Quantitative Estimation on Methane Storage Capacity of Organic-Rich Shales from the Lower Silurian Longmaxi Formation in the Eastern Sichuan Basin, China

Guo, Xiaowen; Luo, Tao; Dong, Tian; Yang, Rui; Han, Yuanjia; Yi, Jizheng; He, Sheng; Shu, Zhiguo; Bao, Hanyong

doi:10.1007/s12583-020-1394-7

Cited by 7 publications

(2 citation statements)

References 43 publications

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“…The Sichuan Basin is the first shale gas production base in China, and in recent years, China Petroleum and Chemical Corporation Jianghan Oilfield Branch has discovered industrial gas flow in the Permian System in the Hongxing area of eastern Sichuan, which proves that this formation has a good prospect for exploration and development. , However, the Permian system in this region has been studied to a low degree, and the gas content of shale gas has not been systematically evaluated by previous researchers; therefore, its gas content is not clear, and there is a lack of theoretical guidance for later production. In the production process of shale gas wells, free gas in fractures and matrix pores is mainly in the early stage, and adsorbed gas is mainly in the late stage. − Therefore, in situ gas content and adsorbed/free gas ratio are key parameters for shale gas resource evaluation, and they are of great significance for clarifying the exploitation potential of the target area, guiding the late-stage exploitation project, and predicting the late-stage production of the gas wells. ,,,− …”

Section: Introductionmentioning

confidence: 99%

“…The current methods for evaluating gas content can be categorized into direct and indirect methods, and the direct method is a method to directly measure the amount of desorbed gas and residual gas in the rock samples, to extrapolate the amount of lost gas, and then to obtain the total gas content. − Bertard et al were the first to propose a method for estimating natural gas content, the Bertard direct method . The theoretical basis of this method is that the amount of gas released from coal samples during early desorption is inversely proportional to the square root of time.…”

Section: Introductionmentioning

confidence: 99%

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Gas-Bearing Characteristics of Permian Shales in Hongxing Area, Sichuan Basin, China: A Comprehensive Evaluation and Comparison Using Multiple Methods

Li,

Lu,

et al. 2024

Energy Fuels

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In situ gas content and adsorbed gas ratio are the key parameters for shale gas content evaluation, and they can provide important references for the selection of development target areas and optimization of later development strategies. As a new formation for shale gas exploration and development, the gas content and adsorbed gas ratio of the Permian in the Hongxing area are not clear, which limits further development work. In this study, five shale samples from the Wujiaping Formation in the Hongxing area of the Sichuan Basin were used for sealing and desorption experiments, and four methods, namely, the USBM method, the polynomial method, the Amoco method, and the CIF method, were used to evaluate the gas content of the shale, and the results of the CIF method were found to be more accurate in comparison. The in situ gas content of Permian shales in the Hongxing area ranged from 5.38 to 13.36 cm 3 /g, with an average value of 8.30 cm 3 /g, and the ratio of adsorbed gas ranged from 45.24 to 74.67%, with an average value of 54.9%. Comparison with other typical shale and coal formations in several sedimentary basins in China shows that the in situ gas content and adsorbed gas ratio of Wujiaping shale are higher than those of Longmaxi shale in the Sichuan Basin and Shahezi shale in the Songliao Basin but lower than those of Shanxi and Taiyuan coal in the Qinshui Basin. The Wujiaping shale in the study area has unique gas-bearing characteristics; the high in situ gas content shows its good resource potential, but the high adsorbed gas ratio puts forward higher technical requirements for the efficient development of this resource.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Gas-Bearing Characteristics of Permian Shales in Hongxing Area, Sichuan Basin, China: A Comprehensive Evaluation and Comparison Using Multiple Methods

Li,

Lu,

et al. 2024

Energy Fuels

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Differential evolution of pore fluid pressure in the Sinian carbonate reservoirs of the central and eastern Sichuan Basin, China: Implication for gas preservation and destruction

Chen,

et al. 2024

Geological Journal

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Trillions of cubic meters of gas reserve have been found in the Sinian Dengying carbonate reservoirs with normal pressure in the central Sichuan Basin, while no industrial gas reservoir have been detected in the Sinian Dengying reservoir with normal pressure in the eastern Sichuan Basin. The pore fluid pressure of gas reservoir is usually closely related to total gas content. To investigate the pore fluid pressure evolution and its implication for gas reserve preservation in the Sinian Dengying reservoir of the central and eastern Sichuan Basin, we conducted a comprehensive analysis including fluid inclusion petrography, microthermometry and Raman spectroscopy. The timings of gas inclusions captured in the central and eastern Sichuan Basin occurred from 175 to 92 Ma and 191 to 183 Ma, respectively. The presence of two‐phase vapour‐solid bitumen inclusions with similar phase proportions in a single fluid inclusion assemblage of fluorite provides direct evidence of in situ oil cracking to gas. The widespread solid bitumen from the Sinian Dengying reservoir in the central Sichuan Basin indicates the existence of massive oil cracking, which results in the formation of overpressure in the reservoir. Pore fluid pressure evolution of the Sinian Dengying reservoir of the central Sichuan Basin experiences normal pressure stage (200–155 Ma), overpressure development stage (155–90 Ma) and overpressure release stage (90–0 Ma). The maximum pore fluid pressure and its corresponding pressure coefficient of the Sinian Dengying reservoir of the central Sichuan Basin are approximately 141.4 MPa and 1.95, respectively. The overpressure development stage reflects the processes of oil cracking and gas accumulation, and the overpressure release stage reflects the dissipation of some natural gas in the Sinian Dengying reservoir of the central Sichuan Basin. The pore fluid pressure of the Sinian Dengying reservoir in the eastern Sichuan Basin has maintained at normal pressure since 200 Ma, indicating that the gas reservoir was small during the oil cracking stage and natural gas completely leaked due to tectonic uplift.

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Hydrocarbon accumulation and reconstruction in the Ediacaran Dengying carbonate reservoirs of the southeastern and central Sichuan Basin, SW China

Luo,

Guo,

et al. 2024

Journal of Asian Earth Sciences

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Quantitative Estimation on Methane Storage Capacity of Organic-Rich Shales from the Lower Silurian Longmaxi Formation in the Eastern Sichuan Basin, China

Cited by 7 publications

References 43 publications

Gas-Bearing Characteristics of Permian Shales in Hongxing Area, Sichuan Basin, China: A Comprehensive Evaluation and Comparison Using Multiple Methods

Gas-Bearing Characteristics of Permian Shales in Hongxing Area, Sichuan Basin, China: A Comprehensive Evaluation and Comparison Using Multiple Methods

Differential evolution of pore fluid pressure in the Sinian carbonate reservoirs of the central and eastern Sichuan Basin, China: Implication for gas preservation and destruction

Hydrocarbon accumulation and reconstruction in the Ediacaran Dengying carbonate reservoirs of the southeastern and central Sichuan Basin, SW China

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