Measuring anisotropic permeability using a cubic shale sample in a triaxial cell

Pan, Zhejun; Ma, Yong; Connell, Luke D.; Down, David I.; Camilleri, Michael

doi:10.1016/j.jngse.2015.05.036

Cited by 147 publications

(40 citation statements)

References 27 publications

(51 reference statements)

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“…For example, the emergence of oil and gas recovery from shale formations has led to renewed interest in laboratory measurements of anisotropic permeability properties of shale samples from major shale plays (e.g., Eagle Ford, Barnett in the US, and emerging plays elsewhere, e.g., Longmaxi formation, Sichuan Basin, China, and Vaca Muerta, Argentina). Numerous studies have detailed the permeability properties (e.g., [37,39]). For example, in Pan et al [39], the authors measured that the shale reservoir could have a horizontal permeability (about 200 nD) that is 25 times the vertical permeability (about 8 nD), and Mokhtari and Tutuncu [37] showed that the horizontal permeability is almost 4 times the vertical permeability.…”

Section: Discussionmentioning

confidence: 99%

“…Numerous studies have detailed the permeability properties (e.g., [37,39]). For example, in Pan et al [39], the authors measured that the shale reservoir could have a horizontal permeability (about 200 nD) that is 25 times the vertical permeability (about 8 nD), and Mokhtari and Tutuncu [37] showed that the horizontal permeability is almost 4 times the vertical permeability. More permeability measurement results are given in Table 2.…”

Section: Discussionmentioning

confidence: 99%

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Rules for Flight Paths and Time of Flight for Flows in Porous Media with Heterogeneous Permeability and Porosity

Zuo

Weijermars

2017

Geofluids

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Porous media like hydrocarbon reservoirs may be composed of a wide variety of rocks with different porosity and permeability. Our study shows in algorithms and in synthetic numerical simulations that the flow pattern of any particular porous medium, assuming constant fluid properties and standardized boundary and initial conditions, is not affected by any spatial porosity changes but will vary only according to spatial permeability changes. In contrast, the time of flight along the streamline will be affected by both the permeability and porosity, albeit in opposite directions. A theoretical framework is presented with evidence from flow visualizations. A series of strategically chosen streamline simulations, including systematic spatial variations of porosity and permeability, visualizes the respective effects on the flight path and time of flight. Two practical rules are formulated. Rule 1 states that an increase in permeability decreases the time of flight, whereas an increase in porosity increases the time of flight. Rule 2 states that the permeability uniquely controls the flight path of fluid flow in porous media; local porosity variations do not affect the streamline path. The two rules are essential for understanding fluid transport mechanisms, and their rigorous validation therefore is merited.

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Section: Discussionmentioning

confidence: 99%

Section: Discussionmentioning

confidence: 99%

Rules for Flight Paths and Time of Flight for Flows in Porous Media with Heterogeneous Permeability and Porosity

Zuo

Weijermars

2017

Geofluids

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“…So it is very important to study gas production in shale matrix during exploration. Shale matrix is mainly composed of clay minerals and organic matters, which provide flow channels with different sizes (Curtis, 2002;Loucks et al, 2009;Passey et al, 2010;Liu et al, 2011;Pan et al, 2015;de Swaan A., 2014;Romero-Sarmiento et al, 2015).…”

Section: Introductionmentioning

confidence: 99%

Physical and mathematical modeling of gas production in shale matrix

Guo

Zhang

et al. 2018

Oil & Gas Science and Technology - Rev. IFP Energies nouvel

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Abstract. Shale gas mainly stores in shale matrix, and gas production in shale matrix is very important during exploration. In order to clarify gas production and transport mechanism in shale matrix, an experimental modeling of gas production in shale matrix was designed and conducted with Longmaxi shale samples collected from South of Sichuan. The experimental results show that gas production decline curve displays a "L" pattern which indicates initial production is high and declines rapidly, while late production is low and declines moderately; meanwhile, pressure propagation in shale matrix is quite slow due to ultralow permeability. Based on the results, a mathematical model was derived to describe gas production in shale matrix. The comparison between numerical solution of mathematical model and experimental results shows that the mathematical model can well describe gas transport in shale matrix. In addition, factors affecting gas production were investigated on the basis of the mathematical model. Adsorbed gas can replenish gas pressure in pores by desorption and delay pressure propagation, and gas production decreases very quickly when there is no adsorbed gas. Other parameters (diffusion coefficient, permeability and porosity) also need to be considered in shale gas development.

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“…Shale oil and gas reservoirs are of relatively low permeability and porosity, and most hydrocarbons are stored in their tight matrixes [1,2]. Largescale hydraulic fracturing serves as an effective means of exploiting shale formation.…”

Section: Introductionmentioning

confidence: 99%

Ion Diffusion Behavior between Fracturing Water and Shale and Its Potential Influence on Production

Shen

Zhu

Shi

et al. 2017

Journal of Chemistry

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Water imbibition, conductivity measurements, and ion identification were performed to investigate ion diffusion behavior between slick water and shale for large-scale hydraulic fracturing. The results indicated that there was strong ion exchange between water and shale. The ion concentration in water increases with fracture complexity and is dependent on the salinity of fracturing fluids. This implies that fracturing effects could be forecast from flow-back fluid ion concentrations after large-scale slick water fracturing. Higher levels of ion diffusion imply the presence of larger fracturing areas and higher level of fracture density for a similar reservoir. The mechanism of ion diffusion and the corresponding effects on IOR (increased oil recovery) based on a field example are discussed.

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Measuring anisotropic permeability using a cubic shale sample in a triaxial cell

Cited by 147 publications

References 27 publications

Rules for Flight Paths and Time of Flight for Flows in Porous Media with Heterogeneous Permeability and Porosity

Rules for Flight Paths and Time of Flight for Flows in Porous Media with Heterogeneous Permeability and Porosity

Physical and mathematical modeling of gas production in shale matrix

Ion Diffusion Behavior between Fracturing Water and Shale and Its Potential Influence on Production

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