A dynamic apparent permeability model for shale microfractures: Coupling poromechanics, fluid dynamics, and sorption-induced strain

2020 ◽  
Vol 74 ◽  
pp. 103104 ◽  
Author(s):  
Yudan Li ◽  
Pingchuan Dong ◽  
Dawei Zhou
Keyword(s):  
Fluid Dynamics ◽  
Apparent Permeability ◽  
Permeability Model

Apparent permeability model for gas transport in shale reservoirs with nano-scale porous media

2018 ◽  
Vol 55 ◽  
pp. 508-519 ◽  
Author(s):  
Shan Wang ◽  
Juntai Shi ◽  
Ke Wang ◽  
Zheng Sun ◽  
Yanan Miao ◽  
...  
Keyword(s):  
Porous Media ◽  
Gas Transport ◽  
Apparent Permeability ◽  
Permeability Model ◽  
Nano Scale ◽  
Shale Reservoirs

scholarly journals Apparent Permeability Model for Gas Transport in Multiscale Shale Matrix Coupling Multiple Mechanisms

Energies ◽  
2020 ◽  
Vol 13 (23) ◽  
pp. 6323
Author(s):  
Xiaoping Li ◽  
Shudong Liu ◽  
Ji Li ◽  
Xiaohua Tan ◽  
Yilong Li ◽  
...  
Keyword(s):  
Pore Size ◽  
Water Distribution ◽  
Gas Transport ◽  
Water Saturation ◽  
Gas Permeability ◽  
Apparent Permeability ◽  
Permeability Model ◽  
Proposed Model ◽  
Irreducible Water Saturation ◽  
The Impact

Apparent gas permeability (AGP) is a significantly important parameter for productivity prediction and reservoir simulation. However, the influence of multiscale effect and irreducible water distribution on gas transport is neglected in most of the existing AGP models, which will overestimate gas transport capacity. Therefore, an AGP model coupling multiple mechanisms is established to investigate gas transport in multiscale shale matrix. First, AGP models of organic matrix (ORM) and inorganic matrix (IOM) have been developed respectively, and the AGP model for shale matrix is derived by coupling AGP models for two types of matrix. Multiple effects such as real gas effect, multiscale effect, porous deformation, irreducible water saturation and gas ab-/de-sorption are considered in the proposed model. Second, sensitive analysis indicates that pore size, pressure, porous deformation and irreducible water have significant impact on AGP. Finally, effective pore size distribution (PSD) and AGP under different water saturation of Balic shale sample are obtained based on proposed AGP model. Under comprehensive impact of multiple mechanisms, AGP of shale matrix exhibits shape of approximate “V” as pressure decrease. The presence of irreducible water leads to decrease of AGP. At low water saturation, irreducible water occupies small inorganic pores preferentially, and AGP decreases with small amplitude. The proposed model considers the impact of multiple mechanisms comprehensively, which is more suitable to the actual shale reservoir.

A FRACTAL PERMEABILITY MODEL FOR REAL GAS IN SHALE RESERVOIRS COUPLED WITH KNUDSEN DIFFUSION AND SURFACE DIFFUSION EFFECTS

Fractals ◽  
2020 ◽  
Vol 28 (01) ◽  
pp. 2050017 ◽  
Author(s):  
TAO WU ◽  
SHIFANG WANG
Keyword(s):  
Fractal Dimension ◽  
Surface Diffusion ◽  
Shale Gas ◽  
Gas Transport ◽  
Fractal Theory ◽  
Knudsen Diffusion ◽  
Apparent Permeability ◽  
Permeability Model ◽  
Real Gas ◽  
Shale Reservoirs

A better comprehension of the behavior of shale gas transport in shale gas reservoirs will aid in predicting shale gas production rates. In this paper, an analytical apparent permeability expression for real gas is derived on the basis of the fractal theory and Fick’s law, with adequate consideration of the effects of Knudsen diffusion, surface diffusion and flexible pore shape. The gas apparent permeability model is found to be a function of microstructural parameters of shale reservoirs, gas property, Langmuir pressure, shale reservoir temperature and pressure. The results show that the apparent permeability increases with the increase of pore area fractal dimension and the maximum effective pore radius and decreases with an increase of the tortuosity fractal dimension; the effects of Knudsen diffusion and surface diffusion on the total apparent permeability cannot be ignored under high-temperature and low-pressure circumstances. These findings can contribute to a better understanding of the mechanism of gas transport in shale reservoirs.

Apparent permeability model for shale oil transport through elliptic nanopores considering wall-oil interaction

2019 ◽  
Vol 176 ◽  
pp. 1041-1052 ◽  
Author(s):  
Han Wang ◽  
Yuliang Su ◽  
Zhenfeng Zhao ◽  
Wendong Wang ◽  
Guanglong Sheng ◽  
...  
Keyword(s):  
Shale Oil ◽  
Apparent Permeability ◽  
Permeability Model ◽  
Oil Transport

scholarly journals An apparent permeability model of shale gas under formation conditions

2017 ◽  
Vol 14 (4) ◽  
pp. 833-840 ◽  
Author(s):  
Peng Chen ◽  
Shan Jiang ◽  
Yan Chen ◽  
Shanshan Wang
Keyword(s):  
Shale Gas ◽  
Apparent Permeability ◽  
Permeability Model ◽  
Formation Conditions

Influence of Borneol on In Vitro Corneal Permeability and on In Vivo and In Vitro Corneal Toxicity

2009 ◽  
Vol 37 (3) ◽  
pp. 791-802 ◽  
Author(s):  
H Yang ◽  
Y Xun ◽  
Z Li ◽  
T Hang ◽  
X Zhang ◽  
...  
Keyword(s):  
Clinical Investigation ◽  
In Vitro Toxicity ◽  
Corneal Tissue ◽  
Apparent Permeability ◽  
Permeability Model ◽  
Corneal Permeability ◽  
Hydrophilic Drugs ◽  
Corneal Toxicity

This study examined whether borneol could enhance corneal drug permeability. Model drugs containing either synthetic or natural borneol were co-administered to isolated intact or de-epithelialized rabbit corneas and the apparent permeability coefficients were measured. Draize tests in rabbits and levels of isolated intact rabbit corneal hydration were used to measure in vivo and in vitro toxicity, respectively. Synthetic borneol (0.1%) increased corneal penetration of the lipophilic agents, indomethacin and dexamethasone, by 1.23 and 2.40, respectively, and of the hydrophilic agents, ofloxacin, ribavirin and tobramycin, by 1.87, 2.80 and 3.89, respectively. For natural borneol, the corresponding fold increases were 1.67, 2.00, 2.15, 2.18 and 3.39, respectively. Removing the epithelium attenuated the penetration-enhancing effects of borneol. Borneol (0.1%) did not damage corneal tissue. The ability of borneol to enhance drug penetration through the outer corneal layer, particularly for highly-hydrophilic drugs, suggests that further clinical investigation may be warranted.

Permeability of Organic-Rich Shale

SPE Journal ◽  
2015 ◽  
Vol 20 (06) ◽  
pp. 1384-1396 ◽  
Author(s):  
Asana Wasaki ◽  
I. Yucel Akkutlu
Keyword(s):  
Pore Pressure ◽  
History Matching ◽  
Molecular Transport ◽  
Measured Quantity ◽  
Stress Dependence ◽  
Well Performance ◽  
Apparent Permeability ◽  
Permeability Model ◽  
The Impact ◽  
Sorbed Phase

Summary Measured permeability of an organic-rich shale sample varies significantly with applied laboratory conditions, such as the confining pressure, temperature, and the measurement fluid type. This indicates that the measured quantity is influenced by several mechanisms that add complexity to the measurement. The complexity is mainly caused by stress dependence of the matrix permeability. Also, it is because organic-rich shale holds significant volumes of fluids in sorbed (adsorbed, dissolved) states; sorption can also influence the permeability through its own storage and transport mechanisms. The stress-dependence and sorption effects on permeability could develop under the reservoir conditions and influence the production, although we currently do not have a predictive permeability model that considers their coexistence. In this work, this is accomplished by considering that the shale matrix consists of multiple continua with organic and inorganic pores. Stress dependency of the permeability comes along with slit-shaped pores, whereas the sorption effects are associated with nanoscale organic capillaries. A simple conceptual flow model with an apparent shale permeability is developed that couples the molecular-transport effects of the sorbed phase with the stress dependence of the slit-shaped pores. The simulation results show the impact of the permeability model on the production. Sensitivity analysis on the new permeability model shows that the stress dependence of the overall transport is significant at high pore pressure, when the effective stress is relatively low. Diffusive molecular transport of the sorbed phase becomes important as the stress gets larger and, hence, the slit-shaped pores close. The constructed apparent-permeability vs. pore-pressure curves show the dominance of the molecular transport as an increase in permeability characterized by appearance of a minimum permeability value at the intermediate values of the pressure. One can use the new permeability model easily in history matching a well performance and optimizing its production.

scholarly journals Apparent Permeability Model for Shale Gas Reservoirs Considering Multiple Transport Mechanisms

Geofluids ◽  
2018 ◽  
Vol 2018 ◽  
pp. 1-18 ◽  
Author(s):  
Shijun Huang ◽  
Yonghui Wu ◽  
Linsong Cheng ◽  
Hongjun Liu ◽  
Yongchao Xue ◽  
...  
Keyword(s):  
High Pressure ◽  
Viscous Flow ◽  
Surface Diffusion ◽  
Adsorption Layer ◽  
Pore Diameter ◽  
Adsorbed Layer ◽  
The Other ◽  
Transport Mechanisms ◽  
Apparent Permeability ◽  
Permeability Model

Shale formation is featured in nanopores and much gas adsorptions. Gas flow in the shale matrix is not a singular viscous flow, but a combination of multiple mechanisms. Much work has been carried out to analyze apparent permeability of shale, but little attention has been paid to the effect of unique gas behavior in nanopores at high pressure and adsorbed layer on apparent permeability. This work presents a new model considering multiple transport mechanisms including viscous flow (without slip), slip flow, Knudsen diffusion, and surface diffusion in the adsorption layer. Pore diameter and mean free path of gas molecules are corrected by considering the adsorption layer and dense gas effect, respectively. Then the effects of desorption layer, surface diffusion, and gas behavior on gas apparent permeability in nanopores of shale are analyzed. The results show that surface diffusion is the dominant flow mechanism in pores with small diameter at low pressure and that the effect of adsorbed layer and dense gas on apparent permeability is strongly affected by pressure and pore diameter. From the analysis results, the permeability value calculated with the new apparent permeability model is lower than in the other model under high pressure and higher than in the other model under high pressure, so the gas production calculated using the new permeability model will be lower than using the other model at early stage and higher than using the other model at late stage.

Sign in / Sign up

Export Citation Format

Share Document