Surfactant viscoelasticity as a key parameter to improve supercritical CO2 foam stability/foamability and performance in porous media

Yu, Ying; García, Brayan F.; Saraji, Soheil

doi:10.1016/j.jnnfm.2020.104311

Cited by 31 publications

(23 citation statements)

References 29 publications

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“…In our previous study, foamability and foam stability tests for CAPB, LAPB, and LO surfactants were performed in the absence of crude oil . Based on this study, CAPB, LAPB, and LO solutions all made decently stable scCO 2 foam at a 0.1 wt % surfactant concentration.…”

Section: Results and Discussionmentioning

confidence: 96%

“…LO, which is characterized as the surfactant with negligible viscoelasticity among three surfactants and has the worst performance (i.e., foamability and stability) in the absence of oil, also shows minor endurance with the crude oil. Meanwhile, CAPB has better foamability and longer half-life than LAPB, even in the presence of crude oil.…”

Section: Results and Discussionmentioning

confidence: 99%

“…The surfactants used here were cocamidopropyl betaine (CAPB), lauramidopropyl betaine (LAPB), and lauramine oxide (LO), which were provided by Stepan. The surfactant solution rheology has been evaluated; the bulk foamability and stability performance and foam performance in Berea sandstone have been validated in our previous study . As a result, all three surfactants are adequate candidates as the scCO 2 foam boosters.…”

Section: Materials and Methodsmentioning

confidence: 99%

“…After that, 85 mL of scCO 2 was injected into the cell before 24 h equilibration. According to our previous study, the foam quality of 85% was adopted to optimize one surfactant within the three candidates . The experimental condition was checked the next day, premixing.…”

Section: Materials and Methodsmentioning

confidence: 99%

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Supercritical CO₂ Foam Stabilized by a Viscoelastic Surfactant in Fractured Porous Media: The Effect of Fracture Surface Roughness

Saraji

2021

Energy Fuels

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Foam flooding has been used for gas conformance control during enhanced oil recovery (EOR) in heterogeneous reservoirs. The application of foam flooding in naturally or hydraulically fractured reservoirs has recently been gaining attention. There are, however, limited studies on supercritical CO 2 (scCO 2 ) foam behavior in the fractured system. Specifically, the impact of fracture properties such as aperture size, surface roughness, and fracture orientation in natural rocks are not well studied. In this work, we investigated the behavior of scCO 2 foam stabilized by a viscoelastic surfactant in fractured systems. The apparent viscosity of foam in fractured and nonfractured cores was compared. Furthermore, the effects of fracture surface roughness and crude oil on foam behavior were determined. We found that the fracture surface roughness positively affects the apparent viscosity of foam in the absence and presence of crude oil. Also, the formation of the complex structure of the water-oil-CO 2 system during oil−foam co-injection may serve a major role in causing a significant apparent viscosity.

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Section: Results and Discussionmentioning

confidence: 96%

Section: Results and Discussionmentioning

confidence: 99%

Section: Materials and Methodsmentioning

confidence: 99%

Section: Materials and Methodsmentioning

confidence: 99%

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Supercritical CO₂ Foam Stabilized by a Viscoelastic Surfactant in Fractured Porous Media: The Effect of Fracture Surface Roughness

Saraji

2021

Energy Fuels

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“…CO 2 injection into depleted reservoirs has drawn increasing attention in carbon capture, utilization, and storage (CCUS) and in enhanced oil recovery (EOR) projects due to its potential to increase subsurface carbon storage. − However, gaseous and supercritical CO 2 -flooding schemes suffer from low reservoir sweep efficiency because of the low density and low viscosity of CO 2 , reservoir fractures, and heterogeneous rock permeability. ,− One possible solution to address these issues is to add a foaming agent ( e.g ., surfactant) into the injection brine. − The added foaming agent provides CO 2 -flow resistance, which yields better sweep efficiency in porous media. − …”

Section: Introductionmentioning

confidence: 99%

Crude Oil Recovery with Duomeen CTM-Stabilized Supercritical CO₂ Foams for HPHT and Ultrahigh-Salinity Carbonate Reservoirs

et al. 2020

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The compatibility of an amine-based foaming agent, Duomeen CTM [C 12−14 N(CH 3 )C 3 N(CH 3 ) 2 ], and crude oil on supercritical CO 2 foam transport are evaluated for a carbonate reservoir with high pressure and high temperatures (HPHT) and ultrahigh salinities. The CTM solubility in the formation brine (FB) with ultrahigh salinity is evaluated as a function of temperature and pH. CTM is a switchable surfactant, whereby it is soluble in FB when its pH is adjusted to or below a critical pH where protonation has occurred. The thermal stability of CTM at pH 6 was demonstrated at 135 °C with an oxygen scavenger. The adsorption of CTM was evaluated on pure calcite and reservoir carbonate rock. CTM adsorption was determined to be low on calcite, but moderate on reservoir carbonate, due to the presence of siliceous minerals. As expected, the phase behavior of protonated CTM in FB at pH = 4 with crude oil was characteristic of a Winsor Type I phase. The surfactant preferentially propagates with the aqueous phase in the presence of crude oil. The CTM foamability was evaluated in Indiana limestone cores in the: (1) absence of crude oil in a water-wet core, (2) presence of residual oil in a mixed-wet core, and (3) presence of residual oil in oil-wet cores. The foam strength remained stable with 13% residual oil in a mixed-wet core without requiring a minimum pressure gradient (MPG) for starting foam generation. However, at a higher residual oil saturation of 20% in an oil-wet core, the foam strength weakened significantly, and a MPG of 3 psi/ft was necessary for foam generation. These findings provide a framework for the application of CTM-based foams to provide CO 2 mobility control and recover crude oil in carbonate reservoirs at HPHT conditions.

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Liquid foam: Fundamentals, rheology, and applications of foam displacement in porous structures

Moradpour,

Yang,

Tsai

2024

Current Opinion in Colloid & Interface Science

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Surfactant viscoelasticity as a key parameter to improve supercritical CO2 foam stability/foamability and performance in porous media

Cited by 31 publications

References 29 publications

Supercritical CO₂ Foam Stabilized by a Viscoelastic Surfactant in Fractured Porous Media: The Effect of Fracture Surface Roughness

Supercritical CO₂ Foam Stabilized by a Viscoelastic Surfactant in Fractured Porous Media: The Effect of Fracture Surface Roughness

Crude Oil Recovery with Duomeen CTM-Stabilized Supercritical CO₂ Foams for HPHT and Ultrahigh-Salinity Carbonate Reservoirs

Liquid foam: Fundamentals, rheology, and applications of foam displacement in porous structures

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Surfactant viscoelasticity as a key parameter to improve supercritical CO2 foam stability/foamability and performance in porous media

Cited by 31 publications

References 29 publications

Supercritical CO2 Foam Stabilized by a Viscoelastic Surfactant in Fractured Porous Media: The Effect of Fracture Surface Roughness

Supercritical CO2 Foam Stabilized by a Viscoelastic Surfactant in Fractured Porous Media: The Effect of Fracture Surface Roughness

Crude Oil Recovery with Duomeen CTM-Stabilized Supercritical CO2 Foams for HPHT and Ultrahigh-Salinity Carbonate Reservoirs

Liquid foam: Fundamentals, rheology, and applications of foam displacement in porous structures

Contact Info

Product

Resources

About

Supercritical CO₂ Foam Stabilized by a Viscoelastic Surfactant in Fractured Porous Media: The Effect of Fracture Surface Roughness

Supercritical CO₂ Foam Stabilized by a Viscoelastic Surfactant in Fractured Porous Media: The Effect of Fracture Surface Roughness

Crude Oil Recovery with Duomeen CTM-Stabilized Supercritical CO₂ Foams for HPHT and Ultrahigh-Salinity Carbonate Reservoirs