Co-sequestration of SO2 with supercritical CO2 in carbonates: An experimental study of capillary trapping, relative permeability, and capillary pressure

Akbarabadi, Morteza; Piri, Mohammad

doi:10.1016/j.advwatres.2014.08.011

Cited by 35 publications

(6 citation statements)

References 59 publications

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“…The stability of a residually trapped non‐wetting phase over several hours has been well documented [e.g., Akbarabadi and Piri , ; Krevor et al ., ; Lu et al ., ; Niu et al ., ], and the resilience of the residually trapped phase to further displacement observed in Figure is thus consistent. Most two‐phase core flooding experiments in the literature are targeted at determining relative permeability trends [e.g., Burnside and Naylor , ; Reynolds and Krevor , ] and the injection regimes typically used correspond to the associated techniques for relative permeability measurements (i.e., steady state, un‐steady state etc .)…”

Section: Resultsmentioning

confidence: 99%

Capillary trapping quantification in sandstones using NMR relaxometry

Connolly

Vogt

Iglauer

et al. 2017

Water Resources Research

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Capillary trapping of a non‐wetting phase arising from two‐phase immiscible flow in sedimentary rocks is critical to many geoscience scenarios, including oil and gas recovery, aquifer recharge and, with increasing interest, carbon sequestration. Here we demonstrate the successful use of low field 1H Nuclear Magnetic Resonance [NMR] to quantify capillary trapping; specifically we use transverse relaxation time [T2] time measurements to measure both residual water [wetting phase] content and the surface‐to‐volume ratio distribution (which is proportional to pore size] of the void space occupied by this residual water. Critically we systematically confirm this relationship between T2 and pore size by quantifying inter‐pore magnetic field gradients due to magnetic susceptibility contrast, and demonstrate that our measurements at all water saturations are unaffected. Diffusion in such field gradients can potentially severely distort the T2‐pore size relationship, rendering it unusable. Measurements are performed for nitrogen injection into a range of water‐saturated sandstone plugs at reservoir conditions. Consistent with a water‐wet system, water was preferentially displaced from larger pores while relatively little change was observed in the water occupying smaller pore spaces. The impact of cyclic wetting/non‐wetting fluid injection was explored and indicated that such a regime increased non‐wetting trapping efficiency by the sequential occupation of the most available larger pores by nitrogen. Finally the replacement of nitrogen by CO2 was considered; this revealed that dissolution of paramagnetic minerals from the sandstone caused by its exposure to carbonic acid reduced the in situ bulk fluid T2 relaxation time on a timescale comparable to our core flooding experiments. The implications of this for the T2‐pore size relationship are discussed.

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Section: Resultsmentioning

confidence: 99%

Capillary trapping quantification in sandstones using NMR relaxometry

Connolly

Vogt

Iglauer

et al. 2017

Water Resources Research

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“…The inlet brine saturations were used to characterize the capillary pressure versus saturation relationships (Ramakrishnan & Capiello ). Detailed information regarding the experimental procedures and conditions is presented elsewhere (Akbarabadi & Piri ). Results are illustrated in Fig.…”

Section: Resultsmentioning

confidence: 99%

Experimental investigation of carbon dioxide trapping due to capillary retention in saline aquifers

Akbarabadi

Karpyn

et al. 2015

Geofluids

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Capillary trapping is a physical mechanism by which carbon dioxide (CO 2 ) is naturally immobilized in the pore spaces of aquifer rocks during geologic carbon sequestration operations, and thus a key aspect of estimating geologic storage potential. Here, we studied capillary trapping of supercritical carbon dioxide (scCO 2 ), and the effect of initial scCO 2 saturation and flow rate on the storage/trapping potential of Berea sandstone. We performed two-phase, scCO 2 -brine displacements in two samples, each subject to four sequential drainage-imbibition coreflooding cycles to quantify end-point saturations of scCO 2 with the aid of micro-and macro-computed tomography imaging. From these experiments, we found that between 51% and 75% of the initial CO 2 injected can be left behind after the brine injection. We also observed that the initial scCO 2 saturation influenced the residual scCO 2 saturation to a greater extent than the rate of brine injection under the experimental conditions examined. In spite of differences in the experimental conditions tested, as well as those reported in the literature, initial and residual saturations were found to follow a consistent relationship.

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“…In short term, storage capacity is controlled by structural and capillary trappings [ Bandara et al ., ], which are governed by capillary pressure, because capillary pressure between CO 2 and water (or other fluids) phases entraps both connected CO 2 plume below the caprock and disconnected CO 2 bubbles in formation pores [ Krevor et al ., ]. Also, capillary pressure contributes to the safer long‐term trapping mechanisms by solubility and mineral trapping [ Akbarabadi and Piri , ]. Capillary pressure between CO 2 and water in GCS can be explained by the Young‐Laplace equation as below:

P_{C} = P_{{C O}_{2}} - P_{w a t e r} = \frac{{2 γ}_{(W - {C O}_{2})} c o s true(θ true)}{R}

where P C is capillary pressure,

P_{{C O}_{2}}

is CO 2 pressure, P wate r is water pressure, γ CO 2 ‐water is the water‐CO 2 interfacial tension, θ is the water contact angle on mineral surface, and R is pore radius.…”

Section: Introductionmentioning

confidence: 99%

The change in contact angle at unsaturated CO₂‐water conditions: Implication on geological carbon dioxide sequestration

Jafari

Jung

2016

Geochem Geophys Geosyst

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The performance of a geologic carbon storage site strongly depends on the capillary pressure of sealing rock and formations. While wettability of minerals is a key factor in capillary pressure, published contact angles are inconsistent. This study explores the discrepancy of published contact angles in order to reduce the uncertainty of measured laboratory contact angles, and understand the variation of contact angles at unsaturated CO 2 -water conditions. A ratio of droplet dimension and triple line (or contact line) are used to explain the observed wide range of contact angles and the variation of contact angle at unsaturated conditions. Results show that the shape factor has a good agreement with contact angle change during CO 2 dissolution in water. Silica substrate has clear two pinned and slip stages of triple line during CO 2 droplet dissolution, which cause contact angle on silica substrate to increase from 34.58 to 42.18. However, mica substrate has the repeated pinned and slip stages due to the heterogeneity of mica surface, which cause contact angle to increase dramatically from 25.48 to 68.18. Thus, both the impact of the unsaturated CO 2 -water conditions on the wide range of contact angle and the heterogeneity of mineral surface should be considered when one estimates capillary pressure based on contact angle in geological CO 2 sequestration. R( 1) where P C is capillary pressure, P CO2 is CO 2 pressure, P water is water pressure, c CO2-water is the water-CO 2 interfacial tension, h is the water contact angle on mineral surface, and R is pore radius.

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Co-sequestration of SO2 with supercritical CO2 in carbonates: An experimental study of capillary trapping, relative permeability, and capillary pressure

Cited by 35 publications

References 59 publications

Capillary trapping quantification in sandstones using NMR relaxometry

Capillary trapping quantification in sandstones using NMR relaxometry

Experimental investigation of carbon dioxide trapping due to capillary retention in saline aquifers

The change in contact angle at unsaturated CO₂‐water conditions: Implication on geological carbon dioxide sequestration

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Co-sequestration of SO2 with supercritical CO2 in carbonates: An experimental study of capillary trapping, relative permeability, and capillary pressure

Cited by 35 publications

References 59 publications

Capillary trapping quantification in sandstones using NMR relaxometry

Capillary trapping quantification in sandstones using NMR relaxometry

Experimental investigation of carbon dioxide trapping due to capillary retention in saline aquifers

The change in contact angle at unsaturated CO2‐water conditions: Implication on geological carbon dioxide sequestration

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The change in contact angle at unsaturated CO₂‐water conditions: Implication on geological carbon dioxide sequestration