Receding and advancing (CO 2 + brine + quartz) contact angles as a function of pressure, temperature, surface roughness, salt type and salinity

Al-Yaseri, Ahmed; Lebedev, Maxim; Barifcani, Ahmed; Iglauer, Stefan

doi:10.1016/j.jct.2015.07.031

Cited by 193 publications

(211 citation statements)

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“…[3][4][5][6][7][8] Among all these types of CO 2 storage sites, deep saline aquifers are considered more suitable, because they have the largest CO 2 storage capacity and the widest geographical spread. 13,27,[29][30][31][32][33][34][35][36][37][38][39] Wettability, as has been previously shown in laboratory experiments (at the mm to cm scale), has a significant effect on residual trapping 15,[40][41][42] and structural trapping. Indeed, water contact angles between 0°(strongly water-wet) and 170°(strongly CO 2 -wet) have been measured, where CO 2 -wettability mainly depends on the surface chemistry, and to a lesser extent on temperature, pressure, and brine composition.…”

Section: Introductionmentioning

confidence: 54%

Influence of CO₂‐wettability on CO₂ migration and trapping capacity in deep saline aquifers

et al. 2016

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CO2 migration and trapping capacity in deep saline aquifers are highly influenced by various rock and fluid parameters. One of the key parameters, which has received little attention, is CO2‐wettability. We thus simulated the behavior of a CO2 plume in a deep saline aquifer as a function of rock wettability and predicted various associated CO2 migration patterns and trapping capacities. We clearly show that CO2‐wet reservoirs are most permeable for CO2; CO2 migrates furthest upwards and the plume has a candle‐like shape, while in a water‐wet reservoir the plume is more compact and rain‐drop shaped. Furthermore, higher residual trapping capacities are achieved in water‐wet rock, while solubility trapping is more efficient in CO2‐wet rock. We thus conclude that rock wettability has a highly significant impact on both CO2 migration and trapping capacities and that water‐wet reservoirs are preferable CO2 sinks due to their higher storage capacities and higher containment security. © 2016 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Section: Introductionmentioning

confidence: 54%

Influence of CO₂‐wettability on CO₂ migration and trapping capacity in deep saline aquifers

et al. 2016

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“…reported that increasing water salinity from 0 wt% (DI water) to 20 wt% leads to an increase in advancing contact angle by 16° (from 59 o to 75 o ) and an increase in receding contact angle by 12° (from 54 o to 66 o ) for a mica surface at 323 K and 15 MPa. Similarly, significant increases were measured for quartz . This effect is caused by a better surface charge screening at higher salinities.…”

Section: Introductionmentioning

confidence: 57%

“…This increase in migration distance with increasing salinity is caused by the shift in the characteristics curves (i.e. relative permeability and capillary pressure); recall that salinity affects the CO 2 ‐rock wettability, and increasing brine salinity leads to reduced water wettability …”

Section: Resultsmentioning

confidence: 99%

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Impact of salinity on CO₂containment security in highly heterogeneous reservoirs

et al. 2017

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It is well established that brine salinity can vary substantially in prospective CO2 geo‐storage reservoirs. However, the impact of salinity on containment security has received only little attention. We thus used a compositional reservoir simulation to evaluate the effect of salinity on CO2 plume migration and CO2 trapping capacities in a 3D heterogeneous reservoir. The used heterogeneous reservoir consists of two formations: the bottom part of the reservoir is a fluvial reservoir, and the top part represents a near‐shore environment. Our results clearly indicate that salinity has a significant influence on CO2 migration and the relative amount of mobile, residual, and dissolved CO2. Lower salinity decreases CO2 mobility and migration distance, and enhances residual and solubility trapping significantly. We thus conclude that brine salinity is an important impact factor in the context of CO2 geo‐storage, and that less saline reservoirs are preferable CO2 sinks due to increased storage capacity and containment security. © 2017 Society of Chemical Industry and John Wiley & Sons, Ltd.

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“…Al-Anssari et al [129] investigated the influence of pressure on the wettability of calcites treated with and without nanoparticles in the presence of CO 2 to account for pressure variation with injection depth. An increase in pressure with increase in contact angle occurred for all surfaces tested which is attributed to an increase in intermolecular interactions between CO 2 and calcite, which increased significantly with increasing CO 2 density thus an implication of a reduction in structural and residual trapping capacities at reservoir conditions [126][127][128][130][131][132][133]. At ambient condition, oil-wet calcite was weakly CO 2 -wet (115 θa -0.1 MPa and 323 K) and strongly CO 2 -wet at storage conditions (148 θa -20 MPa and 323 K) -the high contact angle is an indication of possibilities of CO 2 leakage.…”

Section: Co 2 Storage and Leakage Inhibitionmentioning

confidence: 91%

A Realistic Look at Nanostructured Material as an Innovative Approach for Enhanced Oil Recovery Process Upgrading

Nwidee¹,

Barifcani²,

Lebedev³

et al. 2018

Recent Insights in Petroleum Science and Engineering

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With the continuous rise in energy demand and decline in reserves, the Petroleum Industries are constantly in search of inventive and novel approaches to optimize hydrocarbon recovery despite several decades of deployment of conventional and enhanced strategies. This chapter presents an in-depth analysis of nanomaterial (nanoparticles), their unique characteristics and potentials in relation to smart field development, enhanced oil recovery (EOR) and CO 2 geosequestration. The particles surface functionalities, unique size dependent property, adsorption, and transport behavior were scrutinized. The materials precise role in enhancing reservoir parameters that influences rock-fluid interactions, and reservoir fluid distribution and displacement such as permeability, wettability, interfacial tension, and asphaltene aggregate growth inhibition were evaluated. The study argues that the application of nanoparticle based fluids as novel EOR approach offers more holistic measures, potentials, and opportunities than micro and macro particles and can stimulate the continuous evolution of EOR processes even under harsh reservoir conditions, thus, offering better benefits over conventional surface-active agents. We believe this study will significantly impact the understanding of EOR with respect to nanoparticles, which is crucial for augmenting reservoir processes and to accelerate the realization of nanoparticles for EOR and CO 2 sequestration processes at industrial scale.Keywords: EOR, nanoparticles, adsorption, Asphaltene, wettability, IFT, permeability, viscosity, CO 2 © 2018 The Author(s). Licensee InTech. This chapter is distributed under the terms of the Creative Commons Attribution License (http://creativecommons.org/licenses/by/3.0), which permits unrestricted use, distribution, and reproduction in any medium, provided the original work is properly cited. OverviewIt is a fact that the period of cheap hydrocarbon recovery is waning as hydrocarbons are currently been explored in remote regions under harsh reservoir conditions. The accessible hydrocarbon resources are constantly declining with a corresponding increase in energy demand which invariably contributes to the price irregularities in the oil and gas industry. Globally, the growth in energy demand appears to be predominant amidst feasible unconventional energy options (renewable energy). Unarguably, newer energy sources, such as nuclear, wind, geo-thermal and solar are effective measures for addressing energy shortage. However, they are yet to be ample alternatives for substituting the role of oil in meeting the ever-rising energy demand. To date, these demands are currently being substantiated via hydrocarbon sources especially petroleum -oil is still the most valuable product with great global economic impact. Currently, diverse conventional strategies (waterflooding), and enhanced methods (use of chemicals, gases, and microbes) are been deployed in oil fields, regardless, these challenges persist. More efficient, yet cost-effective, environmenta...

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Receding and advancing (CO 2 + brine + quartz) contact angles as a function of pressure, temperature, surface roughness, salt type and salinity

Cited by 193 publications

References 45 publications

Influence of CO₂‐wettability on CO₂ migration and trapping capacity in deep saline aquifers

Influence of CO₂‐wettability on CO₂ migration and trapping capacity in deep saline aquifers

Impact of salinity on CO₂containment security in highly heterogeneous reservoirs

A Realistic Look at Nanostructured Material as an Innovative Approach for Enhanced Oil Recovery Process Upgrading

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Receding and advancing (CO 2 + brine + quartz) contact angles as a function of pressure, temperature, surface roughness, salt type and salinity

Cited by 193 publications

References 45 publications

Influence of CO2‐wettability on CO2 migration and trapping capacity in deep saline aquifers

Influence of CO2‐wettability on CO2 migration and trapping capacity in deep saline aquifers

Impact of salinity on CO2containment security in highly heterogeneous reservoirs

A Realistic Look at Nanostructured Material as an Innovative Approach for Enhanced Oil Recovery Process Upgrading

Contact Info

Product

Resources

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Influence of CO₂‐wettability on CO₂ migration and trapping capacity in deep saline aquifers

Influence of CO₂‐wettability on CO₂ migration and trapping capacity in deep saline aquifers

Impact of salinity on CO₂containment security in highly heterogeneous reservoirs