Comparisons of pore size distribution: A case from the Western Australian gas shale formations

Hinai, Adnan Al; Rezaee, Reza; Esteban, Lionel; Labani, Mohammad Mahdi

doi:10.1016/j.juogr.2014.06.002

Cited by 210 publications

(104 citation statements)

References 42 publications

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“…Among the methods, the MICP is relatively fast and convenient. Hinai et al 47 confirmed that the MICP method can be a reliable technique for understanding pore throat size distribution decrease to 3 nm and determining most porosity involved in fluid transportation. The method is also reliable in shale samples.…”

Section: Spontaneous Imbibition In Porous Mediamentioning

confidence: 98%

Spontaneous Imbibition Process in Micro–nano Fractal Capillaries Considering Slip Flow

Shen

et al. 2018

Fractals

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An imbibition process of water into a matrix is required to investigate the influences of large-volume fracturing fluids on gas production of unconventional formations. Slip flow has been recognized by recent studies as a major mechanism of fluid transport in nanotubes. For nanopores in shale, a slip boundary is nonnegligible in the imbibition process. In this study, we established an analytic equation of spontaneous imbibition considering slip effects in capillaries. A spontaneous imbibition model that couples the analytic equation considering the slip effect was constructed based on fractal theory. We then used a model for various conditions, such as slip boundary, pore structure, and fractal dimension of pore tortuosity, to capture the imbibition characteristics considering the slip effect. A dynamic contact angle was integrated into the modeling. Results of our study verify that the slip boundary influences water imbibition significantly. The imbibition speed is significantly improved when slip length reaches the equivalent diameter of a tube. Therefore, disregarding the slip effect will underestimate the imbibition speed in shale samples.

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Section: Spontaneous Imbibition In Porous Mediamentioning

confidence: 98%

Spontaneous Imbibition Process in Micro–nano Fractal Capillaries Considering Slip Flow

Shen

et al. 2018

Fractals

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“…Subsequently, another concept related to Hydraulic Flow Units (HFUs) was proposed (Yan et al, 2011;Sachsenhofer and Koltun, 2012;Clarkson et al, 2013;Wilson et al, 2016), which was defined as the minimum units in reservoir and the volume of rocks with similar petrophysical character that affects fluid flow, and classified by Sedimentary Microfacies Zonations (SMZ). SMZ technique has many limitations in the quantitative division in the vertical and flame due to the fuzzy microphase bound (Hinai et al, 2014). First quantitative method was proposed by Amaefule et al (1993), using the parameters Flow Zone Indicator (FZI) and Reservoir Quality Indicators (RQI) derived from the modified Kozeny-Carmann (K-C) equation:…”

Section: Pore Type and Hfusmentioning

confidence: 99%

“…Summary for the current improved methods based on the K-C equation for HFUs determination established by Hinai et al (2014). pressure curve) is an important constitutive relationship in complex 3D porous structures for characterizing the transmission of fluid and mass, since it controls the fluids distribution in the pore space during drainage and imbibition processes.…”

Section: Capillary Pressure Curves From Pore-scale Modelingmentioning

confidence: 99%

Applications of digital core analysis and hydraulic flow units in petrophysical characterization

Chen

Zhou

2017

Adv. Geo-Energ. Res.

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Conventional petrophysical characterizations are often based on direct laboratory measurements. Although they provide accurate results, such measurements are time-consuming and limited by instrument and environment. What's more, in the georesource energy industry, availability and cuttings of core plugs are difficult. Because of these reasons, virtual digital core technology is of increasing interest due to its capability of characterizing rock samples without physical cores and experiments. Virtual digital core technology, also known as digital rock physics, is used to discover, understand and model relationships between material, fluid composition, rock microstructure and macro equivalent physical properties. Based on actual geological conditions, modern mathematical methods and imaging technology, the digital model of the core or porous media is created to carry out physical field numerical simulation. In this review, the methods for constructing digital porous media are introduced first, then the characterization of thin rock cross section and the capillary pressure curve using scanning electron microscope image under mixed wetting are presented. Finally, we summarize the hydraulic flow unit methods in petrophysical classification.Keywords: Digital core, porous media, petrophysical characterization, thin section, mercury injection capillary pressure.Citation: Chen, X., Zhou, Y. Applications of digital core analysis and hydraulic flow units in petrophysical characterization. Adv.

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“…Therefore, the distribution of the multiple exponential decay processes in rocks which are T 2 spectrum means the pore size distribution of the core. The pore throats reflected by T 2 spectral line of core of target block are mainly divided into three categories: clay-bound water pore, capillary-bound water pore, and free fluid pore [14,15]. T 2 spectrum cut-off value is obtained from empirical value and chart method.…”

Section: Relation Between Pore Throat Size and Nmr T 2 Spectrummentioning

confidence: 99%

Experimental Study on Water Sensitivity Difference Based on Oiliness of Porous Medium Rock

Li¹,

2017

Geofluids

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This study presents the differences of water sensitivity experiment of porous medium rock between conventional dry core samples and oil-bearing core. The comparison was made to analyze the impact of single-phase fluid and multiphase fluid on the actual sensitivity of rock. The nuclear magnetic resonance (NMR) test was carried out to reveal the distribution of oil in porous medium and the microscopic influence mechanism of oil phase. The study shows that the initial oil in place could isolate the clay from water, and then the expansion and the migration of the clay were prevented to reduce the decrease of degree of damage.

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Comparisons of pore size distribution: A case from the Western Australian gas shale formations

Cited by 210 publications

References 42 publications

Spontaneous Imbibition Process in Micro–nano Fractal Capillaries Considering Slip Flow

Spontaneous Imbibition Process in Micro–nano Fractal Capillaries Considering Slip Flow

Applications of digital core analysis and hydraulic flow units in petrophysical characterization

Experimental Study on Water Sensitivity Difference Based on Oiliness of Porous Medium Rock

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