Hydraulic Fracturing

Guo, Boyun; Liu, Xinghui; Tan, Xuehao

doi:10.1016/b978-0-12-809374-0.00014-3

Cited by 7 publications

(2 citation statements)

References 60 publications

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“…Figure 4 presents the pumping rate of linear gel which amounts to approximately 2 m 3 /min, and N 2 is introduced at the same rate. Net pressure-one of the most important parameters during the fracturing treatment-as the difference between the bottom dynamic pressure during treatment and the fracture closure pressure [38][39][40], behaves similarly in both simulated cases. Maximum value is reached at the end of fracturing treatments and amounts to 76.1 bar for non-foamed fluid and 83.9 bar for foamed fluid, respectively.…”

Section: D Simulation Resultsmentioning

confidence: 99%

Experimental and Simulation Studies of Energized Fracturing Fluid Efficiency in Tight Gas Formations

Wilk

2019

Energies

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The use of water-based fracturing fluids during fracturing treatment can be a problem in water-sensitive formations due to the permeability damage hazard caused by clay minerals swelling. The article includes laboratory tests, analyses and simulations for nitrogen foamed fracturing fluids. The rheology and filtration coefficients of foamed fracturing fluids were examined and compared to the properties of conventional water-based fracturing fluid. Laboratory results provided the input for numerical simulation of the fractures geometry for water-based fracturing fluids and 50% N2 foamed fluids, with addition of natural, fast hydrating guar gum. The results show that the foamed fluids were able to create shorter and thinner fractures compared to the fractures induced by the non-foamed fluid. The simulation proved that the concentration of proppant in the fracture and its conductivity are similar or slightly higher when using the foamed fluid. The foamed fluids, when injected to the reservoir, provide additional energy that allows for more effective flowback, and maintain the proper fracture geometry and proppant placing. The results of laboratory work in combination with the 3D simulation showed that the foamed fluids have suitable viscosity which allows opening the fracture, and transport the proppant into the fracture, providing successful fracturing operation. The analysis of laboratory data and the performed computer simulations indicated that fracturing fluids foamed by nitrogen are a good alternative to non-foamed fluids. The N2-foamed fluids exhibit good rheological parameters and proppant-carrying capacity. Simulated fracture of water-based fracturing fluid is slightly longer and higher compared to foamed fluid. At the same time, when using a fluid with a gas additive, the water content in fracturing fluid is reduced which means the minimization of the negative results of the clay minerals swelling.

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Section: D Simulation Resultsmentioning

confidence: 99%

Experimental and Simulation Studies of Energized Fracturing Fluid Efficiency in Tight Gas Formations

Wilk

2019

Energies

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“…Therefore, for many oil companies, the development of hydrocarbon stimulation methods is a priority. Stimulation treatments, such as HF [4,5,6], matrix acidizing, acid fracturing [7,8,9], or EOR [6,10,11,12] are common techniques used to increase the extraction productivity. In all aforementioned cases, the stimulation (injection) fluid is a crucial element and must meet special requirements depending on the goal of the application [13,14,15].…”

Section: Introductionmentioning

confidence: 99%

Impact of Nitrogen Foamed Stimulation Fluids Stabilized by Nanoadditives on Reservoir Rocks of Hydrocarbon Deposits

2019

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The first objective of this experiment was to improve the stabilization of N2 based foam with nanoparticles as an alternative to typical fracturing fluid, which consists of a gelling agent (HPG—hydroxypropyl guar). The second objective of the project was to investigate the damage caused by nanoparticle–based nitrogen foamed fracturing fluids (F.F) on a reference sandstone, using permeability and porosity tests, optical microscope with a Profilometer, and a scanning electron microscope (SEM). The properties of F.F with two types of SiO2 nanoparticles (hydrophilic fumed silica Areosil 300 and silica sol U-2 obtained by the sol-gel method), such as rheology and core damage, were investigated. The discussion of this research results is based on the stability tests carried out with the use of rheology and the foam half-life, formation damage ratio, and observation of exposed samples using SEM and the Profilometer. The permeability and porosity damage ratios of the damaged core samples were found to decrease when nitrogen foamed fluids were used. These results were confirmed with the Profilometer and SEM images. The experimental data showed that the foam stability increased when silica (SiO2) nanoparticles were added. SiO2 nanoparticle-surfactant-stabilized foam for fracturing is superior to traditional water-based fracturing fluids and causes lower core permeability damage than a traditional F.F.

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Optimization of Parameters of a Hydraulic Mobile Pumping Unit for Hydraulic Fracturing

Bill,

Kireev,

Korchagina

et al. 2024

Springer Proceedings in Materials

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Hydraulic Fracturing

Cited by 7 publications

References 60 publications

Experimental and Simulation Studies of Energized Fracturing Fluid Efficiency in Tight Gas Formations

Experimental and Simulation Studies of Energized Fracturing Fluid Efficiency in Tight Gas Formations

Impact of Nitrogen Foamed Stimulation Fluids Stabilized by Nanoadditives on Reservoir Rocks of Hydrocarbon Deposits

Optimization of Parameters of a Hydraulic Mobile Pumping Unit for Hydraulic Fracturing

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