Enhanced Hydrate-Based Geological CO 2 Capture and Sequestration as a Mitigation Strategy to Address Climate Change

• Published in: Energies
• Main Authors: Pandey, Jyoti Shanker, Daas, Yousef Jouljamal, Karcz, Adam Paul, Solms, Nicolas von
• Format: Article in Journal/Newspaper
• Language: English
• Published: 2020
• Subjects: Climate change; CO2 capture and sequestration; Amino acids; Formation kinetics; Permafrost and marine sands; /dk/atira/pure/sustainabledevelopmentgoals/climate_action; name=SDG 13 - Climate Action; /dk/atira/pure/sustainabledevelopmentgoals/life_below_water; name=SDG 14 - Life Below Water; permafrost
• Online Access: https://orbit.dtu.dk/en/publications/07ef320d-16fa-411d-9356-4ef52a5a73e5; https://doi.org/10.3390/en13215661; https://backend.orbit.dtu.dk/ws/files/222877361/energies_13_05661.pdf

Geological sequestration of CO 2 -rich gas as a CO 2 capture and storage technique has a lower technical and cost barrier compared to industrial scale-up. In this study, we have proposed CO 2 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 CO 2 capture efficiency in hydrate in the presence of kinetic promoters while using diluted CO 2 gas (CO 2 -N 2 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 CO 2 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 CO 2 split fraction (0.60–0.90) in hydrate for 120 bar initial injection pressure. CO 2 split fraction can be enhanced by reducing sand particle size or increasing the CO 2 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 ...