Numerical simulation of limited-entry multi-cluster fracturing in horizontal well

Li, Yang; Deng, Jingen; Liu, Wei; Yan, Wei; Feng, Yongcun; Cao, Wenke; Wang, Pengfei; Hou, Youlin

doi:10.1016/j.petrol.2017.03.023

Cited by 61 publications

(24 citation statements)

References 35 publications

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“…Fluid flows in at point 1 and exits at point 2. The calculation equation of the perforation pressure drop is given by [ 24 , 25 ]: …”

Section: Methodsmentioning

confidence: 99%

“…According to the perforation pressure drop calculation Eq ( 12 ), it can be seen that the number of perforating holes N and the diameter of perforating holes D p are the key factors affecting the frictional resistance of perforating holes that realize the flow distribution adjustment. At the same time, reference [ 14 ] found in the simulation process of the staged multi-cluster fracturing model that the calculation results of perforation clusters on both sides are symmetric and the number of cluster perforations on both sides can be set the same. Finally, three parameters are selected to optimize, respectively, the number of intermediate cluster perforations(A), the number of cluster perforations on both sides(B), and the diameter of intermediate cluster perforations(C).…”

Section: Response Optimization Design Methodsmentioning

confidence: 99%

“…A single-stage three-cluster fracturing model was established, proving that the flow distribution could be effectively regulated by controlling the hole friction and the impact of stress interference on the non-uniform fracture propagation could be reduced. Zhao [ 13 ] and Li [ 14 ] established a segmental multi-cluster model and numerically simulated the number of perforation holes in different perforation clusters, so as to control the hole friction and achieve uniform distribution of the flow of each perforation cluster. However, the above methods only consider the impact of a single factor on the fracture propagation of the formation in the process of studying the staged multi-cluster fracturing model, and do not consider multiple factors and the interaction between multiple factors at the same time.…”

Section: Introductionmentioning

confidence: 99%

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Research on optimization of perforation parameters for formation fractures based on response surface optimization method

et al. 2021

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For staged multi-cluster fracturing, methods for controlling perforation friction to adjust the flow distribution of each cluster can effectively promote the uniform extension of multiple fractures but lacks a fast and quantitative optimization method for different perforation parameters of each cluster. By establishing a numerical model of single-stage three-cluster flow-limited fracturing under stress-seepage coupling, and based on the response surface optimization method, fully considering the impact of perforation parameters interaction among three perforation clusters, according to the regression equation fitted under the global response, the rapid optimization of perforation parameters of segmented multi-cluster fracturing model is realized. The results show that: in determining the three factors of the study, it is found that there is an obvious interaction between the number of intermediate cluster perforations and the number of cluster perforations on both sides, the number of cluster perforations on both sides and the diameter of intermediate cluster perforations, the response surface optimization method gives the optimal perforation parameter combination of three clusters of fractures under global response; When the perforation parameters were combined before optimization, the fracture length difference was 32.550m, and the intermediate perforation cluster evolved into invalid perforation cluster, when the perforation parameters were combined after optimization, the fracture length difference was 0.528m, the three perforation clusters spread uniformly, and there are no invalid clusters. At the same time, the regression equation under the response is optimized before and after the comparison between the predicted value of the equation and the actual simulation value. It is found that the estimated deviation rate of the equation before optimization is 1.2%, and the estimated deviation rate after optimization is 0.4%. The estimated deviation rates are all less, and the response regression equation based on the response surface optimization method can quickly optimize the perforation parameters. The response surface optimization method is suitable for the multi parameter optimization research of formation fracturing which is often affected by many geological and engineering factors. Combining with the engineering practice and integrating more factors to optimize the hydraulic fracturing parameters, it is of great significance to improve the success rate of hydraulic fracturing application.

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“…Fluid flows in at point 1 and exits at point 2. The calculation equation of the perforation pressure drop is given by [ 24 , 25 ]: …”

Section: Methodsmentioning

confidence: 99%

Section: Response Optimization Design Methodsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Research on optimization of perforation parameters for formation fractures based on response surface optimization method

et al. 2021

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“…Therefore, when evaluating fracture injection pressures during SLFTP, effects of previous fracture can be neglected, while pore pressure enhancement, the minimum horizontal principal stress, rock tensile strength, and injection rate must be taken into consideration [43].…”

Section: Factors Influencingmentioning

confidence: 99%

Evaluations of Fracture Injection Pressure and Fracture Mouth Width during Separate-Layer Fracturing with Temporary Plugging

Wang

Zhou

Liang

et al. 2018

Mathematical Problems in Engineering

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Separate-layer fracturing with temporary plugging (SLFTP) is a potential way to stimulate multiple layer reservoirs due to its low cost, low risk, and high efficiency. In this study, based on the cohesive zone model (CZM), a 3D fully fluid-solid coupling and multiple layer model is established to investigate factors influencing fracture injection pressure and fracture mouth width. The cohesive layer properties are based on the reported study, which have been validated through a series of numerical experiments. Innovatively, the spring model is innovatively proposed to represent the plugging effect of diverting agents and prop the aperture of the previous fractures. Simulation results reveal that the effects of previous fractures in multiple layer formations can be neglected, which is quite different from multistage fracturing for horizontal wells. Fracture injection pressure can be evaluated more accurately by taking the following factors into consideration: the minimum horizontal principal stress, rock tensile strength, injection rate, and pore pressure enhancement. Further, fracture mouth width is strongly influenced by rock tensile strength, Young’s modulus, and injection rate. This study provides a guidance for candidate well selection and diverting agent optimization during SLFTP in multilayer formations.

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“…10 In addition, some advanced models have been implemented in various numerical frameworks such as finite element method (FEM), boundary element method (BEM), and discrete element method (DEM). In the framework of FEM, adaptive remeshing technique, [17][18][19][20] cohesive element, [21][22][23][24][25] and the partition of unity methods (eg, XFEM and GFEM) [26][27][28][29][30][31][32][33][34] are the most widely used tools for simulating hydraulic fracturing. Displacement discontinuity method (DDM), a special boundary element method which was first proposed by Crouch et al, 35 is particularly suitable for hydraulic fracture propagation modeling due to its relatively computational efficiency as well as simplicity of meshing and remeshing.…”

Section: Introductionmentioning

confidence: 99%

A 2D explicit numerical scheme–based pore pressure cohesive zone model for simulating hydraulic fracture propagation in naturally fractured formation

Liu

Deng

et al. 2019

Energy Science & Engineering

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In this work, a 2D pore pressure cohesive zone model is presented to simulate the hydraulic fracture propagation in naturally fractured formation, in which the fracturing process is governed by a bilinear cohesive zone model equipped with Coulomb's friction law and the fluid flow within the hydraulic fracture is described by the lubrication equation. In this model, fluid leak‐off into rock matrix is ignored and a fully explicit temporal integration scheme is adopted to overcome the convergence issue of conventional implicit scheme (eg, Newton‐Raphson method). The advantage of the proposed model is that it does not require any special crossing criterion to determine the interaction behavior when the hydraulic fracture hits the natural fracture. Implementation of the model was described in detail, and then, the model was verified with well‐known analytical solution of KGD problem and criteria of hydraulic fracture crossing natural fracture. The capability of the proposed model to capture the interaction behavior between hydraulic fracture and natural fracture was demonstrated by the good agreement of the modeling result and analytical solution. Several numerical cases were performed to investigate the impact of key factors on fracture network evolution during hydraulic fracturing treatment. Results show that fracture network is not only governed by the spatial distribution of natural fracture, but also greatly affected by the initial hydraulic aperture of natural fracture and in situ stress contrast.

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Numerical simulation of limited-entry multi-cluster fracturing in horizontal well

Cited by 61 publications

References 35 publications

Research on optimization of perforation parameters for formation fractures based on response surface optimization method

Research on optimization of perforation parameters for formation fractures based on response surface optimization method

Evaluations of Fracture Injection Pressure and Fracture Mouth Width during Separate-Layer Fracturing with Temporary Plugging

A 2D explicit numerical scheme–based pore pressure cohesive zone model for simulating hydraulic fracture propagation in naturally fractured formation

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