Friction characteristics of proppant suspension and pack during slickwater hydraulic fracturing

Zhou, Hangyu; Guo, Jianchun; Zhang, Tao; Zeng, Jie

doi:10.1016/j.geoen.2023.211435

Cited by 7 publications

(3 citation statements)

References 31 publications

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“…Its curing temperature is 70 ˚C. The average grain size for 20/40 fusheng sand is 0.594 mm and the bulk density is 1.58 g/cm 3 . This resin-coated sand contains 4.7 wt % resin.…”

Section: Materials and Apparatusmentioning

confidence: 99%

“…It generally refers to proppant production phenomenon after a fractured well is put in production [1]. It leads to many negative effects including production loss, corrosion of surface and downhole equipments and increase of production costs etc., so some techniques must be applied to control proppant flowback during production of a fractured well [2,3]. One kind of such techniques is to consolidate proppant grains together and prevent them entering the wellbore.…”

Section: Introductionmentioning

confidence: 99%

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Feasibility of Proppant Flowback Control by Use of Resin-coated Proppant

Jiao,

Zhu,

Chang

et al. 2024

J. Basic Appl. Sci.

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Proppant flowback is a problem in Xinjiang oilfield. It decreases production rate of a fractured oil well, corrodes surface and downhole facilities and increases production costs. Curable resin-coated sand is a common technique to control proppant flowback. This article presents an experimental investigation whether it is feasible to control proppant flowback by use of resin-coated sand and whether resin-coated sand has a negative effect on proppant pack conductivity. It included two kinds of experiments, Proppant flowback experiment measured critical flow rate while the Proppant pack conductivity one measured proppant conductivity. The experimental results of proppant flowback show that the critical flow rate of resin-coated sand is far greater than that of common sand which means proppant flowback would not happen by resin-coated sand tail-in. Compared to Xinjiang sand conductivity, resin-coated sand conductivity is far smaller though it declines slightly which means use of resin-coated sand would lead to conductivity loss and sequentially results in production impairment. Experimental results show that it is feasible to control proppant flowback by use of resin-coated sand and resin-coated sand would affect fracture conductivity of a fractured oil well. Based on the experimental results, resin-coated proppant conductivity can be improved by use of resin-coated ceramic or liquid-resin-coated proppant. The achievements can give a direction towards how to select a resin-coated proppant and how to improve resin-coated proppant.

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“…Its curing temperature is 70 ˚C. The average grain size for 20/40 fusheng sand is 0.594 mm and the bulk density is 1.58 g/cm 3 . This resin-coated sand contains 4.7 wt % resin.…”

Section: Materials and Apparatusmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Feasibility of Proppant Flowback Control by Use of Resin-coated Proppant

Jiao,

Zhu,

Chang

et al. 2024

J. Basic Appl. Sci.

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“…), different proppant types (grain size (Sahai and Moghanloo, 2019), sphericity (Zhang, 2017), density (Hao, 2018;Li, 2018)), different carrying fluid viscosities (Anschutz et al, 2023;Zhang et al, 2021), different injection flow rates (Liang et al, 2018;Liu et al, 2019;Zhang et al, 2023b), different fracture types (eg. even-wide fractures (Liang et al, 2018), elliptical shape fractures (Zhu et al, 2023) or complex fractures (Li et al, 2024;Qu et al, 2023;Xiang and Li, 2023)) were also investigated in the indoor tests to obtain the proppant accumulation distribution under various conditions, which then served as a reference for optimization of the parameters of the hydraulic fracturing in the field, Bai and Li (2023) and Zhou et al (2023) did research on the friction and settling characteristics by indoor tests to provide parameters for numerical model. However, the model equipment of indoor tests during hydraulic fracturing does not fully simulate the actual situation of a fracture morphology in the subsurface.…”

Section: Introductionmentioning

confidence: 99%

Simulation and solution of a proppant migration and sedimentation model for hydraulically fractured inhomogeneously wide fractures

Peiqi,

Lin,

et al. 2024

Energy Exploration & Exploitation

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The distribution of proppant during hydraulic fracturing may directly contribute to the flow conductivity of the proppant fracture, so research on the migration and sedimentation of proppant in the fracture and the final distribution pattern is of great relevance. The mass conservation equations of proppant solids and fracturing fluid were adopted to describe the distribution of proppant migration and sedimentation in the fracture, improving the additional gravity coefficient by utilizing the density difference between proppant and fracturing fluid and the concentration of proppant, together with the proppant sedimentation velocity at different Reynolds numbers in this study. The flow coefficients were obtained by discretizing the system of equations through the finite volume method combined with the harmonic mean method and the upstream weight method. The concentration additional pressure gradient term was computed by using the Superbee format innovatively to improve the solution convergence of the model. Numerical simulations with identical parameters were compared with indoor test results, which fully verified the correctness of the model and the accuracy of the discrete solution based on the finite volume method. The effects of flow rate of fracturing fluid, ratio of injected sand, viscosity of fracturing fluid, grain size of proppant and density of proppant on proppant migration and sedimentation based on three elliptical fracture morphologies: even-wide, top-wide and bottom-narrow as well as top-narrow and bottom-wide were investigated and analyzed through comparing the rate of proppant front movement, the level of sweeping range and the degree of inhomogeneity in the range under different conditions. Findings of this study suggest that: (1) top-wide and bottom-narrow fractures are more preferable for homogenous sanding in the early stage of proppant injection, and top-narrow and bottom-wide fractures are best for sanding in the later stage; (2) the viscosity of fracturing fluid is the most influential factor on proppant migration and sedimentation, which increases in the range of 100 mPa.s to enhance the sweeping range and homogeneity of proppant sanding and therefore achieve a better fracturing effect.

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