Experimental Study on the Stabilization Mechanisms of CO<sub>2</sub> Foams by Hydrophilic Silica Nanoparticles

Wang, Pan; You, Qing; Han, Lei; Deng, Weibing; Liu, Yifei; You, Qing; Gao, Mingwei; Dai, Caili

doi:10.1021/acs.energyfuels.7b04125

Cited by 56 publications

(23 citation statements)

References 33 publications

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“…The interfacial tension of CO 2 –H 2 O is lower than that of CH 4 –H 2 O and that of N 2 –H 2 O, which is beneficial to increase foam volume (Chen & Yang, 2019; Kamari et al, 2017; Mirzaie & Tatar, 2020; C. Zhang, Wu, et al, 2020). CO 2 dissolving in water can make the solution acidic, which can affect the foaming ability and the function of the surfactants (P. Wang et al, 2018). The high density of CO 2 is also conducive to the interaction with the surfactant solution to form more volume of foam (Emadi et al, 2012; Farajzadeh et al, 2009).…”

Section: Resultsmentioning

confidence: 99%

“…Zhang, Wu, et al, 2020). CO 2 dissolving in water can make the solution acidic, which can affect the foaming ability and the function of the surfactants (P. Wang et al, 2018). The high density of CO 2 is also conducive to the interaction with the surfactant solution to form more volume of foam (Emadi et al, 2012;Farajzadeh et al, 2009).…”

Section: Comparison Of Ch 4 N 2 and Co 2 Foamsmentioning

confidence: 99%

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Stabilization of natural gas foams using different surfactants at high pressure and high temperature conditions

Bi¹,

Zhang

et al. 2021

J Surfact & Detergents

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Natural gas foam can be used for mobility control and channel blocking during natural gas injection for enhanced oil recovery, in which stable foams need to be used at high reservoir temperature, high pressure and high water salinity conditions in field applications. In this study, the performance of methane (CH 4 ) foams stabilized by different types of surfactants was tested using a high pressure and high temperature foam meter for surfactant screening and selection, including anionic surfactant (sodium dodecyl sulfate), non-anionic surfactant (alkyl polyglycoside), zwitterionic surfactant (dodecyl dimethyl betaine) and cationic surfactant (dodecyl trimethyl ammonium chloride), and the results show that CH 4 -SDS foam has much better performance than that of the other three surfactants. The influences of gas types (CH 4 , N 2 , and CO 2 ), surfactant concentration, temperature (up to 110 C), pressure (up to 12.0 MPa), and the presence of polymers as foam stabilizer on foam performance was also evaluated using SDS surfactant. The experimental results show that the stability of CH 4 foam is better than that of CO 2 foam, while N 2 foam is the most stable, and CO 2 foam has the largest foam volume, which can be attributed to the strong interactions between CO 2 molecules with H 2 O. The foaming ability and foam stability increase with the increase of the SDS concentration up to 1.0 wt% (0.035 mol/L), but a further increase of the surfactant concentration has a negative effect. The high temperature can greatly reduce the stability of CH 4 -SDS foam, while the foaming ability and foam stability can be significantly enhanced at high pressure. The addition of a small amount of polyacrylamide as a foam stabilizer can significantly increase the viscosity of the bulk solution and improve the foam stability, and the higher the molecular weight of the polymer, the higher viscosity of the foam liquid film, the better foam performance.

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Section: Resultsmentioning

confidence: 99%

Section: Comparison Of Ch 4 N 2 and Co 2 Foamsmentioning

confidence: 99%

Stabilization of natural gas foams using different surfactants at high pressure and high temperature conditions

Bi¹,

Zhang

et al. 2021

J Surfact & Detergents

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“…Improving sweep efficiency and oil displacement efficiency are the two main EOR mechanisms. Various EOR techniques have been applied to enhance the oil recovery in a mature reservoir, such as chemical flooding, , foam flooding, , conformance control technique, − and so on. Chemical flooding has shown great potential for enhanced oil recovery, which can be mainly categorized as polymer flooding, − surfactant flooding, − surfactant–polymer flooding, , and alkali–surfactant–polymer (ASP) flooding .…”

Section: Introductionmentioning

confidence: 99%

Insights into the Effects of Salinity on the Transport Behavior of Polymer-Enhanced Branched-Preformed Particle Gel Suspension in Porous Media

Wang

et al. 2021

Energy Fuels

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The branched-preformed particle gel (B-PPG) is a novel viscoelastic particle gel used for improving sweep efficiency and enhancing oil recovery in a heterogeneous mature reservoir. To improve the performance of B-PPG, partially hydrolyzed polyacrylamide (HPAM) is used to increase the viscosity and to prepare a homogeneous B-PPG suspension. Although some encouraging progress has been made in the application of polymer-enhanced B-PPG suspension, its transport behavior in porous media is still unclear, which is crucial for its application in enhanced oil recovery (EOR) in a heterogeneous reservoir. Due to the complex reservoir condition of different brine salinities, the physiochemical property of polymer-enhanced B-PPG suspension as well as its transport behavior in porous media can be affected, which may lead to unsatisfactory results. Understanding the effects of salinity on the transport behavior of polymer-enhanced B-PPG suspension in porous media is of vital importance in figuring out the flow behavior and improving the sweep efficiency in the mature reservoir. In this study, the effects of salinity on the swelling ratio, particle size, viscosity property, and suspension stability of B-PPG and polymer-enhanced B-PPG suspension were studied. Meanwhile, sand pack flow experiments were conducted to study the transport behavior of polymer-enhanced B-PPG suspension in porous media. The results show that when the brine salinity increases, the swelling ratio and particle size of B-PPG, as well as the viscosity and the suspension stability of polymer-enhanced B-PPG suspension all demonstrate a decreasing trend. In the range of 3550–10 651 mg·L–1, as the brine salinity increases, the resistance factor decreases and the transportation of polymer-enhanced B-PPG suspension in porous media becomes easier. In this case, the ratio of swollen B-PPG particle diameter to the pore throat diameter turns out to be the determining factor that governs the transport behavior. However, when the brine salinity is higher than 10 651 mg·L–1, with the increase of brine salinity, the resistance factor increases. As a result, the effects of viscosity and suspension stability of polymer-enhanced B-PPG suspension become more prominent.

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“…Foam has been demonstrated to effectively control the mobility of gas. , Based on the theory of Pickering foam, nanoparticles are used to play a synergistic effect with surfactants to enhance the stability of foam. − In recent years, many researchers have studied gas mobility control by nanoparticle-stabilized foam. Farhadi et al presented that uniform CO 2 foam with higher viscosity could be obtained from nanoparticle-surfactant dispersion, leading to better mobility control ability than foam generated from surfactant solution.…”

Section: Introductionmentioning

confidence: 99%

CO₂ Mobility Control in Porous Media by Using Armored Bubbles with Silica Nanoparticles

Zhou

Zheng

et al. 2020

Ind. Eng. Chem. Res.

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CO2 mobility control in porous media is crucial to geological sequestration of CO2 and enhanced oil recovery (EOR). Although aqueous foam has been widely used to control the mobility of CO2, bubble dispersion with low gas content is formed easily because of gas–liquid separation caused by gravity differentiation, which reduces the storage volume of CO2 and limits its utilization. In this work, the use of armored bubbles with silica nanoparticles for CO2 mobility control in porous media was explored. Visual micromodel flooding experiments were conducted to study the pore-scale flow behaviors of bubbles. Both homogeneous and heterogeneous flooding experiments were used to evaluate the mobility control ability of bubble dispersions. The results showed that the nanoparticles were adsorbed on the interface of CO2 bubbles and formed an armor layer, which made the interface more solid-like and enhanced the roughness of the bubble film. Subsequently, the effective viscosity of the armored CO2 bubble dispersions increased and showed a shear-thinning property. By observing the pore-scale flow behaviors, it was found that armored bubbles showed high rigidity and strong plugging ability, thereby trapping CO2 in porous media and enlarging the sweep region. A synergistic plugging effect occurred between the armored bubbles, which drove the subsequent bubbles to invade into the residual oil region. Moreover, as the armored bubbles became rough, the residual oil was activated more easily by the scraping effect, and the oil-transporting ability of bubbles was enhanced. Thus, residual oils formed after water flooding could be displaced by armored bubbles thoroughly. In homogeneous porous media, the breakthrough and flow channels of the displacing fluid were controlled by the strong plugging of armored bubbles in porous media, and the displacement efficiency was enhanced. The ultimate oil recovery of armored bubble flooding was improved by about 11.4% compared to that of bare surfactant bubble flooding. In heterogeneous porous media, the mobility of the displacing fluid in relatively high permeability sandpack was reduced more effectively by armored bubbles. Even during the subsequent water flooding stage, the armored bubbles showed relatively strong resistance to water erosion and inhibited the differentiation of outflow percentage. Therefore, the flow profile was controlled by armored bubbles, and the ultimate oil recovery was improved by about 14.3% using armored bubbles. The results confirmed the high mobility control performance of nanoparticle-armored bubbles for EOR.

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Experimental Study on the Stabilization Mechanisms of CO₂ Foams by Hydrophilic Silica Nanoparticles

Cited by 56 publications

References 33 publications

Stabilization of natural gas foams using different surfactants at high pressure and high temperature conditions

Stabilization of natural gas foams using different surfactants at high pressure and high temperature conditions

Insights into the Effects of Salinity on the Transport Behavior of Polymer-Enhanced Branched-Preformed Particle Gel Suspension in Porous Media

CO₂ Mobility Control in Porous Media by Using Armored Bubbles with Silica Nanoparticles

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Experimental Study on the Stabilization Mechanisms of CO2 Foams by Hydrophilic Silica Nanoparticles

Cited by 56 publications

References 33 publications

Stabilization of natural gas foams using different surfactants at high pressure and high temperature conditions

Stabilization of natural gas foams using different surfactants at high pressure and high temperature conditions

Insights into the Effects of Salinity on the Transport Behavior of Polymer-Enhanced Branched-Preformed Particle Gel Suspension in Porous Media

CO2 Mobility Control in Porous Media by Using Armored Bubbles with Silica Nanoparticles

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Product

Resources

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Experimental Study on the Stabilization Mechanisms of CO₂ Foams by Hydrophilic Silica Nanoparticles

CO₂ Mobility Control in Porous Media by Using Armored Bubbles with Silica Nanoparticles