Effect of tortuosity on the stress-dependent permeability of tight sandstones: Analytical modelling and experimentation

Wang, Fuyong; Cheng, Hui

doi:10.1016/j.marpetgeo.2020.104524

Cited by 24 publications

(25 citation statements)

References 41 publications

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“…During the development of unconsolidated sandstone reservoirs, sand particles migrate near the wellbore as pore pressure decreases, which aggravates the stress sensitivity effect. The stress-dependent permeability characterization formula has been reported [27][28][29]. Based on the exponential relation of permeability, as shown in Equation ( 1), a new stress sensitivity coefficient is introduced in this paper.…”

Section: Quantitative Characterization Of Key Parametersmentioning

confidence: 99%

Numerical Simulation Investigation on Well Performance Integrated Stress Sensitivity and Sand Production

et al. 2021

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For unconsolidated sanding wells, the interaction between sanding and pressure-dependent permeability as oil is produced from the bottom of the well puts higher challenges on the evaluation and prediction of well performance. Therefore, it is essential to assess the oil well performance considering the synthetic effect of stress-sensitive and produced sand particles. In this paper, a new stress-sensitive factor is proposed to describe the relationship between stress and permeability in the numerical model. Also, based on the rectangular plastic region by the sand migration near the perforation, a quantitative expression of the sanding area for numerical model calculation was established. Combined with a quantitative description of these two key parameters, a sand-producing horizontal well model is established to evaluate production performance. In this model, the area of sand production near the wellbore is considered as the inner area with increased permeability while the outer zone remains the original reservoir. Besides, the model was verified by the production data from the sand-producing horizontal well in the oilfield. Furthermore, sensitivity parameters (such as stress sensitivity, the size of sanding zone, well location, and reservoir boundaries) are used to make the analysis of well productivity, which provides a theoretical basis for petroleum engineers to adjust the development plan for horizontal wells in the weakly consolidated sandstone reservoir.

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Section: Quantitative Characterization Of Key Parametersmentioning

confidence: 99%

Numerical Simulation Investigation on Well Performance Integrated Stress Sensitivity and Sand Production

et al. 2021

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“…Using the exponential model between permeability and effective stress to simplify the porous reservoir into a capillary model, Wang and Cheng introduced the fractal theory to obtain the expression of effective permeability during rock compression [31]. It can be written as…”

Section: Model Construction and Solutionmentioning

confidence: 99%

“…There is a complex fracture network in the fractured area, and the dual porosity medium model is widely used to study the flow mechanism in the fractured area (Figure 3) [33,34]. Wang and Cheng used the slab model and fractal theory to build a mathematical model between the permeability and the effective stress of fracture system [31]:…”

Section: Model Construction and Solutionmentioning

confidence: 99%

Pressure Response of a Horizontal Well in Tight Oil Reservoirs with Stimulated Reservoir Volume

Chen¹,

Pingguo³

et al. 2021

Lithosphere

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Stimulated reservoir volume is an effective stimulation measure and creates a complex fracture network, but the description and characterization of fracture network are very difficult. Well test analysis is a common method to describe the fracture network, and it is the key to build a proper interpretation model. However, most published works only consider the shape of the fractured area or the stress sensitivity effect, and few works take both factors into account. In this paper, based on reservoir properties and flow law after a stimulated reservoir volume, an interpretation model is established with an arbitrary shape of the fractured area and stress sensitivity effect of different flow areas. The model is solved to conduct the pressure response using Laplace transform, point source function, and boundary element theory. The influence of fractures’ parameters and stress sensitivity effect is analyzed on the pressure behavior. Results from this study show that the special flow regimes for a horizontal well with a stimulated reservoir volume are (1) bilinear flow dominated by hydraulic fractures, (2) linear flow dominated by formation around the hydraulic fractures, (3) crossflow from a matrix system to the fractured area, and (4) radial flow control by properties of the fractured area. Parameters of hydraulic fractures mainly affect the early stage of pressure behavior. On the contrary, the stress-sensitive effect mainly affects the middle and late stages; the stronger the stress sensitivity effect is, the more obvious the effect is. The findings of this study can help for better understanding of the fracture network in a tight oil reservoir with a stimulated reservoir volume.

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“…In recent years, extensive research has been conducted on the gas permeability characteristics of sandstone (Amann-Hildenbrand et al, 2016;Fu et al, 2015;Ghanbarian et al, 2016;Wang et al, 2017b;Wang and Cheng., 2020;Wu et al, 2020;Zhang et al, 2019).…”

Section: Introductionmentioning

confidence: 99%

Gas Permeability Change With Deformation and Cracking of a Sandstone Under Triaxial Compressiongas Permeability Change With Deformation and Cracking of a Sandstone Under Triaxial Compression

Lin

Liu

Chen

et al. 2022

Preprint

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In this paper, a THMC (Thermal-Hydrological-Mechanical-Chemical) multi-field coupling triaxial cell was used to systematically study the evolution of gas permeability and the deformation characteristics of sandstone. The effects of confining pressure, axial pressure, and air pressure on gas permeability characteristics were fully considered in the test. The gas permeability of sandstone decreases with increasing confining pressure. When the confining pressure is low, the variation of gas permeability is greater than the variation of gas permeability at high confining pressure. The gas injection pressure has a significant effect on the gas permeability evolution of sandstone. As the gas injection pressure increases, the gas permeability of sandstone tends to decrease. At the same confining pressure, the gas permeability of the sample during the unloading path is less than the gas permeability of the sample in the loading path. When axial pressure is applied, it has a significant influence on the permeability evolution of sandstone. When the axial pressure is less than 30 MPa, the gas permeability of the sandstone increases as the axial pressure increases. At axial pressures greater than 30 MPa, the permeability decreases as the axial pressure increases. Finally, the micro-pore/fracture structure of the sample after the gas permeability test was observed using 3D X-ray CT imaging.

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Effect of tortuosity on the stress-dependent permeability of tight sandstones: Analytical modelling and experimentation

Cited by 24 publications

References 41 publications

Numerical Simulation Investigation on Well Performance Integrated Stress Sensitivity and Sand Production

Numerical Simulation Investigation on Well Performance Integrated Stress Sensitivity and Sand Production

Pressure Response of a Horizontal Well in Tight Oil Reservoirs with Stimulated Reservoir Volume

Gas Permeability Change With Deformation and Cracking of a Sandstone Under Triaxial Compressiongas Permeability Change With Deformation and Cracking of a Sandstone Under Triaxial Compression

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