Visualization of hydrate formation during CO2 storage in water-saturated sandstone

Almenningen, Stian; Gauteplass, Jarand; Fotland, Per; Aastveit, Gry L.; Barth, Tanja; Ersland, Geir

doi:10.1016/j.ijggc.2018.11.008

Cited by 58 publications

(21 citation statements)

References 20 publications

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“…In addition, the dissociation process of CH 4 hydrate consisted of three stages—the initiation stage, the rapid dissociation stage, and the post dissociation stage. In addition, Almenningen, Gauteplass [ 58 ] visualized CO 2 -water drainage flow followed by hydrate formation using high-field MRI. It is important to identify CO 2 flow and hydrate growth patterns in sediment pores in order to obtain an effective hydrate sealing process.…”

Section: Modeling Regarding Dissociation and Formation Of Gas Hydratementioning

confidence: 99%

Numerical Simulation on the Dissociation, Formation, and Recovery of Gas Hydrates on Microscale Approach

Sholihah

Sean

2021

Molecules

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Investigations into the structures of gas hydrates, the mechanisms of formation, and dissociation with modern instruments on the experimental aspects, including Raman, X-ray, XRD, X-CT, MRI, and pore networks, and numerical analyses, including CFD, LBM, and MD, were carried out. The gas hydrate characteristics for dissociation and formation are multi-phase and multi-component complexes. Therefore, it was important to carry out a comprehensive investigation to improve the concept of mechanisms involved in microscale porous media, emphasizing micro-modeling experiments, 3D imaging, and pore network modeling. This article reviewed the studies, carried out to date, regarding conditions surrounding hydrate dissociation, hydrate formation, and hydrate recovery, especially at the pore-scale phase in numerical simulations. The purpose of visualizing pores in microscale sediments is to obtain a robust analysis to apply the gas hydrate exploitation technique. The observed parameters, including temperature, pressure, concentration, porosity, saturation rate, and permeability, etc., present an interrelationship, to achieve an accurate production process method and recovery of gas hydrates.

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Section: Modeling Regarding Dissociation and Formation Of Gas Hydratementioning

confidence: 99%

Numerical Simulation on the Dissociation, Formation, and Recovery of Gas Hydrates on Microscale Approach

Sholihah

Sean

2021

Molecules

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“…The pore habit of gas hydrate in sediments is important for hydrate-based geological CO 2 capture and storage and their long term stability. Experimental studies suggest the formation of both pore filling [73,74] and grain coating CO 2 hydrate morphologies [63]. The limitation with these studies lies in the experimental design as the experimental setup is a batch reactor without provision of a constant CO 2 supply.…”

Section: Induction Time Measurement In Isothermal Experimentsmentioning

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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“…The study of fluid mobility is commonly addressed by flow-through experiments under reservoir conditions in the laboratory, typically complemented with non-intrusive techniques such as computed tomography (CT) scanning (Akbarabadi and Piri, 2013;Krevor et al, 2012), magnetic resonance imaging (Almenningen et al, 2018), or electrical resistivity (Carrigan et al, 2013;Falcon-Suarez et al, 2016;Nakatsuka et al, 2010). Electrical resistivity is also used as a remote sensing technique for monitoring the CO 2 plume advance in saline aquifers (i.e., controlled-source electromagnetic surveys -CSEM, e.g., Park et al (2013)), due to the strong resistivity contrast between brine (low resistivity) and CO 2 (high resistivity).…”

Section: Introductionmentioning

confidence: 99%

Transport properties of saline CO2 storage reservoirs with unconnected fractures from brine-CO2 flow-through tests

Muñoz‐Ibáñez

Falcón-Suarez

Marín‐Moreno

et al. 2020

Journal of Petroleum Science and Engineering

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CO 2 storage in fractured reservoirs may lead to fast CO 2 flow through interconnected fracture networks; but the role of isolated fractures on brine-CO 2 multiphase flow systems remains unclear. We present the results of a brine-CO 2 flow-through experiment in which we assess the change in transport properties of a synthetic sandstone plug (a surrogate of a saline siliciclastic CO 2 reservoir) containing non-connected fractures aligned 45 � from its axis. The test was performed at 40 MPa of constant hydrostatic confining pressure and ~11 MPa of pore pressure, at room temperature (~19.5 � C), using pure liquid-CO 2 and 35 g L À 1 NaCl salt solution. The injected CO 2-brine volume fraction was increased from 0 to 1 in 0.2 units-steps (drainage). Upon achievement of the maximum CO 2 saturation (S CO2 ~0.6), the plug was flushed-back with the original brine (imbibition). During the test, we monitored simultaneously pore pressure, temperature, axial and radial strains, and bulk electrical resistivity. The fractured sample showed lower values of cross-and end-points in the relative permeability curves to CO 2 compared to non-fractured samples, from comparable experiments performed at similar pressure and brine salinity conditions, but different temperature. Our results suggest that a non-connected fracture network affects the mobility of the individual phases, favouring the trapping of CO 2 in the porous medium and improving the storage efficiency of the reservoir. These evidences show the need of a better understanding of fracture connectivity prior to discard fractured reservoirs as unsuitable geological formations for CO 2 storage.

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Visualization of hydrate formation during CO2 storage in water-saturated sandstone

Cited by 58 publications

References 20 publications

Numerical Simulation on the Dissociation, Formation, and Recovery of Gas Hydrates on Microscale Approach

Numerical Simulation on the Dissociation, Formation, and Recovery of Gas Hydrates on Microscale Approach

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

Transport properties of saline CO2 storage reservoirs with unconnected fractures from brine-CO2 flow-through tests

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