The effect of foam quality, particle concentration and flow rate on nanoparticle-stabilized CO<sub>2</sub> mobility control foams

Fu, Chunkai; Yu, Jianjia; Liu, Ning

doi:10.1039/c8ra10352f

Cited by 14 publications

(5 citation statements)

References 28 publications

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“…This was because the texture of the foam generated at a low-quality regime was finer, with smaller trapped gas bubbles resulting in a lower pressure drop. This finding agreed with the literature, 39,68 which categorized foam texture into different types based on the gas bubble size. Fine foam possesses a small bubble, whereas coarse foam has much larger gas bubbles that collapse promptly.…”

Section: Effect Of Foam Quality (Phase 3)supporting

confidence: 93%

“…Therefore, the fine foam produced in a low-quality regime is more stable and stronger than the coarse foam generated in a high-quality regime. Additionally, as the bubbles get larger, they are vulnerable to more collisions and interactions, resulting in slightly coarser foams …”

Section: Resultsmentioning

confidence: 99%

“…Additionally, as the bubbles get larger, they are vulnerable to more collisions and interactions, resulting in slightly coarser foams. 39 Figures 20 and 21 show the ultimate oil recovery and foam apparent viscosity, respectively, for both foaming agents. A direct correlation is observed between the apparent viscosity and oil recovery.…”

Section: Effect Of Foam Quality (Phase 3)mentioning

confidence: 99%

“…Permeability contrast defined as the ratio of the permeabilities of the fracture and matrix is another key parameter that significantly impacts the performance of foams among a large number of reservoir conditions such as rock wettability, − surface roughness, and mineralogy. Such investigations help identify superior chemicals or blends of chemicals for field applications and mitigate the risk by determining, for instance, the optimum range of surfactant concentrations at which a desirable foam performance is achieved for a given fractured medium.…”

Section: Introductionmentioning

confidence: 99%

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Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Youssif,

Sharma,

Goual

et al. 2024

Energy Fuels

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Foam flooding in fractured tight oil reservoirs can enhance gas mobility and conformance control by diverting gas flow from high-permeability zones (fractures) to low-permeability ones (matrices). Several factors, including operating conditions, foam generation parameters, fluid injection schemes, and properties of injected and resident fluids, affect the fracture−matrix interactions. However, thus far, the literature provides a limited understanding of the effects of such factors on the fluid displacement mechanisms between matrices and fractures in propped fractured rocks under reservoir conditions. In this study, two different methane foam injection schemes were investigated for their impact on foamability and oil recovery from propped fractured oil-wet carbonate cores at 115 °C and 3500 psi: (1) foamalternating-gas injection (FAGI-D) and ( 2) foam-alternating-wet gas-alternating-gas injection (FAGI-W-D). The aqueous solutions consisted of high-salinity brine containing two foaming agents: surfactant A (anionic) and surfactant B (amphoteric). The macroscale foam flooding tests showed that the performance of foam in oil-wet porous media was significantly influenced by the number of cycles, foam slug size, total injection rate, and gas fraction. Surfactants A and B exhibited different foaming behaviors irrespective of the foam injection scheme at a fixed concentration (4000 ppm) and foam quality (85%). For surfactant A, a large foam slug size (i.e., six pore volumes) and a high injection rate were necessary to generate foam. In contrast, a lower slug size (i.e., three pore volumes) and a lower injection rate were sufficient for surfactant B. The latter also showed better tolerance toward oil and produced foam of good strength in oil-wet porous media. Therefore, the foam generated by surfactant B significantly reduced the gas mobility and enhanced the fluid displacement from the matrix, leading to higher oil recovery (20.61%) compared with its counterpart (12.96%). Interestingly, the performance of both surfactants was improved at a lower foam quality of 70% and resulted in better foamability, stability, and oil production from tight matrices. This behavior can be attributed to the high water content in the foam, which depleted the oil saturation inside the porous medium more efficiently, leading to increased foamability and higher foam stability. The results also demonstrated that a higher total injection rate of 3 cc/min supported the generation of gas bubbles and caused significant fracture−matrix interactions, diverting more gas from the fracture to the rock matrix.

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Section: Effect Of Foam Quality (Phase 3)supporting

confidence: 93%

Section: Resultsmentioning

confidence: 99%

Section: Effect Of Foam Quality (Phase 3)mentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Youssif,

Sharma,

Goual

et al. 2024

Energy Fuels

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show abstract

“…Research has shown that increasing the gas flow rate can decrease foam generation time, suggesting faster bubble formation. 69 Additionally, lower gas flow rates might necessitate the use of additives like sodium carboxymethylcellulose to prevent bubble collapse and enhance foamability. 70 However, excessively high gas flow rates can also negatively impact foam stability.…”

Section: Effect Of Gas Flowmentioning

confidence: 99%

Carbon Dioxide (CO₂) Microbubble Suspension and Stabilization for Advancing Tertiary Oil Recovery

Dubey,

Majumder

2024

Energy Fuels

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Maximizing oil recovery from existing fields is essential to satisfy global energy demands. Enhanced oil recovery (EOR) techniques, particularly those utilizing carbon dioxide (CO 2 ) microbubbles (MBs), offer promising avenues for improving sweep efficiency and ultimately, oil recovery. This study investigates the influence of formulation and operational parameters on the stability of CO 2 MBs within oil-in-water emulsions designed for EOR applications. Emulsions were formulated using the surfactant sodium dodecyl sulfate (SDS), sodium chloride (NaCl) brine, and light liquid paraffin oil. The stability of the CO 2 MBs was evaluated at atmospheric pressure and room temperature by monitoring drainage rate and half-life. Results indicate that increasing SDS concentration and decreasing NaCl concentration significantly enhance MB stability. An optimal brine-to-oil ratio is crucial, with moderate gas flow rates promoting stability. Surface tension measurements further elucidated the effect of brine on stability. The study additionally explores the rheological behavior of the emulsions, examining the relationship between shear rate and viscosity for various influencing factors. The power-law model was employed to analyze the flow behavior of the emulsions. Dynamic light scattering measurements provided insights into the size distribution of the MBs, aiding in the understanding of their stability behavior.

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Experimental Study on Foam Properties of Mixtures of Organic Silicon and Hydrocarbon Surfactants Regulated by Nano-SiO2 Particles

Zhang,

Shang,

Liu

et al. 2024

Fire Technol

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The effect of foam quality, particle concentration and flow rate on nanoparticle-stabilized CO₂ mobility control foams

Abstract: CO2 foam is regarded as a promising technology and widely used in the oil and gas industry, not only to improve oil production, but also to mitigate carbon emissions through their capture.

Cited by 14 publications

References 28 publications

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Carbon Dioxide (CO₂) Microbubble Suspension and Stabilization for Advancing Tertiary Oil Recovery

Experimental Study on Foam Properties of Mixtures of Organic Silicon and Hydrocarbon Surfactants Regulated by Nano-SiO2 Particles

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The effect of foam quality, particle concentration and flow rate on nanoparticle-stabilized CO2 mobility control foams

Abstract: CO2 foam is regarded as a promising technology and widely used in the oil and gas industry, not only to improve oil production, but also to mitigate carbon emissions through their capture.

Cited by 14 publications

References 28 publications

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Experimental Evaluation of Foam-Assisted Gas Injection in Proppant-Packed Fractured Oil-Wet Carbonate

Carbon Dioxide (CO2) Microbubble Suspension and Stabilization for Advancing Tertiary Oil Recovery

Experimental Study on Foam Properties of Mixtures of Organic Silicon and Hydrocarbon Surfactants Regulated by Nano-SiO2 Particles

Contact Info

Product

Resources

About

The effect of foam quality, particle concentration and flow rate on nanoparticle-stabilized CO₂ mobility control foams

Carbon Dioxide (CO₂) Microbubble Suspension and Stabilization for Advancing Tertiary Oil Recovery