Offshore Gas Hydrates 2015
DOI: 10.1016/b978-0-12-802319-8.00005-x
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Hydrate Inhibition During Drilling and Production

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Cited by 5 publications
(4 citation statements)
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“…Therefore, KHIs and AAs classified as LDHIs, typically effective at 0.5–2 vol %, are of significant interest. , KHIs are used to delay hydrate nucleation and growth times by affecting the hydrogen-bonding network of water . Conversely, AAs work by preventing hydrate particle agglomeration, managing hydrate formation risks, and extending the lifespan of the production assets. The prevention of hydrate particles from agglomeration not only affects flow assurance in oil and gas fields but also other technological applications, such as energy storage (natural gas and hydrogen), gas separation, desalination, and so forth.…”
Section: Introductionmentioning
confidence: 99%
“…Therefore, KHIs and AAs classified as LDHIs, typically effective at 0.5–2 vol %, are of significant interest. , KHIs are used to delay hydrate nucleation and growth times by affecting the hydrogen-bonding network of water . Conversely, AAs work by preventing hydrate particle agglomeration, managing hydrate formation risks, and extending the lifespan of the production assets. The prevention of hydrate particles from agglomeration not only affects flow assurance in oil and gas fields but also other technological applications, such as energy storage (natural gas and hydrogen), gas separation, desalination, and so forth.…”
Section: Introductionmentioning
confidence: 99%
“…Even so, there was a significant association between increased depth and clam beds, despite the narrow range of depths encountered (~6 m). This relationship between clam distribution and local lows on a soft-sediment seabed may reflect hydrogeological processes, including methane escape and sediment instabilities (Rogers, 2015). This relationship was not consistently observed at the Blake Ridge "Main" seep site (Wagner et al, 2013).…”
Section: Morphotype Distributions and Associationsmentioning
confidence: 96%
“…Therefore, researchers are interested in using KHIs, which are water-soluble polymers and require significantly less concentration than THIs to show hydrate suppression . Moreover, they also do not shift the hydrate–liquid–vapor equilibrium (HLVE) curve …”
Section: Drilling Fluids For Gas Hydrate Wellsmentioning
confidence: 99%
“…203 Moreover, they also do not shift the hydrate−liquid−vapor equilibrium (HLVE) curve. 204 In major drilling expeditions, water-based drilling fluid (WBM), generally seawater, was preferred as a result of its economic feasibility at a shallower depth. 205 The induction time for hydrate formation in oil-based mud (OBM) is lower than that in WBM because gas readily dissolves in oil than water.…”
Section: Drilling Fluids For Gas Hydrate Wellsmentioning
confidence: 99%