematic comparison was carried out to reveal the differences in reservoir characterizes and gas-bearing properties, and summarize their controlling factors and “sweet spots” distribution. The type and distribution of organic matter (OM) dominate the differences between marine and continental shale in the HOMS. Compared with Longmaxi marine shale with OM of type I–II1 kerogen, there are fewer biogenic siliceous, lower proportion of organic pores, and more inorganic pores (including dominant clay related pores, quartz intergranular pores, and dissolution pores) in Shahezi continental shale with OM of type III–II2 kerogen, corresponding to larger average pore size and smaller specific surface area (SSA). Quartz content, porosity, and SSA are mainly controlled by TOC for marine shale, while those are controlled by deposition and burial depth for continental shale. Plain marsh shale, adjacent to a coal seam, is favorable for the development of cemented quartz grains and the limited conversion of mixed illite/smectite (I/S) to illite, which can effectively restrain the impact of burial depth on the proportion of intergranular and dissolution pores, porosity, and pore size for continental shale. I/S, rather than OM, mainly contributes to the methane adsorption capacity in continental shale, of which the adsorbed gas content is obviously lower than that of marine shale. Due to the higher pressure coefficient (PC), porosity and total gas content of marine shale still increase with increasing the burial depth, while those of Shahezi continental shale decrease rapidly due to the slight increase of PC with depth. Some exploration potential in organic-rich thick shales should be expected in the Shahezi Formation, which are developed in plain marsh or delta front with burial depths in the range of 2600–3600 m.

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Section: Experimental Results and Analysissupporting

confidence: 56%

Section: Experimental Results and Analysissupporting

confidence: 53%

Comparison of Marine and Continental Shale Gas Reservoirs and Their Gas-Bearing Properties in China: The Examples of the Longmaxi and Shahezi Shales

Xiao

Shao

et al. 2021

Energy Fuels

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“…The Young’s modulus and Poisson’s ratio in VTI medium exhibit anisotropy with respect to the bedding direction, resulting in distinct values that can be determined using elastic coefficients. Eqs – provide a calculation method for these parameters. , E v = C 33 false( C 11 + C 12 false) − 2 C 13 2 C 11 + C 12 E h = false( C 11 − C 12 false) false( C 33 C 11 + C 33 C 12 − 2 C 13 2 false) C 11 C 33 − C 13 2 μ v = C 13 C 11 …”

Section: Experiments and Methodsmentioning

confidence: 99%

“…The measurement of velocity anisotropy relies on a single parallel bedding direction sample, as initially proposed by Wang. 40 The fundamental assumption of the measurement is that the elastic properties of the sample being measured can be characterized by TI (transverse isotropy). To measure wave velocities for three observation modes, namely, v p,90 , v s,90 , and v s,0 in the long axis direction of the sample, a 1 MHz main frequency ultrasonic transducer is employed.…”

Section: Sample Preparationmentioning

confidence: 99%

Quantitative Characterization of Elastic Parameters and Its Implications for Reservoir Evaluation: A Case Study on High Clay-rich Continental Shale

Zhang,

Zhao,

Yin

et al. 2024

Energy Fuels

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“…Shale oil and gas have proven to be a type of unconventional oil and gas resource with abundant reserves (Curtis 2002;Jarvie et al 2007;Zhang et al 2018). In the past decade, there have been many successful examples of shale oil and gas exploration, such as the Barnett Shale in the Fort Worth Basin (Bernard et al 2012), the Horn River Group shale in the Western Canada Sedimentary Basin (Ross and Bustin 2009;Dong et al 2015), the Posidonia Shale in Europe (Gasparik et al 2014), the Devonian Woodford Shale in Oklahoma and Texas, and the Longmaxi Formation in the Sichuan Basin (Tian et al 2013;Yang et al 2016). These examples are marine shales rich in Type I and II kerogen, while marine-continental transitional shales rich in Type III kerogen have not yet been found for large-scale commercial exploitation.…”

Section: Introductionmentioning

confidence: 99%

Porosity model and pore evolution of transitional shales: an example from the Southern North China Basin

Yang

Guo

2020

Pet. Sci.

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The evolution of shale reservoirs is mainly related to two functions: mechanical compaction controlled by ground stress and chemical compaction controlled by thermal effect. Thermal simulation experiments were conducted to simulate the chemical compaction of marine-continental transitional shale, and X-ray diffraction (XRD), CO 2 adsorption, N 2 adsorption and high-pressure mercury injection (MIP) were then used to characterize shale diagenesis and porosity. Moreover, simulations of mechanical compaction adhering to mathematical models were performed, and a shale compaction model was proposed considering clay content and kaolinite proportions. The advantage of this model is that the change in shale compressibility, which is caused by the transformation of clay minerals during thermal evolution, may be considered. The combination of the thermal simulation and compaction model may depict the interactions between chemical and mechanical compaction. Such interactions may then express the pore evolution of shale in actual conditions of formation. Accordingly, the obtained results demonstrated that shales having low kaolinite possess higher porosity at the same burial depth and clay mineral content, proving that other clay minerals such as illite-smectite mixed layers (I/S) and illite are conducive to the development of pores. Shales possessing a high clay mineral content have a higher porosity in shallow layers (< 3500 m) and a lower porosity in deep layers (> 3500 m). Both the amount and location of the increase in porosity differ at different geothermal gradients. High geothermal gradients favor the preservation of high porosity in shale at an appropriate R o. The pore evolution of the marine-continental transitional shale is divided into five stages. Stage 2 possesses an R o of 1.0%-1.6% and has high porosity along with a high specific surface area. Stage 3 has an R o of 1.6%-2.0% and contains a higher porosity with a low specific surface area. Finally, Stage 4 has an R o of 2.0%-2.9% with a low porosity and high specific surface area.

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Experimental investigation of mechanical compaction on the physical and elastic properties of synthetic shales

Cited by 5 publications

References 33 publications

Comparison of Marine and Continental Shale Gas Reservoirs and Their Gas-Bearing Properties in China: The Examples of the Longmaxi and Shahezi Shales

Comparison of Marine and Continental Shale Gas Reservoirs and Their Gas-Bearing Properties in China: The Examples of the Longmaxi and Shahezi Shales

Quantitative Characterization of Elastic Parameters and Its Implications for Reservoir Evaluation: A Case Study on High Clay-rich Continental Shale

Porosity model and pore evolution of transitional shales: an example from the Southern North China Basin

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