An analytical model to couple gas storage and transport capacity in organic matter with noncircular pores

Sheng, Guanglong; Zhao, Hui; Su, Yuliang; Javadpour, Farzam; Wang, Chenchen; Zhou, Yuhui; Jing-Hua, Liu; Wang, Hui

doi:10.1016/j.fuel.2020.117288

Cited by 78 publications

(43 citation statements)

References 46 publications

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“…In 2020, Sheng et al propose a new approach to describe the complex migration mechanism, in which the digital cores are used to describe the pore structure, and analytical models were used to simulate gas flow mechanism ( Figure 4) [30]. Combining the planar pore structure obtained by CT scanning, the pore structure of porous media is comprehensively considered, and the dynamic change of pore size (stress sensitivity, desorption shrinkage), the apparent permeability model of organic/inorganic porous media coupled with microscale migration mechanism, and the apparent porosity model coupled gases with different occurrence states are proposed.…”

Section: Flow Parameters Calculation Of Porous Media In Shale Reservoirsmentioning

confidence: 99%

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A Review of Flow Mechanism and Inversion Methods of Fracture Network in Shale Gas Reservoirs

Huang

Sheng

et al. 2021

Geofluids

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The pore structure of shale gas reservoirs has strong heterogeneity, and the flow mechanism in multiscale media is complex. The fracture network of hydraulic fracturing is significantly affected by reservoir in situ stress, rock mechanical properties, and natural fracture distribution. At present, there is no efficient and accurate inversion method for fracture networks. Accurately describing fracture network morphology and flow capacity distribution of induced fracture is an important basis for production analysis, fracturing evaluation, and production plan. This article focuses on the hot issues of shale gas development, from three aspects: flow parameter characterization method of organic/inorganic matter, multiscale mass transfer simulation of shale gas reservoir, and inversion method of fracture network morphology and flow capacity, to introduce relevant research progress in detail. At the same time, the advantages and shortcomings of current related researches are compared and analyzed. Based on this, the key scientific problems existing on flow mechanisms and inversion method of fracture network in shale gas reservoirs are proposed, which can provide guidance for further research.

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Section: Flow Parameters Calculation Of Porous Media In Shale Reservoirsmentioning

confidence: 99%

“…Multimedia 3D apparent porosity/permeability model Figure 4: Approach for apparent porosity/permeability modeling of Complex porous media [30]. 5 Geofluids fracture network is reconstructed based on serial-sectioned digital images of a shale cube hydraulically fractured under true-triaxial conditions.…”

Section: Equivalent Integralmentioning

confidence: 99%

A Review of Flow Mechanism and Inversion Methods of Fracture Network in Shale Gas Reservoirs

Huang

Sheng

et al. 2021

Geofluids

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“…Multiple methods have been used to appraise the pore structure characteristics of tight reservoirs, which mainly include casting the thin section, scanning electron microscope (SEM), low-temperature nitrogen adsorption (NA), mercury intrusion porosimetry (MIP), low-field nuclear magnetic resonance (NMR) and computed tomography (CT) [28]. Both casting the thin section and SEM can directly observe the pore characteristics in two dimensions, but SEM has a higher resolution [29][30][31][32].…”

Section: Pore Throat Size Distribution Sem and Qemscan Analysismentioning

confidence: 99%

The Effect of Fracturing Fluid Saturation on Natural Gas Flow Behavior in Tight Reservoirs

Meng

Shen

et al. 2020

Energies

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Hydraulic fracturing becomes an essential method to develop tight gas. Under high injection pressure, fracturing fluid entering into the formation will reduce the flow channel. To investigate the influence of water saturation on gas flow behavior, this study conducted the gas relative permeability with water saturation and the flow rate with the pressure gradient at different water saturations. As the two dominant tight gas-bearing intervals, the Upper Paleozoic Taiyuan and Shihezi Formations deposited in Ordos Basin were selected because they are the target layers for holding vast tight gas. Median pore radius in the Taiyuan Formation is higher than the one in the Shihezi Formation, while the most probable seepage pore radius in the Taiyuan Formation is lower than the one in the Shihezi Formation. The average irreducible water saturation is 54.4% in the Taiyuan Formation and 61.6% in the Shihezi Formation, which indicates that the Taiyuan Formation has more movable water. The average critical gas saturation is 80.4% and 69.9% in these two formations, respectively, which indicates that the Shihezi Formation has more movable gas. Both critical gas saturation and irreducible water saturation have a negative relationship with porosity as well as permeability. At the same water saturation, the threshold gradient pressure of the Taiyuan Formation is higher than the one in the Shihezi Formation, which means that water saturation has a great influence on the Taiyuan Formation. Overall, compared with the Shihezi Formation, the Taiyuan Formation has a higher median pore size and movable water saturation, but water saturation has more influence on its gas flow capacity. Our research is conducive to understanding the effect of fracturing fluid filtration on the production of natural gas from tight reservoirs.

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“…Shale oil exploration and development enhance the necessity of determining the pore structures [1][2][3][4]. Previous studies have proved that oil-bearing shales generally have tiny pores and narrow throat [5][6][7].…”

Section: Introductionmentioning

confidence: 99%

Characterization of Shale Pore Structure by Multitechnique Combination and Multifractal Analysis and Its Significance

et al. 2020

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Understanding pore structure would enable us to obtain a deeper insight into the fluid mechanism in porous media. In this research, multifractal analysis by various experiments is employed to analyze the pore structure and heterogeneity characterization in the source rock in Ordos Basin, China. For this purpose, imaging apparatus, intrusion tests, and nonintrusion methods have been used. The results show that the objective shale reservoir contains complex pore network, and minor pores dominant the pore system. Both intrusion and nonintrusion methods detected pore size distributions show multifractal nature, while the former one demonstrates more heterogeneous features. The pore size distributions acquired by low temperature adsorption and nuclear magnetic resonance have relatively good consistence, indicating that similar pore network detection method may share the same mechanism, and the full-ranged pore size distributions need to be acquired by multitechniques. Chlorite has an obvious impact on the heterogeneity of pore structure in narrow pore size range, while illite and I/S mixed layer influence that in wide range. Kerogen index is the fundamental indicators of geochemical parameters. With the decrease of averaged small and middle/large pore radius, the heterogeneity of pore structures increase in narrow and wide ranges, respectively. This work employed a comprehensive methodology based on multitechniques and helps to explore how pore networks affect reservoir quality in shale reservoirs.

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An analytical model to couple gas storage and transport capacity in organic matter with noncircular pores

Cited by 78 publications

References 46 publications

A Review of Flow Mechanism and Inversion Methods of Fracture Network in Shale Gas Reservoirs

A Review of Flow Mechanism and Inversion Methods of Fracture Network in Shale Gas Reservoirs

The Effect of Fracturing Fluid Saturation on Natural Gas Flow Behavior in Tight Reservoirs

Characterization of Shale Pore Structure by Multitechnique Combination and Multifractal Analysis and Its Significance

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