Effect of Heterogeneity of Porous Media on Gas Permeation and Entrapment

Mikami, Yohei; Deguchi, Yoshihiro; Suekane, Tetsuya

doi:10.4236/jfcmv.2014.23013

Cited by 5 publications

(5 citation statements)

References 33 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…Injecting gas at low Ca reduced instability of displacement during the downward drainage process, which agrees well with previous studies. 16,23 With the Ca increasing, CO 2 occupied large pores in the middle of the core vertically and preferentially. Thus the CO 2 clusters were larger than those in the low Ca experiments.…”

Section: Resultsmentioning

confidence: 99%

See 1 more Smart Citation

Experimental study of two-phase flow properties of CO₂containing N₂in porous media

Jiang

Liu

et al. 2016

RSC Adv.

View full text Add to dashboard Cite

In preliminary analyses, the co-injection of CO 2 with H 2 S, SO 2 and N 2 impurities has been shown to reduce total carbon capture and storage (CCS) cost. The multiphase flow properties of impurities in the CO 2 -brine system in porous media are the key to understanding the mechanisms and nature of geological CO 2 sequestration projects. In this study experiments were performed on the multiphase flow process of CO 2 /N 2 /brine system at conditions similar to aquifer pressure and temperature using the X-ray CT technique. Experiments at various rates of CO 2 injection that affect saturation and spatial distribution of injected gas were conducted in this experiment. The results indicate an strong relationship between gas saturation and porosity distribution in porous media, and the increasing capillary number leads to lower saturation in downward injection. Small capillary numbers and higher fractional flows in the gas phase both result in uniform saturation maps in the core. The CO 2 clusters seem larger at high capillary numbers and the high CO 2 collection regions extend based on the saturation distribution in the lower CO 2 fraction as the flow pattern stays similar as the same capillary number. CO 2 containing N 2 tends to retain more correlative relationships at different gas injection rates compared with the pure CO 2 stream.Even though both distribution and saturation are storage concerns, the N 2 component has little effect on gas distribution, whereas it brings about an overall increase in the saturation for most experiments.Thus the N 2 enhanced the storage performance of CO 2 .

show abstract

Section: Resultsmentioning

confidence: 99%

“…Similar results were achieved in previous research. 23 One of the possible reasons could be that the vc/v is not precise enough to predict a residual saturation trend in downward drainage between small Ca intervals, and stability will be disturbed by small-scale heterogeneity in pores media. In Fig.…”

Section: Stability Analysismentioning

confidence: 99%

Experimental study of two-phase flow properties of CO₂containing N₂in porous media

Jiang

Liu

et al. 2016

RSC Adv.

View full text Add to dashboard Cite

show abstract

“…Four fluid pairs were selected such that the dimensionless Bond number, capillary number, and viscosity ratio covered those of the CO 2 and water system in the aquifers (Cinar et al, 2009;Suekane and Okada, 2013). The packed bed of glass spheres with a well sorted diameter was used as a porous medium because its homogeneity eliminated the unacceptable capillary effect due to the inhomogeneity of the porous medium (Mikami et al, 2014). The distribution of the non-wetting phase in the packed bed was scanned with a micro-focused X-ray computer tomography (CT) scanner (Comscantechno Co. ScanXmate-RB090SS).…”

Section: Experimental Apparatus and Scheme 21 Experimental Apparatusmentioning

confidence: 99%

Non-wetting phase saturation after drainage from the wetting-phase-filled porous medium

Suekane

Saito

Jiang

2015

JFST

Self Cite

View full text Add to dashboard Cite

Understanding and predicting the efficiency of displacement, i.e., the non-wetting phase saturation after drainage, is of great importance in many practical applications. In this study, we experimentally derive the empirical equations of the non-wetting phase saturation as a function of the capillary number, the Bond number, and the viscosity ratio. A series of laboratory experiments are conducted with a packed bed of glass beads. Several fluid pairs are used to change the viscosity ratio. However, the density of the non-wetting phase is lower than that of the wetting phase for all pairs. In the case of vertically upward injection, the non-wetting phase saturation decreases with the Bond number and increases with the capillary number for all fluid pairs. In the case of the unfavorable viscosity ratio, the non-wetting phase saturation is low because the displacement interface is always unstable. At a low capillary number, the capillary fingering enhanced by buoyancy results in low non-wetting phase saturation. In the case of the downward injection, if the viscosity ratio is favorable, the displacement front is always stable against the Darcy velocity. If the viscosity ratio is unfavorable, the displacement front is stable for low Darcy velocity, when the non-wetting phase saturation is high. When the Darcy velocity exceeds the critical velocity, the non-wetting phase saturation reduces.

show abstract

“…The two‐phase vertical displacement process that characterizes CO 2 leakage events is unstable and may fall into one of three patterns in porous media: capillary, gravitational, and viscous regimes (Bandara et al, ; Holtzman et al, ; Lenormand et al, ). These regimes have been identified analytically and through bench‐scale experiments (Holtzman et al, ; Wang et al, ; Zhang et al, ), based on nondimensional numbers: the capillary number, bond number, and gravity number (Cottin et al, ; Levine et al, ; Løvoll et al, ; Mikami et al, ; Zhou et al, ). However, there is still a gap in our understanding of how this trapping behavior takes place under reservoir pressures and temperature subject to realistic fluid phase and interfacial conditions.…”

Section: Introductionmentioning

confidence: 99%

Interactions Between Stratigraphy and Interfacial Properties on Flow and Trapping in Geologic Carbon Storage

Liang

Clarens

2018

Water Resources Research

View full text Add to dashboard Cite

Gas leakage from geologic carbon storage sites could undermine the long‐term goal of reducing emissions to the atmosphere and negatively impact groundwater resources. Despite this, there remain uncertainties associated with the transport processes that would govern this leakage. These stem from the complex interaction between governing forces (e.g., gravitational, viscous, and capillary), the heterogeneous nature of the porous media, and the characteristic length scales of these leakage events, all of which impact the CO2 fluid flow processes. Here we assessed how sub‐basin‐scale horizons in porous media could impact the migration and trapping of a CO2 plume. A high‐pressure column packed with two layers of sand with different properties (e.g., grain size and wettability) was used to create a low‐contrast stratigraphic horizon. CO2 in supercritical or liquid phase was injected into the bottom of the column under various conditions (e.g., temperature, pressure, and capillary number) and the transport of the resulting plume was recorded using electrical resistivity. The results show that CO2 trapping was most strongly impacted by shifting the wettability balance to mixed‐wet conditions, particularly for residual saturation. A 16% increase in the cosine of the contact angle for a mixed‐wet sand resulted in nearly twice as much residual trapping. Permeability contrast, pressure, and temperature also impacted the residual saturation but to a lesser extent. Flow rate affected the dynamics of saturation profile development, but the effect is transient, suggesting that the other effects observed here could apply to a broad range of leakage conditions.

show abstract

Effect of Heterogeneity of Porous Media on Gas Permeation and Entrapment

Cited by 5 publications

References 33 publications

Experimental study of two-phase flow properties of CO₂containing N₂in porous media

Experimental study of two-phase flow properties of CO₂containing N₂in porous media

Non-wetting phase saturation after drainage from the wetting-phase-filled porous medium

Interactions Between Stratigraphy and Interfacial Properties on Flow and Trapping in Geologic Carbon Storage

Contact Info

Product

Resources

About

Effect of Heterogeneity of Porous Media on Gas Permeation and Entrapment

Cited by 5 publications

References 33 publications

Experimental study of two-phase flow properties of CO2containing N2in porous media

Experimental study of two-phase flow properties of CO2containing N2in porous media

Non-wetting phase saturation after drainage from the wetting-phase-filled porous medium

Interactions Between Stratigraphy and Interfacial Properties on Flow and Trapping in Geologic Carbon Storage

Contact Info

Product

Resources

About

Experimental study of two-phase flow properties of CO₂containing N₂in porous media

Experimental study of two-phase flow properties of CO₂containing N₂in porous media