Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Polak, Szczepan; Cinar, Yildiray; Holt, Torleif; Torsæter, Ole

doi:10.1016/j.petrol.2015.02.031

Cited by 12 publications

(7 citation statements)

References 48 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Most of the work to date has focused on nonaqueous phase liquid (NAPL) migration observed in sandbox experiments [e.g., Barth et al ., ; Fagerlund et al ., ; Glass et al ., ; Kueper and Frind , ], while studies that specifically address GCS are quite scarce and are limited to cm‐to‐m observations of immiscible [ Pini et al ., ; Polak et al ., ; Trevisan et al ., ; Werner et al ., ; Zhao et al ., ] and miscible displacements [ Agartan et al ., ; Neufeld et al ., ]. A dimensional analysis approach has also been proposed to reconcile laboratory scales and field scales [ Cinar et al ., ; Polak et al ., ; Trevisan et al ., ; Werner et al ., ]. In this context, physical models prove to be very useful, because they enable a systematic evaluation of flow regimes and heterogeneity contrasts in terms of, e.g., strength and correlation length of a permeability field.…”

Section: Introductionmentioning

confidence: 99%

Imaging and quantification of spreading and trapping of carbon dioxide in saline aquifers using meter‐scale laboratory experiments

Trevisan

Pini

Cihan

et al. 2017

Water Resources Research

View full text Add to dashboard Cite

The role of capillary forces during buoyant migration of CO2 is critical toward plume immobilization within the postinjection phase of a geological carbon sequestration operation. However, the inherent heterogeneity of the subsurface makes it very challenging to evaluate the effects of capillary forces on the storage capacity of these formations and to assess in situ plume evolution. To overcome the lack of accurate and continuous observations at the field scale and to mimic vertical migration and entrapment of realistic CO2 plumes in the presence of a background hydraulic gradient, we conducted two unique long‐term experiments in a 2.44 m × 0.5 m tank. X‐ray attenuation allowed measuring the evolution of a CO2‐surrogate fluid saturation, thus providing direct insight into capillarity‐dominated and buoyancy‐dominated flow processes occurring under successive drainage and imbibition conditions. The comparison of saturation distributions between two experimental campaigns suggests that layered‐type heterogeneity plays an important role on nonwetting phase (NWP) migration and trapping, because it leads to (i) longer displacement times (3.6 months versus 24 days) to reach stable trapping conditions, (ii) limited vertical migration of the plume (with center of mass at 39% versus 55% of aquifer thickness), and (iii) immobilization of a larger fraction of injected NWP mass (67.2% versus 51.5% of injected volume) as compared to the homogenous scenario. While these observations confirm once more the role of geological heterogeneity in controlling buoyant flows in the subsurface, they also highlight the importance of characterizing it at scales that are below seismic resolution (1–10 m).

show abstract

Section: Introductionmentioning

confidence: 99%

Imaging and quantification of spreading and trapping of carbon dioxide in saline aquifers using meter‐scale laboratory experiments

Trevisan

Pini

Cihan

et al. 2017

Water Resources Research

View full text Add to dashboard Cite

show abstract

“…The capillary pressure does not scale with the IFT because of this wettability change . In the studies of CO 2 invasion into porous media, the effect of IFT is considered important; however, the effect of CA is overlooked . The IFT values combined with CA are important for the measurement of relative permeability and the water retention curve …”

Section: Background – Literature Reviewmentioning

confidence: 99%

“…[44][45][46][47] In the studies of CO 2 invasion into porous media, the effect of IFT is considered important; however, the effect of CA is overlooked. 48,49 The IFT values combined with CA are important for the measurement of relative permeability and the water retention curve. [50][51][52][53] The surface de-wetting phenomenon by CO 2 has been reported in the literature.…”

Section: Contact Anglementioning

confidence: 99%

Interfacial tension and contact angle in CO₂‐water/nanofluid‐quartz system

Zheng¹,

Barrios

Perreault

et al. 2018

Greenhouse Gases

View full text Add to dashboard Cite

Nanoparticles can modify the interface properties that are critical for fluid flow in porous media. The interfacial tension (IFT) between CO2 and water and the contact angle (CA) of a water droplet on a mineral surface under high CO2 pressure are critical parameters for CO2‐related applications such as CO2 geological sequestration and CO2‐enhanced resource recovery. This study investigated the IFT and CA in a water‐CO2‐quartz system and a nanofluid (water including either Al2O3 or TiO2 nanoparticles)‐CO2‐quartz system. The values of the IFT and CA were obtained by axisymmetric drop shape analysis (ADSA) for a droplet on a quartz surface in a chamber pressurized with CO2. The effect of nanoparticles on the IFT and CA was explored by comparing the values for the pure water‐CO2‐quartz system. In addition, the effect of CO2 adsorption onto the substrate on the wettability was investigated. The results show that the values of the IFT decrease with increasing CO2 pressure, and the addition of nanoparticles to pure water lowers the IFT further (∼up to a 40% reduction in the liquid CO2 pressure range). The de‐wetting phenomenon was observed for both gaseous and liquid CO2 conditions. © 2018 Society of Chemical Industry and John Wiley & Sons, Ltd.

show abstract

“…Consequently, the flow velocity increases, which effectively gathers and drives the flow of CH 4 in the reservoirs [16]. Moreover, the maintenance of pressure can also provide pressure support to prevent the formation of subsidence and water invasion [17]. In addition, injecting CO 2 into tight sandstone gas reservoirs not only can achieve the purpose of EGR but also realize CO 2 geological storage, which is of great significance for mitigating the global greenhouse effect [18,19].…”

Section: Introductionmentioning

confidence: 99%

Experimental Study on Feasibility of Enhanced Gas Recovery through CO2 Flooding in Tight Sandstone Gas Reservoirs

Wang

Liu

et al. 2018

Processes

View full text Add to dashboard Cite

The development of natural gas in tight sandstone gas reservoirs via CH4-CO2 replacement is promising for its advantages in enhanced gas recovery (EGR) and CO2 geologic sequestration. However, the degree of recovery and the influencing factors of CO2 flooding for enhanced gas recovery as well as the CO2 geological rate are not yet clear. In this study, the tight sandstone gas reservoir characteristics and the fluid properties of the Sulige Gasfield were chosen as the research platform. Tight sandstone gas long-core displacement experiments were performed to investigate (1) the extent to which CO2 injection enhanced gas recovery (CO2-EGR) and (2) the ability to achieve CO2 geological storage. Through modification of the injection rate, the water content of the core, and the formation dip angle, comparative studies were also carried out. The experimental results demonstrated that the gas recovery from CO2 flooding increased by 18.36% when compared to the depletion development method. At a lower injection rate, the diffusion of CO2 was dominant and the main seepage resistance was the viscous force, which resulted in an earlier CO2 breakthrough. The dissolution of CO2 in water postponed the breakthrough of CO2 while it was also favorable for improving the gas recovery and CO2 geological storage. However, the effects of these two factors were insignificant. A greater influence was observed from the presence of a dip angle in tight sandstone gas reservoirs. The effect of CO2 gravity separation and its higher viscosity were more conducive to stable displacement. Therefore, an additional gas recovery of 5% to 8% was obtained. Furthermore, the CO2 geological storage exceeded 60%. As a consequence, CO2-EGR was found to be feasible for a tight sandstone gas reservoir while also achieving the purpose of effective CO2 geological storage especially for a reservoir with a dip angle.

show abstract

Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Cited by 12 publications

References 48 publications

Imaging and quantification of spreading and trapping of carbon dioxide in saline aquifers using meter‐scale laboratory experiments

Imaging and quantification of spreading and trapping of carbon dioxide in saline aquifers using meter‐scale laboratory experiments

Interfacial tension and contact angle in CO₂‐water/nanofluid‐quartz system

Experimental Study on Feasibility of Enhanced Gas Recovery through CO2 Flooding in Tight Sandstone Gas Reservoirs

Contact Info

Product

Resources

About

Use of low- and high-IFT fluid systems in experimental and numerical modelling of systems that mimic CO2 storage in deep saline formations

Cited by 12 publications

References 48 publications

Imaging and quantification of spreading and trapping of carbon dioxide in saline aquifers using meter‐scale laboratory experiments

Imaging and quantification of spreading and trapping of carbon dioxide in saline aquifers using meter‐scale laboratory experiments

Interfacial tension and contact angle in CO2‐water/nanofluid‐quartz system

Experimental Study on Feasibility of Enhanced Gas Recovery through CO2 Flooding in Tight Sandstone Gas Reservoirs

Contact Info

Product

Resources

About

Interfacial tension and contact angle in CO₂‐water/nanofluid‐quartz system