Study on Fluid-Rock Interaction and Reuse of Flowback Fluid for Gel Fracturing in Desert Area

Liang, Tianbo; Shao, Linjie; Yao, Erdong; Zuo, Jie; Liu, Xiongfei; Bao, Zhenmin; Zhou, Fujian

doi:10.1155/2018/8948961

Cited by 8 publications

(8 citation statements)

References 41 publications

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“…The scope of physicochemical analysis of flowback fluid reported in the literature is very diverse (He et al 2013;Hayes 2012;Olsson et al 2013;Yang 2019;Konieczyńska et al 2011;Konieczyńska et al 2015;Owen 2017;Owen and Bustin 2017;Liang et al 2018;Busby 2018;EA 2011;Zolfaghari et al 2015). Total dissolved solids concentration (TDS), pH, concentration of sodium, potassium, calcium, barium, strontium, iron, chloride, bromide, and sulfate are the most frequently reported in the literature.…”

Section: Chemical Characteristic Of Flowback Fluids From Worldwide Locationsmentioning

confidence: 99%

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Hydraulic fracturing flowback chemical composition diversity as a factor determining possibilities of its management

Fajfer

Lipińska

Konieczyńska

2021

Environ Sci Pollut Res

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The chemical characteristic of flowback fluid from hydraulic fracturing for shale gas exploration/production in various localizations is presented. The results of statistical analysis have shown that variability in the chemical composition of these fluids is statistically significant and depends on the time difference between fracturing process and flowback sampling as well as sampling spot within the installation for flowback collection. Parameters which depend on sampling schedule (time and spot of sampling) are as follows: electrical conductivity and concentration of ammonia, boron, barium, calcium, lithium, sodium, magnesium, manganese, sodium, strontium, silicate, bromide, and chloride. Independent parameters are pH, total organic carbon (TOC), concentration of potassium, and iron. The ranges of the values of the characteristic parameters were determined, taking into account the representativeness of the samples, supported by statistical tests. The methods for the reuse of flowback fluids in terms of chemical composition are presented.

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Section: Chemical Characteristic Of Flowback Fluids From Worldwide Locationsmentioning

confidence: 99%

“…Chinese studies concerned flowback fluids from boreholes in the Longmaxi shale formations of the Sichuan Basin (Yang et al 2019 ) and from the Tarim Basin (Liang et al 2018 )(Fig. 1 ).…”

Section: Introductionmentioning

confidence: 99%

Hydraulic fracturing flowback chemical composition diversity as a factor determining possibilities of its management

Fajfer

Lipińska

Konieczyńska

2021

Environ Sci Pollut Res

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“…The drainage and production data in the initial stage of well opening after fracturing is the first-hand data that can best reflect the effect of fracturing. In recent years, these data have been deeply studied to evaluate the fracturing effect of MFHWs [19][20][21][22][23][24][25]. The fracture network formed by fracturing is initially filled with fracturing fluid.…”

Section: Introductionmentioning

confidence: 99%

A Novel Mathematical Model for Fracturing Effect Evaluation Based on Early Flowback Data in Shale Oil Reservoirs

Wang

Lei

et al. 2021

Geofluids

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For shale oil reservoirs, the horizontal well multistage fracturing technique is mostly used to reform the reservoir in order to achieve economic and effective development. The size of the reservoir reconstruction volume and the quantitative characterization of the fracture system are of great significance to accurately predict the productivity of shale oil wells. There are few flowback models for shale oil reservoirs. To solve this problem, first, a physical model of the simultaneous production of oil, gas, and water in the early flowback stage of shale oil development is established using the material balance equation for a fracture system. Second, the physical model of the underground fracture system is simplified, which is approximately regarded as a thin cylindrical body with a circular section. The flow of the fluid in the fracture system is approximately regarded as radial flow. In this model, the expansion of the fluid and the closure of the fracture are defined as integrated storage coefficients to characterize the storage capacity of the fracture system. Then, the curves illustrating the relationships between the oil-water ratio and the cumulative oil production and between the gas-water ratio and the cumulative gas production are drawn, and the curves are used to divide the flowback stage into an early stage and a late stage because the flowback process of shale oil wells exhibits obvious stage characteristics. Finally, the reservoir reconstruction volume and the related hydraulic fracture parameters are estimated based on the material balance method, and the rationality of the model is verified via numerical simulation. The interpretation results of this novel model are more accurate, making it an effective way to evaluate the hydraulic fracture parameters and transformation effect, and it has guiding significance for the evaluation of the hydraulic fracturing effect in the field.

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“…Water permeation into a porous medium is a common phenomenon in many engineering fields: masonry structure [1][2][3][4], hydraulic fracturing [5][6][7][8][9], concrete [10][11][12][13], and carbon capture and storage (CCS) [14][15][16]. This phenomenon may cause the frost and salt damage to brickwork in masonry structures and the rot damage to wood structures [1].…”

Section: Introductionmentioning

confidence: 99%

“…Change of permeation depth with mobility. The correction coefficient of equation(16)is f κ y = −0 072 lg κ y − 0 365 9. Geofluids elastic modulus anisotropy and Poisson's ratio anisotropy are, respectively, defined as…”

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confidence: 99%

Numerical Simulations on the Front Motion of Water Permeation into Anisotropic Porous Media

Zhang

Wang

et al. 2019

Geofluids

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Water permeation into a porous medium is a common but important phenomenon in many engineering fields such as hydraulic fracturing. The water permeation front moves with time and may significantly impact the field variable evolution near the water front. Many algorithms have been developed to calculate this water front motion, but few numerical algorithms have been available to calculate the water front motion in anisotropic fluid-solid couplings with high computational efficiency. In this study, a numerical model is proposed to investigate the front motion of water permeation into an anisotropic porous medium. This model fully couples the mechanical deformation, fluid flow, and water front motion. The water front motion is calculated based on a directional Darcy’s flow in the anisotropic porous medium, and a revised formula with a correction coefficient is developed for the estimation of permeation depth. After verification with three sets of experimental data, this model is used to numerically investigate the impacts of permeability, viscosity, permeability anisotropy, and mechanical anisotropy on water front motion. Numerical results show that the proposed model can well describe the anisotropic water permeation process with reasonable accuracy. The permeation depth increases with permeability, mobility, and mechanical anisotropy but decreases with viscosity and permeability anisotropy. The correction coefficient mainly depends on porosity evolution, flow pattern, mobility, permeability anisotropy, and mechanical anisotropy.

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Study on Fluid-Rock Interaction and Reuse of Flowback Fluid for Gel Fracturing in Desert Area

Cited by 8 publications

References 41 publications

Hydraulic fracturing flowback chemical composition diversity as a factor determining possibilities of its management

Hydraulic fracturing flowback chemical composition diversity as a factor determining possibilities of its management

A Novel Mathematical Model for Fracturing Effect Evaluation Based on Early Flowback Data in Shale Oil Reservoirs

Numerical Simulations on the Front Motion of Water Permeation into Anisotropic Porous Media

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