Review of Permian Completion Designs and Results

Jaripatke, Omkar A.; Barman, Indranil; Ndungu, John; Schein, Gary W.; Flumerfelt, Raymond W.; Burnett, Nikki; Bello, Hector; Barzola, Gervasio

doi:10.2118/191560-ms

Cited by 12 publications

(4 citation statements)

References 4 publications

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“…For example, during the hydraulic fracturing process, the creation of more dense secondary fractures could yield significant increases in production rates. This observation is consistent with field measurements during the development of the Wolfcamp and Spraberry fields (Jaripatke et al 2018). Improvements in the network's porosity are also expected to be beneficial, but only after the 'critical' threshold of ~ 30% porosity is reached.…”

Section: Discussion and Sensitivity Analysissupporting

confidence: 86%

A Novel Modeling Approach to Stochastically Evaluate the Impact of Pore Network Geometry, Chemistry and Topology on Fluid Transport

et al. 2020

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Fine-grained sandstones, siltstones, and shales have become increasingly important to satisfy the ever-growing global energy demands. Of particular current interest are shale rocks, which are mudstones made up of organic and inorganic constituents of varying pore sizes. These materials exhibit high heterogeneity, low porosity, varying chemical composition and low pore connectivity. Due to the complexity and the importance of such materials, many experimental, theoretical and computational efforts have attempted to quantify the impact of rock features on fluids diffusivity and ultimately on permeability. In this study, we introduce a stochastic kinetic Monte Carlo approach developed to simulate fluid transport. The features of this approach allow us to discuss the applicability of 2D vs 3D models for the calculation of transport properties. It is found that a successful model should consider realistic 3D pore networks consisting of pore bodies that communicate via pore throats, which however requires a prohibitive amount of computational resources. To overcome current limitations, we present a rigorous protocol to stochastically generate synthetic 3D pore networks in which pore features can be isolated and varied systematically and individually. These synthetic networks do not correspond to real sample scenarios but are crucial to achieve a systematic evaluation of the pore features on the transport properties. Using this protocol, we quantify the contribution of the pore network’s connectivity, porosity, mineralogy, and pore throat width distribution on the diffusivity of supercritical methane. A sensitivity analysis is conducted to rank the significance of the various network features on methane diffusivity. Connectivity is found to be the most important descriptor, followed by pore throat width distribution and porosity. Based on such insights, recommendations are provided on possible technological approaches to enhance fluid transport through shale rocks and equally complex pore networks. The purpose of this work is to identify the significance of various pore network characteristics using a stochastic KMC algorithm to simulate the transport of fluids. Our findings could be relevant for applications that make use of porous media, ranging from catalysis to radioactive waste management, and from environmental remediation to shale gas production.

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Section: Discussion and Sensitivity Analysissupporting

confidence: 86%

A Novel Modeling Approach to Stochastically Evaluate the Impact of Pore Network Geometry, Chemistry and Topology on Fluid Transport

et al. 2020

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“…In the main shale area of North America, the well spacing is mostly about 100-300 m. The cluster spacing has shortened to less than 5 m, and the cluster number has increased to more than 15 clusters in a stage to obtain proper fracture length to match the small well spacing [44,45]. In terms of fracture nonpropagation and fracture uneven propagation due to the mechanical property of shale formation and small cluster spacing, limited-entry perforation and diversion technology are introduced to enhance the cluster efficiency and fracture complexity.…”

Section: Geofluidsmentioning

confidence: 99%

Investigation on Nonuniform Extension of Hydraulic Fracture in Shale Gas Formation

Zhao¹,

Zheng

Kang

et al. 2021

Geofluids

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Hydraulic fracturing with multiple clusters has been a significant way to improve fracture complexity and achieve high utilization of shale formation. This technology has been widely applied in the main shale area of North America. In Changning shale block of China, it, as a promising treatment technology, is being used in horizontal well now. Due to the anisotropy of mechanical property and the stress shadowing effect between multiclusters, fractures would extend nonuniformly and even some clusters are invalid, leading to a poor treatment performance. In this work, based on the geology and engineering characteristics of Changning shale block, different cluster number, cluster spacing, perforation distribution, and flow rate were discussed by the numerical simulation method to clarify multifracture propagation. It is implied that with the reduction of cluster number and the growth of cluster spacing and flow rate, the length and average width of interior fractures are inclined to increase due to the mitigation of stress shadowing effect, contributing to the lower standard deviation (SD) of fracture length, but too small cluster number or too large cluster spacing is not recommended. Besides, the perforation distribution with more perforations in interior fractures can get larger length and average width of interior fractures compared with another two perforation distributions because of more fractional flow rates obtained, which results in more even fracture propagations. In Changning shale block, multicluster hydraulic fracturing with 4-6 clusters in a stage has been employed in 300-400 m well spacing, and diversion technology, limited-entry perforation (36-48 perforations per stage), high flow rate (16 m3/min), and small-sized ceramic proppant (100 mesh) are used to get better shale gas production. To promote the even propagation of fractures further, nonuniform perforation distribution should be introduced in the target shale area.

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“…Practical experiences in the Permian Basin of the United States have shown that the production of the parent wells can alter the magnitude and the azimuthal orientation of the in-situ stresses, thereby influencing the production of the infill wells (Pankaj, 2018;Zheng et al, 2018). Considering the inter-well stress evolution pattern in Marcellus shale, the optimal well spacing was determined by establishing the relationship between well spacing and single well fracturing scale (Jaripatke et al, 2018). Huang et al analyzed the effect of the fracturing parameters on the inter-fracture stresses by using the three-dimensional lattice method and the dislocation theory.…”

Section: Introductionmentioning

confidence: 99%

Investigation into the dynamic change pattern of the stress field during integral fracturing in deep reservoirs

Lv,

Luo

et al. 2023

Front. Energy Res.

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Deep reservoirs have high temperature, high pressure, and high stress. The development of such resources is high cost. Integral fracturing applies one-time well displacement, batch drilling, and batch fracturing. Multiple wells are stimulated with zipper fracturing. It can avoid the interference of the well drilling and fracturing. In this way, the spatial stresses can be utilized to generate the complex fracture network. The dynamic change pattern of the stress field is of great value for the design of integral fracturing. Based on the displacement discontinuity method (DDM) and the fracture mechanics criteria, a whole fracture propagation program is developed to calculate the spatial stress distribution and the whole fracture geometry. The reliability of the program is verified against the classical analytical solutions. Based on the program, this work systematically investigates the effects of the fracture length, the fracturing sequence, the fracture distribution mode, and the injection pressure on the stress field. The main conclusions are as follows: 1) When the fracture half-length is 150 m and the well spacing is 300 m, the staggered fracture distribution mode can ensure uniform fracture propagation and realize the active utilization of inter-well stress field; 2) Compared with the relative fracture distribution mode, the staggered fracture distribution mode is less susceptible to the stress field induced by the adjacent hydraulic fractures, hydraulic fractures tend to propagate along the direction of the maximum horizontal principal stress; 3) The stress field is highly influenced by the in-fracture fluid pressure. The stress interference is stronger with a greater fluid injection pressure and a higher fracture deflection angle will be obtained. It can enhance the fracture propagation resistance and increase the stress value. This work discovers the stress change pattern and lays out a solid foundation for the optimization of the integral fracturing.

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Review of Permian Completion Designs and Results

Cited by 12 publications

References 4 publications

A Novel Modeling Approach to Stochastically Evaluate the Impact of Pore Network Geometry, Chemistry and Topology on Fluid Transport

A Novel Modeling Approach to Stochastically Evaluate the Impact of Pore Network Geometry, Chemistry and Topology on Fluid Transport

Investigation on Nonuniform Extension of Hydraulic Fracture in Shale Gas Formation

Investigation into the dynamic change pattern of the stress field during integral fracturing in deep reservoirs

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