Increased CO2 storage capacity using CO2-foam

Føyen, Tore; Brattekås, Bergit; Fernø, Martin A.; Barrabino, Albert; Holt, Torleif

doi:10.1016/j.ijggc.2020.103016

Cited by 65 publications

(29 citation statements)

References 15 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Foam apparent viscosity has been calculated using Eq. ( 1) and ((2) to range between 5.1 to 10.1 cP that corroborates core floods at similar conditions (Føyen et al, 2020).…”

Section: Flowing and Trapped Foamsupporting

confidence: 77%

“…Foam generation at sharp permeability contrasts can also occur some distance from the injection well at lower pressure gradients if sufficient foaming solutions are available. Additionally, super-linear increases in apparent viscosity during core scale unsteady state experiments, indicate that positive feedback behavior (Føyen et al, 2020) is likely related to the backward propagation mechanism observed at the pore-level. small bubbles with area < 10 3 μm 2 ; c) intermediate bubbles with area between 10 3 to 10 4 μm 2 ; d) large bubbles with area > 10 4 μm 2 .…”

Section: Foam Generationmentioning

confidence: 96%

“…Foam is a promising method for reducing CO 2 mobility in enhanced oil recovery (EOR) and CO 2 storage processes. CO 2 foam for mobility control can improve reservoir sweep efficiency, mitigate gravity override, and reduce viscous fingering for increased oil recovery (Enick et al, 2012) and CO 2 storage potential (Føyen et al, 2020). Foam is a thermodynamically unstable two-phase system of dispersed gas bubbles separated by continuous aqueous films (lamellae), stabilized by a foaming agent such as surfactant and/or nanoparticles.…”

Section: Introductionmentioning

confidence: 99%

“…During foam flow the pressure gradients can vary and fluctuate in space and time, resulting in local pressure gradients for the creation of lamellae (Kam and Rossen, 2003). Positive feedback processes can also occur during foam generation because foam increases the pressure gradients and subsequently causes the generation of more foam (Føyen et al, 2020).…”

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

Pore-scale Bubble Population Dynamics of CO2-Foam at Reservoir Pressure

Benali

Føyen

Alcorn

et al. 2021

Preprint

View full text Add to dashboard Cite

The flow of CO 2 foam for mobility control in porous media is dictated by the foam texture, or bubble density, which is commonly expressed as the number of bubbles per unit of flowing gas. In most high-pressure laboratory studies of foam in porous media, the local foam texture cannot be determined due to opaque flow systems. Here, we unlock real-time foam texture dynamics at high pressure (100 bar) by utilizing a realistic pore network with an extended field of view. We identified snap-off as the dominant foam generation mechanism, with additional fining of foam texture caused by backward foam propagation. Foam coalescence during continuous CO 2 injection resulted in large gas channels parallel to the general flow direction that reduced the overall foam apparent viscosity. A large fraction of the CO 2 foam remained trapped (X t > 0.97) and stationary in pores to divert CO 2 flow and increase sweep efficiency. The gas mobility was calculated from the fraction of trapped bubbles at the pore-scale, and the apparent foam viscosity agreed with similar injection test performed at core-scale. Hence, improved understanding of CO 2 foam texture evolution (n f ) can strengthen the validation of numerical foam models for upscaling of flow phenomena, instrumental in the development of field scale implementation of CO 2 foam for in carbon utilization and storage applications.

show abstract

“…Foam apparent viscosity has been calculated using Eq. ( 1) and ((2) to range between 5.1 to 10.1 cP that corroborates core floods at similar conditions (Føyen et al, 2020).…”

Section: Flowing and Trapped Foamsupporting

confidence: 77%

Section: Foam Generationmentioning

confidence: 96%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 2 more Smart Citations

Pore-scale Bubble Population Dynamics of CO2-Foam at Reservoir Pressure

Benali

Føyen

Alcorn

et al. 2021

Preprint

View full text Add to dashboard Cite

show abstract

“…More than 50% of the water was displaced during WAG and 0.25 wt% SAG and 70% was displaced during 0.50 wt% SAG. The increase in foam apparent viscosity had a significant effect on water displacement which resulted in more pore space available for CO 2 storage (Føyen et al, 2020).…”

Section: Sag After Waterfloodmentioning

confidence: 99%

Unsteady-state CO2 foam injection for increasing enhanced oil recovery and carbon storage potential

Sæle

Graue

Alcorn

2022

Adv. Geo-Energy Res.

View full text Add to dashboard Cite

The efficiency of CO 2 injection for enhanced oil recovery and carbon storage is limited by severe viscosity and density differences between CO 2 and reservoir fluids and reservoir heterogeneity. In-situ generation of CO 2 foam can improve the mobility ratio to increase oil displacement and CO 2 storage capacity in geological formations. The aim of this work was to investigate the ability of CO 2 foam to increase oil production and associated CO 2 storage potential, compared to other CO 2 injection methods, in experiments that deploy field-scale injection strategies. Additionally, the effect of oil on CO 2 foam generation and stability was investigated. Three different injection strategies were implemented in the CO 2 enhanced oil recovery and associated CO 2 storage experiments: pure CO 2 injection, water-alternating-gas and surfactant-alternating-gas. Foam generation during surfactantalternating-gas experiments showed reduced CO 2 mobility compared to water-alternatinggas and pure CO 2 injections indicated by the increase in apparent viscosity. CO 2 foam increased oil recovery by 50% compared to pure CO 2 injection and 25% compared to water-alternating-gas. In addition, CO 2 storage capacity increased from 12% during pure CO 2 injection up to 70% during surfactant-alternating-gas injections. Experiments performed at high oil saturations revealed a delay in foam generation until a critical oil saturation of 30% was reached. Oil/water emulsions in addition to CO 2 foam generation contributed to CO 2 mobility reduction resulting in increased CO 2 storage capacity with foam.

show abstract