Enhanced safety of geologic CO2 storage with nanoparticles

Singh, Harpreet; Islam, Akand W.

doi:10.1016/j.ijheatmasstransfer.2017.12.152

Cited by 20 publications

(8 citation statements)

References 52 publications

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“…Recently, a method has been proposed to accelerate the dissolution of CO 2 and brine and reduce the risk of leakage with co-injection of CO 2 with nanoparticles (NPs). Low-level nuclear waste containing NPs was suggested to be an economical method through a fully mixing with CO 2 before injection [8,9]. While the interfacial properties of the accelerated dissolution processes have rarely been studied.…”

Section: Introductionmentioning

confidence: 99%

Co-injection of CO2 and Nanoparticles Enhance Sequestration Potential in Subsurface Aquifers

Sijia¹,

Wang²,

Li³

et al. 2022

Preprint

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CO 2 storage in deep saline aquifers is a promising technique for carbon neutrality. Accelerating the dissolution rate of dissolution trapping is key to improving storage efficiency and providing long-term storage security. In this study, density-driven convection processes were conducted using magnetic resonance imaging (MRI) with two analog fluid pairs as equivalents of the CO 2 -brine fluid system. Superhydrophilic SiO 2 NPs with different mass fractions (0 wt%, 0.1 wt%, and 1 wt%) were added to the dense fluid to investigate the optimum mixing ratio. The basic fluid interface instability is identified. The addition of nanoparticles shortens the onset time of instability and increases the finger numbers in each axial section. It shows that dense fluid with NPs leads to more stable interface behavior. Furthermore, experimental results confirm that a reduction in surface tension between NPs and CO 2 would enhance fluid miscibility and the mass transfer during convection. This study can expand the perspective on accelerated dissolution rates and CCS security in the substance.

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Section: Introductionmentioning

confidence: 99%

Co-injection of CO2 and Nanoparticles Enhance Sequestration Potential in Subsurface Aquifers

Sijia¹,

Wang²,

Li³

et al. 2022

Preprint

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“…It requires knowledge and skills from geology, fluid mechanics, chemistry, geochemistry, hydrogeology, and environmental science. Current research questions in CO2 geological sequestration focus on the improvement of the injection techniques (Hoteit et al, 2019;Sigfusson et al, 2015), ensuring safe and successful implementation (Romasheva and Ilinova, 2019;Singh and Islam, 2018;Soltanian et al, 2019), enhancement of reservoirs capacity (Kim et al, 2017;Raziperchikola et al, 2013), and assessment and prediction of the geological and environmental impacts (Chen et al, 2018). A key point in addressing these research questions relies on a good understanding of the fate of CO2 in geological formations.…”

Section: Introductionmentioning

confidence: 99%

Convective-reactive transport of dissolved CO2 in fractured-geological formations

Shafabakhsh

Ataie-Ashtiani

Simmons

et al. 2021

International Journal of Greenhouse Gas Control

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“…In this regard, the focus of past studies has been to understand the behavior of these systems, including migration within the storage reservoir, chemical reaction with geologic media, potential leakage through wells, leak through the caprock, potential leakage through faults and fractures, and impact of variable injection schemes . Some studies have also considered the impact of these phenomena as a function of scale and various multiphase modeling approaches for CO 2 storage . Many of these studies have been helpful in increasing our fundamental knowledge of the processes at small to regional scale.…”

Section: Introductionmentioning

confidence: 99%

“…23 Some studies have also considered the impact of these phenomena as a function of scale [24][25][26][27][28] and various multiphase modeling approaches for CO 2 storage. 29,30 Many of these studies have been helpful in increasing our fundamental knowledge of the processes at small to regional scale. At the reservoir scale, there have been many simulation and sensitivity studies of CO 2 injection useful in defining the effect of boundary conditions, 31 relative permeability, [32][33][34] and other parameters 35 on the behavior of pressure and saturation.…”

Section: Introductionmentioning

confidence: 99%

Two risk metrics for CO₂storage reservoirs with varying domain size, heterogeneity, and injection rate

Singh

Bromhal

2019

Greenhouse Gases

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Two parameters that play the most important role in the appraisal of environmental risk performance at carbon dioxide (CO2) storage sites are the prospective impact of the pore pressure increase and CO2 saturation. In this context, this study investigates the spatiotemporal evolution of pressure buildup and CO2 saturation as a function of flow region's size, average porosity and permeability, and heterogeneity, as well as the injection rate and total volume of injected fluid. The practical importance of this study is to investigate the factors that affect the extent of pressure buildup and areal extent of CO2 plume both during and after injection, which will impact risk assessment as well as influence effective monitoring operations. This study pursues the above objective using two risk metrics that are based on numerical simulations and illustrated using representative models of three realistic storage sites with varying volumetric storage potential and geological settings, all with open geologic systems. The two metrics (the spatiotemporal extent of pressure buildup and CO2 saturation plume, respectively) used in this study are able to capture the geologic (structural and petrophysical) and operational complexities that cannot be incorporated into analytical or semianalytical solutions. The results of this study suggest that in addition to the average permeability, the areal extent of the pressure buildup during the injection period is strongly related to the injection rate, whereas the postinjection period may be more strongly influenced by the reservoir heterogeneity. The areal extent of the saturation plume during active injection is highly correlated to the mass of injected fluid, and the postinjection behavior is impacted by the shape of the reservoir–seal interface. These findings are consistent with other recent studies by the National Risk Assessment Partnership (NRAP) on characteristic reservoir behavior. The results have been used to generate pressure and saturation plume profiles (over time) that can be used to support risk‐based decision making. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Enhanced safety of geologic CO2 storage with nanoparticles

Cited by 20 publications

References 52 publications

Co-injection of CO2 and Nanoparticles Enhance Sequestration Potential in Subsurface Aquifers

Co-injection of CO2 and Nanoparticles Enhance Sequestration Potential in Subsurface Aquifers

Convective-reactive transport of dissolved CO2 in fractured-geological formations

Two risk metrics for CO₂storage reservoirs with varying domain size, heterogeneity, and injection rate

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Enhanced safety of geologic CO2 storage with nanoparticles

Cited by 20 publications

References 52 publications

Co-injection of CO2 and Nanoparticles Enhance Sequestration Potential in Subsurface Aquifers

Co-injection of CO2 and Nanoparticles Enhance Sequestration Potential in Subsurface Aquifers

Convective-reactive transport of dissolved CO2 in fractured-geological formations

Two risk metrics for CO2storage reservoirs with varying domain size, heterogeneity, and injection rate

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Product

Resources

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Two risk metrics for CO₂storage reservoirs with varying domain size, heterogeneity, and injection rate