CO2 mobility reduction using foam stabilized by CO2- and water-soluble surfactants

Føyen, Tore; Alcorn, Zachary Paul; Fernø, Martin A.; Barrabino, Albert; Holt, Torleif

doi:10.1016/j.petrol.2020.107651

Cited by 33 publications

(16 citation statements)

References 22 publications

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“…It is possible that the lower apparent viscosity in the low-foam-quality regime, which causes this curve shape, is due to the dissolution of some of the CO 2 into the injected water (thus reducing the foam quality and the total flow velocity at the same time), but corrections were already made for the solubility of the CO 2 during the calculation of the gas injection rate. Others have also seen this type of concave curve shape, both with CO 2 in sandstone ,,, and in limestone , and also in tests in capillary tubes. ,, It is known that gas diffusion through the bubble films is significantly higher for CO 2 than for N 2 , which would lead to more rapid foam coarsening. This coarsening, along with the lower pH produced by the CO 2 dissolution, explains the generally weaker foams observed with CO 2 .…”

Section: Resultsmentioning

confidence: 84%

CO₂ Foam Behavior in Carbonate Rock: Effect of Surfactant Type and Concentration

Jones

Kahrobaei

Wageningen

et al. 2022

Ind. Eng. Chem. Res.

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An understanding of how CO 2 foam flows through a reservoir rock is useful for many subsurface applications, including enhanced oil recovery and CO 2 storage. There are economic and environmental benefits in identifying surfactants that exhibit good foaming behavior with CO 2 at both low concentrations and high foam qualities. Core flood experiments have been carried out to investigate the behavior of supercritical CO 2 foams flowing through a high-permeability Indiana Limestone. The foaming behavior and concentration response of two surfactants, a betaine and a sultaine, were investigated. For the two surfactants, the transition foam quality and the maximum apparent foam viscosity both decreased with reducing surfactant concentration. A comparison between the foaming behaviors of these surfactants with CO 2 and N 2 was also carried out. It was found that the N 2 generated stronger foam at low foam qualities, but the CO 2 was better at maintaining good foaming behavior at high foam qualities.

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Section: Resultsmentioning

confidence: 84%

CO₂ Foam Behavior in Carbonate Rock: Effect of Surfactant Type and Concentration

Jones

Kahrobaei

Wageningen

et al. 2022

Ind. Eng. Chem. Res.

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“…† For the study of porous media, 145 data points were collected from nine different published works. [17][18][19][20][43][44][45][46][47] In all experiments, the AOS surfactant stabilized CO 2 foam in sandstone reservoirs. The parameters considered for the ML model are summarized in Table 3, while additional details are provided in Table S2.…”

Section: Experimental Datamentioning

confidence: 99%

Data-driven prediction of in situ CO₂ foam strength for enhanced oil recovery and carbon sequestration

et al. 2022

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“…A differential pressure transducer and two absolute pressure transducers monitored pressure response at the inlet and outlet. Figure 2 shows the experimental set-up, modified from [ 30 ].…”

Section: Materials and Proceduresmentioning

confidence: 99%

“…Produced fluids were depressurized downstream through a series of backpressure regulator (BPR) valves and measured in the production separator and associated water adsorption column using a digital balance. Modified from [ 30 ].…”

Section: Figurementioning

confidence: 99%

Pore- and Core-Scale Insights of Nanoparticle-Stabilized Foam for CO2-Enhanced Oil Recovery

et al. 2020

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Nanoparticles have gained attention for increasing the stability of surfactant-based foams during CO2 foam-enhanced oil recovery (EOR) and CO2 storage. However, the behavior and displacement mechanisms of hybrid nanoparticle–surfactant foam formulations at reservoir conditions are not well understood. This work presents a pore- to core-scale characterization of hybrid nanoparticle–surfactant foaming solutions for CO2 EOR and the associated CO2 storage. The primary objective was to identify the dominant foam generation mechanisms and determine the role of nanoparticles for stabilizing CO2 foam and reducing CO2 mobility. In addition, we shed light on the influence of oil on foam generation and stability. We present pore- and core-scale experimental results, in the absence and presence of oil, comparing the hybrid foaming solution to foam stabilized by only surfactants or nanoparticles. Snap-off was identified as the primary foam generation mechanism in high-pressure micromodels with secondary foam generation by leave behind. During continuous CO2 injection, gas channels developed through the foam and the texture coarsened. In the absence of oil, including nanoparticles in the surfactant-laden foaming solutions did not result in a more stable foam or clearly affect the apparent viscosity of the foam. Foaming solutions containing only nanoparticles generated little to no foam, highlighting the dominance of surfactant as the main foam generator. In addition, foam generation and strength were not sensitive to nanoparticle concentration when used together with the selected surfactant. In experiments with oil at miscible conditions, foam was readily generated using all the tested foaming solutions. Core-scale foam-apparent viscosities with oil were nearly three times as high as experiments without oil present due to the development of stable oil/water emulsions and their combined effect with foam for reducing CO2 mobility

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CO2 mobility reduction using foam stabilized by CO2- and water-soluble surfactants

Cited by 33 publications

References 22 publications

CO₂ Foam Behavior in Carbonate Rock: Effect of Surfactant Type and Concentration

CO₂ Foam Behavior in Carbonate Rock: Effect of Surfactant Type and Concentration

Data-driven prediction of in situ CO₂ foam strength for enhanced oil recovery and carbon sequestration

Pore- and Core-Scale Insights of Nanoparticle-Stabilized Foam for CO2-Enhanced Oil Recovery

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CO2 mobility reduction using foam stabilized by CO2- and water-soluble surfactants

Cited by 33 publications

References 22 publications

CO2 Foam Behavior in Carbonate Rock: Effect of Surfactant Type and Concentration

CO2 Foam Behavior in Carbonate Rock: Effect of Surfactant Type and Concentration

Data-driven prediction of in situ CO2 foam strength for enhanced oil recovery and carbon sequestration

Pore- and Core-Scale Insights of Nanoparticle-Stabilized Foam for CO2-Enhanced Oil Recovery

Contact Info

Product

Resources

About

CO₂ Foam Behavior in Carbonate Rock: Effect of Surfactant Type and Concentration

CO₂ Foam Behavior in Carbonate Rock: Effect of Surfactant Type and Concentration

Data-driven prediction of in situ CO₂ foam strength for enhanced oil recovery and carbon sequestration