Rheology of polymer-free foam fracturing fluids

Gu, Miao; Mohanty, Kishore K.

doi:10.1016/j.petrol.2015.07.018

Cited by 81 publications

(52 citation statements)

References 22 publications

(23 reference statements)

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“…Hydraulic fracturing of shales is a technique that is widely known to unlock these stored reserves [3] and the fracturing fluids that are commonly used are polymer-based aqueous solutions. However, the application of polymers can plug the nanopores, which becomes a crucial issue [4][5][6][7][8][9]. Moreover, the fracturing process requires a high amount of fresh water during its application, it is susceptible to formation damage in water-sensitive regions, and it provides a reduction in liquid recovery [7,9].…”

Section: Introductionmentioning

confidence: 99%

“…There are different models to describe the flow behavior of foam. The most widely used model is Ostwald-de Waele or power law model [5,30,[32][33][34][35][36][37] and it is mathematically represented by Equation (1):…”

Section: Introductionmentioning

confidence: 99%

“…The apparent viscosity of foam is a strong function of various process variables, which include reservoir temperature, reservoir pressure, foam quality, salinity, shear rate, and chemical additives and their concentrations [5,30,31], and it is important to conduct controlled experiments in order to study the effect of each process variable.…”

Section: Introductionmentioning

confidence: 99%

“…Due to temperature increases, thermal thinning and foam film thickening occur, which quickly drains liquid in the lamellas [40]. At elevated temperatures, foam lamella drainage and bubble coalescence are fast, which causes a significant drop in foam viscosity [5,[40][41][42]. Besides this, high fluctuations in temperature cause holes in the lamella because the foam undergoes high lamella rupture and bubble coalescence occurs [42].…”

Section: Introductionmentioning

confidence: 99%

“…Besides this, high fluctuations in temperature cause holes in the lamella because the foam undergoes high lamella rupture and bubble coalescence occurs [42]. Therefore, the apparent viscosity of sCO 2 foam is expected to decrease with rising temperature [5,33].…”

Section: Introductionmentioning

confidence: 99%

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Empirical Modeling of the Viscosity of Supercritical Carbon Dioxide Foam Fracturing Fluid under Different Downhole Conditions

et al. 2018

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High-quality supercritical CO 2 (sCO 2 ) foam as a fracturing fluid is considered ideal for fracturing shale gas reservoirs. The apparent viscosity of the fracturing fluid holds an important role and governs the efficiency of the fracturing process. In this study, the viscosity of sCO 2 foam and its empirical correlations are presented as a function of temperature, pressure, and shear rate. A series of experiments were performed to investigate the effect of temperature, pressure, and shear rate on the apparent viscosity of sCO 2 foam generated by a widely used mixed surfactant system. An advanced high pressure, high temperature (HPHT) foam rheometer was used to measure the apparent viscosity of the foam over a wide range of reservoir temperatures (40-120 • C), pressures (1000-2500 psi), and shear rates (10-500 s −1 ). A well-known power law model was modified to accommodate the individual and combined effect of temperature, pressure, and shear rate on the apparent viscosity of the foam. Flow indices of the power law were found to be a function of temperature, pressure, and shear rate. Nonlinear regression was also performed on the foam apparent viscosity data to develop these correlations. The newly developed correlations provide an accurate prediction of the foam's apparent viscosity under different fracturing conditions. These correlations can be helpful for evaluating foam-fracturing efficiency by incorporating them into a fracturing simulator.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Empirical Modeling of the Viscosity of Supercritical Carbon Dioxide Foam Fracturing Fluid under Different Downhole Conditions

et al. 2018

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Synergistic effects of polymer and bentonite clay on rheology and thermal stability of foam fluid developed for hydraulic fracturing

Verma

Chauhan

Ojha

2017

Asia-Pacific J Chem Eng

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Demand for foam fracturing fluids is ever‐increasing because of its nondamaging characteristics, less water requirement, combined with efficient proppant carrying capacity. The present study reported the synergistic effects of bentonite clay and polymer (guar) on rheology and stability of the foam prepared with surfactant (sodium dodecyl sulfate). Bentonite clay, which is never considered so far for improving quality of foam fracturing fluid, was found to provide improved foam rheology at reduced polymer concentration. Static and dynamic rheology with microscopic study showed the improvement of apparent viscosity, viscoelasticity, thermal stability, and morphology of foam on addition of bentonite clay. Addition of bentonite reduced the doses of polymer with similar proppant suspension capacity, which could be preferred over conventional gelled foam to reduce formation damage incurred by insoluble guar in the very low permeability unconventional reservoirs like shale gas, coal bed methane, or water‐sensitive formations. © 2017 Curtin University and John Wiley & Sons, Ltd.

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Self‐assembly properties of ultra‐long‐chain gemini surfactant with high performance in a fracturing fluid application

Yang

Zhang

et al. 2016

J of Applied Polymer Sci

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A new cationic gemini surfactant (C25‐6‐C25), which had a special structure consisting of ultra‐long hydrophobic chains and amide groups, was synthesized using a main feedstock source obtained from rapeseed for thickening purposes. The 12 mmol L−1 C25‐6‐C25 fluid containing 0.19 mol L−1 potassium chloride (KCl) exhibited highly elastic properties at the angular frequency of 0.04–10 rad s−1. Its viscosity could be maintained at 55 mPa s for 1.5 h under a shear rate of 170 s−1 at 110 °C and it also showed a good proppant‐suspending property. C25‐6‐C25/KCl fluid exhibited high viscoelasticity and good performance, which were attributed to intermolecular forces, hydrogen bonding, and the shielding effect of electrostatic repulsion by KCl. Thus, C25‐6‐C25 is a very promising candidate for fracturing. © 2016 Wiley Periodicals, Inc. J. Appl. Polym. Sci. 2017, 134, 44602.

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Rheology of polymer-free foam fracturing fluids

Cited by 81 publications

References 22 publications

Empirical Modeling of the Viscosity of Supercritical Carbon Dioxide Foam Fracturing Fluid under Different Downhole Conditions

Empirical Modeling of the Viscosity of Supercritical Carbon Dioxide Foam Fracturing Fluid under Different Downhole Conditions

Synergistic effects of polymer and bentonite clay on rheology and thermal stability of foam fluid developed for hydraulic fracturing

Self‐assembly properties of ultra‐long‐chain gemini surfactant with high performance in a fracturing fluid application

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