Quest carbon capture and storage offset project: Findings and learnings from 1st reporting period

Duong, Celina; Bower, Charles; Hume, Ken; Rock, Luc; Tessarolo, Stephen

doi:10.1016/j.ijggc.2019.06.001

Cited by 27 publications

(15 citation statements)

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“…The capillary number ( C a = μ V /σ: the relative effect of viscous forces versus surface tension, where μ represents the viscosity of CO 2 , V represents the characteristic pore velocity of CO 2 , and σ represents the interfacial tension of CO 2 and brine) ranges from 3.13 × 10 –6 to 6.25 × 10 –5 , which can be matched to that in the Quest CCS Project in Canada. One of the injection wells, called IW 8–19, has been operated with an average injection rate of 70 T/h (0.61 Mt/a), − and the capillary number (Ca) near the injection well is around 4.5 × 10 –6 . The nine detailed experimental cases are listed in Table .…”

Section: Methodsmentioning

confidence: 99%

Pore-Scale Experimental Investigation of the Effect of Supercritical CO₂ Injection Rate and Surface Wettability on Salt Precipitation

Jiang

2019

Environ. Sci. Technol.

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Injectivity is one of the most important factors to evaluate the feasibility of CO2 geological storage. Salt precipitation due to the mass of dry CO2 injected into a saline reservoir may cause a significant decrease in injectivity. However, the coupling effect of injection parameters and reservoir conditions on salt precipitation is not clear. Here, we conducted pore-scale visualization experiments to study the morphology and distribution of salt precipitation in porous structures and their effects on permeability reduction. The experimental results are achieved by controlling the supercritical CO2 injection rate and the surface wettability at the reservoir temperature and pressure. It is found that for hydrophilic and neutral porous surfaces, ex situ precipitation occurs and blocks the entirety of pore throats and bodies, which results in a significant reduction in permeability. Increasing the CO2 injection rate can suppress the capillary reflow and prevent the permeability reduction. For a hydrophobic porous surface, in situ precipitation occurs and occupies much smaller pore volume, which has a slight effect on permeability reduction compared to the hydrophilic samples at the same injection rate. Increasing the CO2 injection rate and dewetting the injection well and formation nearby reduce the possibility of salt accumulation, which has less effect on CO2 injectivity.

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Section: Methodsmentioning

confidence: 99%

Pore-Scale Experimental Investigation of the Effect of Supercritical CO₂ Injection Rate and Surface Wettability on Salt Precipitation

Jiang

2019

Environ. Sci. Technol.

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“…In the North Sea, 20 million tons have been injected into the Sleipner project since 1996 and more than 4 million tons have been injected into the Snohvit formation as of 2019. In Alberta, Canada, Shell and its partners are injecting CO 2 into the Basal Cambrian Sands as part of the Quest project and have injected more than 4 million tons of CO 2 as of 2019. , The most recent project to have started injection is Archer Daniel Midland’s injection into the Mt. Simon sandstone in Illinois, USA, which has injected several million tons of CO 2 without issue .…”

Section: Overview Of Carbon Sequestration Pathwaysmentioning

confidence: 99%

Carbon Dioxide Sequestration via Gas Hydrates: A Potential Pathway toward Decarbonization

et al. 2020

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Climate change is known to be dominantly caused by the increased concentration of greenhouse gases in the atmosphere, in particular CO2. To prevent excessive accumulation of CO2 in the atmosphere and the perturbation of natural carbon cycles, carbon capture and sequestration (CCS) is urgently needed. In this review, a brief overview is provided for both biotic and abiotic CO2 sequestration pathways. Special focus is given to sequestration approaches pertaining to clathrate hydrates. CO2 hydrate, a solid compound made of molecular CO2 enclathrated in crystalline lattices formed by water molecules, is an attractive option for long-term CO2 sequestration due to its higher density than seawater, stability below moderate oceanic/permafrost depths, low susceptibility to fluid flow perturbation when formed in sediments. This review compiles and summarizes the research efforts made on CO2 sequestration as hydrates. Various approaches of CO2 sequestration via gas hydrates are discussed, including storage in seawater, sediments under the sea floor, permafrost regions, methane hydrate reservoirs via CO2–CH4 exchange, and depleted gas fields. The technical feasibility and potential storage capacity of these approaches are analyzed. Finally, the key scientific challenges and prospects are identified and highlighted. Issues related to economics, scale-up, and relative attractiveness versus non-hydrate methods are touched upon but are not the focus of this work.

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“…A trapping mechanism via the CO 2 hydrate layer at the base of the gas hydrate stability zone, to prevent upward migration of CO 2 , was suggested by Koide et al [24]. Projects having CO 2 successfully stored in deep saline aquifers highlight the importance of a suitable sealing cap mechanism to prevent CO 2 from leaking for long term storage [28][29][30]. Potential locations to capture and store CO 2 as gas hydrate are described in Figure 2.…”

Section: Introductionmentioning

confidence: 99%

Enhanced Hydrate-Based Geological CO2 Capture and Sequestration as a Mitigation Strategy to Address Climate Change

et al. 2020

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Geological sequestration of CO2-rich gas as a CO2 capture and storage technique has a lower technical and cost barrier compared to industrial scale-up. In this study, we have proposed CO2 capture and storage via hydrate in geological formation within the hydrate stability zone as a novel technique to contribute to global warming mitigation strategies, including carbon capture, utilization, and storage (CCUS) and to prevent vast methane release into the atmosphere caused by hydrate melting. We have attempted to enhance total gas uptake and CO2 capture efficiency in hydrate in the presence of kinetic promoters while using diluted CO2 gas (CO2-N2 mixture). Experiments are performed using unfrozen sands within hydrate stability zone condition and in the presence of low dosage surfactant and amino acids. Hydrate formation parameters, including sub-cooling temperature, induction time, total gas uptake, and split fraction, are calculated during the single-step formation and dissociation process. The effect of sands with varying particle sizes (160–630 µm, 1400–5000 µm), low dosage promoter (500–3000 ppm) and CO2 concentration in feed gas (20–30 mol%) on formation kinetic parameters was investigated. Enhanced formation kinetics are observed in the presence of surfactant (1000–3000 ppm) and hydrophobic amino acids (3000 ppm) at 120 bar and 1 ℃ experimental conditions. We report induction time in the range of 7–170 min and CO2 split fraction (0.60–0.90) in hydrate for 120 bar initial injection pressure. CO2 split fraction can be enhanced by reducing sand particle size or increasing the CO2 mol% in incoming feed gas at given injection pressure. This study also reports that formation kinetics in a porous medium are influenced by hydrate morphology. Hydrate morphology influences gas and water migration within sediments and controls pore space or particle surface correlation with the formation kinetics within coarse sediments. This investigation demonstrates the potential application of bio-friendly amino acids as promoters to enhance CO2 capture and storage within hydrate. Sufficient contact time at gas-liquid interface and higher CO2 separation efficiency is recorded in the presence of amino acids. The findings of this study could be useful in exploring the promoter-driven pore habitat of CO2-rich hydrates in sediments to address climate change.

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Quest carbon capture and storage offset project: Findings and learnings from 1st reporting period

Cited by 27 publications

References 1 publication

Pore-Scale Experimental Investigation of the Effect of Supercritical CO₂ Injection Rate and Surface Wettability on Salt Precipitation

Pore-Scale Experimental Investigation of the Effect of Supercritical CO₂ Injection Rate and Surface Wettability on Salt Precipitation

Carbon Dioxide Sequestration via Gas Hydrates: A Potential Pathway toward Decarbonization

Enhanced Hydrate-Based Geological CO2 Capture and Sequestration as a Mitigation Strategy to Address Climate Change

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Quest carbon capture and storage offset project: Findings and learnings from 1st reporting period

Cited by 27 publications

References 1 publication

Pore-Scale Experimental Investigation of the Effect of Supercritical CO2 Injection Rate and Surface Wettability on Salt Precipitation

Pore-Scale Experimental Investigation of the Effect of Supercritical CO2 Injection Rate and Surface Wettability on Salt Precipitation

Carbon Dioxide Sequestration via Gas Hydrates: A Potential Pathway toward Decarbonization

Enhanced Hydrate-Based Geological CO2 Capture and Sequestration as a Mitigation Strategy to Address Climate Change

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Pore-Scale Experimental Investigation of the Effect of Supercritical CO₂ Injection Rate and Surface Wettability on Salt Precipitation

Pore-Scale Experimental Investigation of the Effect of Supercritical CO₂ Injection Rate and Surface Wettability on Salt Precipitation