Experimental and simulation study of foam stability and the effects on hydraulic fracture proppant placement

Yang, Fei; Pokalai, Kunakorn; Johnson, Raymond L.; Gonzalez, Mary; Haghighi, Manouchehr

doi:10.1016/j.jngse.2017.08.020

Cited by 40 publications

(26 citation statements)

References 28 publications

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“…The characterization of foams is utterly dependent on the size of the bubbles. The foam quality in which the bubble size is defined as the average diameter of the bubbles (it might be varied regarding the properties of the foam and the distribution of the bubbles and for colloidal sizes is about 0.01-0.1 µm) and foam quality is considered as the percentage of the fraction of gas volumes in the generated foam that ranges from 75% to 90% [20][21][22]. Yu et al (2015) proposed a numerical method to simulate the carbon dioxide in a tight formation.…”

Section: Introductionmentioning

confidence: 99%

RETRACTED: Hybrid Thermal-Chemical Enhanced Oil Recovery Methods; An Experimental Study for Tight Reservoirs

Hu¹,

Peng

et al. 2020

Symmetry

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It is essential to have an adequate understanding of the fluid-structure in a porous medium since this gives direct information about the processes necessary to extract the liquid and the likely yield. The concept of symmetry is one of the petroleum engineering issues that has been used to provide an analytical analysis for modeling fluid dynamics through porous media, which can be beneficial to validate the experimental field data. Tight reservoirs regarding their unique reservoir characterization have always been considered as a challenging issue in the petroleum industries. In this paper, different injectivity scenarios which included chemical and thermal methods were taken into consideration to compare the efficiency of each method on the oil recovery enhancement. According to the results of this experiment, the recovery factor for foams and brine injection is about 80%, while it is relatively 66% and 58% for brine-carbon dioxide and brine-nitrogen, respectively. Consequently, foam injection after water flooding would be an effective method to produce more oil volumes in tight reservoirs. Moreover, KCl regarding its more considerable wettability changes has provided more oil production rather than other scenarios.

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Section: Introductionmentioning

confidence: 99%

RETRACTED: Hybrid Thermal-Chemical Enhanced Oil Recovery Methods; An Experimental Study for Tight Reservoirs

Hu¹,

Peng

et al. 2020

Symmetry

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“…The foam stability with the addition of silica nanoparticles was improvised by slowing the foam decay ratio. The enhanced stability resulted from both a reduction in the extent of free drainage due to increases in the aqueous phase viscosity as well as the adsorption of particles around bubbles to prevent coalescences and disproportion. , Higher temperature (80 °C) shows faster decay compared to that at 30 °C due to increased kinetic energy of the molecules as well as reduced base fluid viscosity. However, the foam decay process was very slow.…”

Section: Resultsmentioning

confidence: 99%

Morphology, Rheology, and Kinetics of Nanosilica Stabilized Gelled Foam Fluid for Hydraulic Fracturing Application

Verma

Chauhan

Baruah

et al. 2018

Ind. Eng. Chem. Res.

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Stabilizing mechanism of silica nanoparticles on gelled foam prepared with a very low concentration of polymer (xanthan gum) and surfactant (α-olefin sulfonate) is reported in the present study. The morphology of the foam at optimized composition reveals its improved stability, owing to the adsorption of silica nanoparticles on the bubble interface, which was further confirmed by microscopic images. The foam decay experiments confirmed the slower drainage of liquids through the strong and rough bubble interface in the presence of nanoparticles. The synergistic effects of nanoparticles–polymer–surfactant help to improvise rheology, viscoelastic properties and enhanced static proppant suspension capacity of the foam. Addition of nanoparticles helps in reducing the polymer concentration in the foam fluid without compromising in stability criterion. Thus, the prepared gelled foam offers less formation damage with improved rheology, and proppant carrying capacity without any limitation to low-temperature application.

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“…This phenomenon (the decreasing foam stability and apparent viscosity with increasing foam quality) has been attributed to increasing frequency of bubble collisions and Oswald ripening due to high percentages of dispersed gas per unit volume of the foaming solutions (Osei-Bonsu et al 2016). The higher gas volume per unit volume of surfactant solutions at higher foam quality results in dynamic and recurrent interaction within the foamy fluids, consequently increasing the rate of gas diffusion from lamellae, bubble coalescence and coarsening (Fei et al 2017;Yekeen et al 2018b).…”

Section: Influence Of Foam Quality On the Apparent Viscosities Of Lb And Sio 2 -Lb Foamsmentioning

confidence: 99%

Characterization of lauryl betaine foam in the Hele-Shaw cell at high foam qualities (80%–98%)

et al. 2020

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Lauryl betaine (LB) as an amphoteric surfactant carries both positive and negative charges and should be able to generate stable foam through electrostatic interaction with nanoparticles and co-surfactants. However, no previous attempts have been made to investigate the influence of nanoparticles and other co-surfactants on the stability and apparent viscosity of LB-stabilized foam. In this study, a thorough investigation on the influence of silicon dioxide (SiO2) nanoparticles, alpha olefin sulfonate (AOS) and sodium dodecyl sulfate (SDS), on foam stability and apparent viscosity was carried out. The experiments were conducted with the 2D Hele-Shaw cell at high foam qualities (80%–98%). Influence of AOS on the interaction between the LB foam and oil was also investigated. Results showed that the SiO2-LB foam apparent viscosity decreased with increasing surfactant concentration from 0.1 wt% to 0.3 wt%. 0.1 wt% SiO2 was the optimum concentration and increased the 0.1 wt% LB foam stability by 108.65% at 96% foam quality. In the presence of co-surfactants, the most stable foam, with the highest apparent viscosity, was generated by AOS/LB solution at a ratio of 9:1. The emulsified crude oil did not imbibe into AOS-LB foam lamellae. Instead, oil was redirected into the plateau borders where the accumulated oil drops delayed the rate of film thinning, bubble coalescence and coarsening.

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Experimental and simulation study of foam stability and the effects on hydraulic fracture proppant placement

Cited by 40 publications

References 28 publications

RETRACTED: Hybrid Thermal-Chemical Enhanced Oil Recovery Methods; An Experimental Study for Tight Reservoirs

RETRACTED: Hybrid Thermal-Chemical Enhanced Oil Recovery Methods; An Experimental Study for Tight Reservoirs

Morphology, Rheology, and Kinetics of Nanosilica Stabilized Gelled Foam Fluid for Hydraulic Fracturing Application

Characterization of lauryl betaine foam in the Hele-Shaw cell at high foam qualities (80%–98%)

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