A semi‐analytical model for capturing dynamic behavior of hydraulic fractures during flowback period in tight oil reservoir

Jia, Peng; Ma, Ming; Cheng, Linsong; Clarkson, Christopher R.

doi:10.1002/ese3.769

Cited by 10 publications

(4 citation statements)

References 43 publications

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“…In addition, as unconventional oil and gas resources are explored and developed, (semi)analytical solution, numerical simulation techniques are being developed to make the pressure and rate analysis (also known as PTA, RTA) with stress sensitivity [19][20][21]. However, few models have been reported considering the synthetical impact of sand migration and stress sensitivity [22][23][24][25].…”

Section: Introductionmentioning

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: Introductionmentioning

confidence: 99%

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

et al. 2021

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“…Actually, the partially water-covered boundary condition is widely existed in fractured reservoirs during water injection and unconventional reservoirs after hydraulic fracturing. Understanding the mechanism of oil recovery by spontaneous imbibition with partially water-covered boundary conditions can make a contribution to predicting production performance in fractured (Chen and Mohanty, 2013;Cui et al, 2020;Zhong et al, 2020) and unconventional reservoirs (He et al, 2020;Jia et al, 2020;Wang et al, 2018).…”

Section: Introductionmentioning

confidence: 99%

Effect of viscosity on oil recovery by spontaneous imbibition from partially water-covered matrix blocks

Zhang

et al. 2021

Energy Exploration & Exploitation

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Spontaneous imbibition is an important mechanism of oil recovery from fractured reservoirs and unconventional reservoirs. Oil is produced by combining co- and counter-current imbibition when the matrix blocks was partially covered by water. In this paper, we focused on the effect of viscosity ratios on oil production by spontaneous imbibition and established the numerical model for one-dimensional linear imbibition with TEO-OW boundary conditions, which was validated by the experimental data. The effect of viscosity ratio on co- and counter-current imbibition is investigated and scaling result of the imbibition recovery curve for wide range of viscosity ratio using the conventional scaling equation was tested, which indicates that the close correlation was achieved only when oil-water viscosity ratios are higher. Then, a modified scaling equation was developed based on the piston-like assumption for one-dimensional co-current imbibition and close correlation of imbibition recovery curves was achieved when viscosity ratios are lower. Finally, correlation of imbibition recovery curves was improved for wide range of viscosity ratios by combining conventional and modified scaling equation. Results show that since the shape of imbibition recovery curves is not similar for different viscosity ratios, it is difficult to obtain the perfect correlation using the constant viscosity term.

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“…However, these models are generally inappropriate for fractured wells. Semianalytical models capture the two-phase flow behavior in the fracture and have much higher computational efficiency than numerical simulation methods, which have recently attracted increasingly attention [25][26][27][28][29]. However, these methods are mainly employed for simulate early time flowback of fractured wells.…”

Section: Introductionmentioning

confidence: 99%

A Semianalytical Model for Simulating Fluid Flow in Tight Sandstone Reservoirs with a Bottom Aquifer

Wang¹,

Bai²,

Xu³

et al. 2021

Geofluids

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Water breaks through along fractures is a major concern in tight sandstone reservoirs with a bottom aquifer. Analytical models fail to handle the three-dimensional two-phase flow problem for partially penetrating inclined fractures, so time-consuming numerical simulation are often used for this problem. This paper presents an efficient semianalytical model for this problem considering three-dimensional fractures and two-phase flow. In the model, the hydraulic fracture is handled discretely with a numerical discrete method. The three-dimensional volumetric source function in real space and superposition principle are employed to solve the model analytically for fluid flow in the reservoir. The transient flow equations for flow in three-dimensional inclined fractures are solved by the finite difference method numerically, in which two-phase flow and stress-dependent properties are considered. The eventual solution of the model and transient responses are obtained by coupling the model for flow in the reservoir and discrete fracture dynamically. The validation of the semianalytical model is demonstrated in comparison to the solution of the commercial reservoir simulator Eclipse. Based on the proposed model, the effects of some critical parameters on the characteristics of water and oil flow performances are analyzed. The results show that the fracture conductivity, fracture permeability modulus, inclination angle of fractures, aquifer size, perforation location, and wellbore pressure drop significantly affect production rate and water breakthrough time. Lower fracture conductivity and larger inclination angle can delay the water breakthrough time and enhance the production rate, but the increment tends to decline gradually. Furthermore, water breakthrough will occur earlier if the wellbore pressure drop and aquifer size are larger. Besides, the stress sensitivity and perforation location can delay the water breakthrough time.

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A semi‐analytical model for capturing dynamic behavior of hydraulic fractures during flowback period in tight oil reservoir

Cited by 10 publications

References 43 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

Effect of viscosity on oil recovery by spontaneous imbibition from partially water-covered matrix blocks

A Semianalytical Model for Simulating Fluid Flow in Tight Sandstone Reservoirs with a Bottom Aquifer

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