Determining the permeability of tight rock with gas transient flow

Ling, Kegang; He, Jun; Pei, Peng; Han, Guoqing; Zhang, He

doi:10.1016/j.jngse.2013.07.003

Cited by 18 publications

(7 citation statements)

References 19 publications

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“…The porosity and permeability of samples were measured by gas flow method (Ling et al, 2013;Li et al, 2019). The porosity was measured using the ULTRAPORE-300 helium-porosity automatic measuring instrument (Core Lab, USA), while the permeability was measured using the DP-DYX-6G gas permeability measuring instrument (i.e., gas permeameter) (Beijing Yaou Depeng Technology Company, China).…”

Section: Samples and Methodsmentioning

confidence: 99%

The differential diagenesis controls on the physical properties of lithofacies in sandstone reservoirs from the Jurassic Shaximiao Formation, western Sichuan depression, China

Deng

et al. 2020

Journal of Petroleum Science and Engineering

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Section: Samples and Methodsmentioning

confidence: 99%

The differential diagenesis controls on the physical properties of lithofacies in sandstone reservoirs from the Jurassic Shaximiao Formation, western Sichuan depression, China

Deng

et al. 2020

Journal of Petroleum Science and Engineering

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“…To investigate the correlation between Biot"s coefficient and other petrophysical properties, we also measured sample porosity with gas compression method [13], and sample permeability with unsteady-state flow methods [14].…”

Section: Methodsmentioning

confidence: 99%

A new method to determine Biot's coefficients of Bakken samples

Rui²,

Ling

2016

Journal of Natural Gas Science and Engineering

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In recent years, the development of oil and gas from shale has proceeded quickly in the world through the use of multistage fracturing technology in horizontal well. However, without the knowledge of rock poroelastic characteristics, the successful rate of hydraulic fracturing will be low. Among those poroelastic characteristics, effective stress is required for creating artificial fractures in the shale formation. In this study a new method is proposed to measure the Biot"s coefficient, which is one of the key poroelastic parameters for calculating the effective stress.The Biot"s coefficient is obtained after the variations of both the confining and the pore pressures are recorded with a simplified measuring procedures. The Bakken shale samples from Williston Basin are tested. The experiment results show that the Biot"s coefficient of Bakken samples obtained from horizontal drilling and vertical drilling are significantly different from each other. This provides a solid base to scientists and engineers for Bakken in-situ stress analysis during multistage hydraulic fracturing and reservoir depletion due to production. IntroductionIn recent years, the development of oil and gas from shale has proceeded quickly in the world through the use of multistage fracturing technology in horizontal well. By creating the fractures to enlarge the stimulated reservoir

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“…Experimental methods can supply the necessary information, but are often costly, time consuming, or even impractical. 9 On the contrary, computer simulations are cost effective, but are often limited in terms of accuracy or availability of computational resources; 10 therefore, a compromise among the levels of detail needed, the accuracy expected, and the computational cost should be determined. For this work, we implement and compare three approaches to predict permeability of complex pore networks representing those identified in shale rocks.…”

Section: Introductionmentioning

confidence: 99%

Estimating permeability in shales and other heterogeneous porous media: Deterministic vs. stochastic investigations

Apostolopoulou

Dusterhoft

Day

et al. 2019

International Journal of Coal Geology

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With increasing global energy demands, unconventional formations, such as shale rocks, are becoming an important source of natural gas. Extensive efforts focus on understanding the complex behavior of fluids (including their transport in the sub-surface) to maximize natural gas yields. Shale rocks are mudstones made up of organic and inorganic constituents of varying pore sizes (1-500nm). With cutting-edge imaging technologies, detailed structural and chemical description of shale rocks can be obtained at different length scales. Using this knowledge to assess macroscopic properties, such as fluid permeability, remains challenging. Direct experimental measurements of permeability supply answers, but at elevated costs of time and resources. To complement these, computer simulations are widely available; however, they employ significant approximations, and a reliable methodology to estimate permeability in heterogeneous pore networks remains elusive. For this study, permeability predictions obtained by implementing two deterministic methods and one stochastic approach, using a kinetic Monte Carlo algorithm, are compared. This analysis focuses on the effects resulting from pore size distribution, the impact of micro-and macropores, and the effects of anisotropy (induced or naturally occurring) on the predicted matrix permeability. While considering multiple case studies, recommendations are provided on the optimal conditions under which each method can be used. Finally, a stochastic analysis is performed to estimate the permeability of an Eagle Ford shale sample using the kinetic Monte Carlo algorithm. Successful comparisons against experimental data demonstrate the appeal of the stochastic approach.

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Determining the permeability of tight rock with gas transient flow

Cited by 18 publications

References 19 publications

The differential diagenesis controls on the physical properties of lithofacies in sandstone reservoirs from the Jurassic Shaximiao Formation, western Sichuan depression, China

The differential diagenesis controls on the physical properties of lithofacies in sandstone reservoirs from the Jurassic Shaximiao Formation, western Sichuan depression, China

A new method to determine Biot's coefficients of Bakken samples

Estimating permeability in shales and other heterogeneous porous media: Deterministic vs. stochastic investigations

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