Probability distributions of gas hydrate formation

Wu, Reuben; Kozielski, Karen; Hartley, Patrick G.; May, Eric F.; Boxall, J.; Maeda, Nobuyo

doi:10.1002/aic.14037

Cited by 46 publications

(43 citation statements)

References 18 publications

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“…At all concentrations, it was observed that the hydrate formation temperature increased with operating pressure as shown in Figure (20), these results perfectly agreed with the published literature (Moraveji et al, 2010;Wu et al, 2013).…”

Section: Pressure Effect On Formation Temperature Point For Dpcsupporting

confidence: 90%

The influence of corrosion inhibitors on hydrate formation temperature along the subsea natural gas pipelines

Obanijesu

Gubner

Barifcani

et al. 2014

Journal of Petroleum Science and Engineering

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Pipeline industry annually invests millions of dollar on corrosion inhibitors in order to minimize corrosion's implication on flow assurance; however, attention has never been focused on the possibilities of these chemicals to promote hydrate formation along deepwater pipeline which is also a flow assurance problem. Five inhibitors were investigated in this study at different concentrations and pressures in a cryogenic sapphire cell at static condition. The changes in the formation temperature established that all the inhibitors promote hydrate but at different rates while their hydrate formation patterns also differ from one another. Their ability to promote hydrate could be attributed to their hydrogen bonding properties which is required for hydrate formation. Also, the difference in the promotion rate is attributed to their different sizes and structures, active functional groups and affinity for water molecules which determine the type of hydrogen bonding exhibited by each inhibitor while in solution. The structure and size of each inhibitor also affect its electronegativity and ionization energy since the active electrons of some of the inhibitors have direct exposure to the nucleus while for others; the active electrons at the outermost shell have been shielded from direct influence of the attractive force. Furthermore, the active functional groups obeys electronegativity trend of periodic table to determine whether the resulting bond type will be polar ionic, covalent or ionic with some covalent characteristic in nature. Though, all the inhibitors are foamy; Dodecylpyridinium chloride (DPC) was however the foamiest. DPC also exhibited its highest promotion ability at 200ppm and exhibited specific behaviour at 5000ppm to suggest a change in the hydrate formation rate beyond the critical micelles concentration (CMC). Again, increase in agitation rate prolonged the complete solidification time of the hydrates probably due to the gas solubility. Finally, the feasibility of using this chemical as an additive at high concentrations for natural gas transportation and storage in slurry form was observed due to some exhibited properties, this however requires further investigations.

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Section: Pressure Effect On Formation Temperature Point For Dpcsupporting

confidence: 90%

The influence of corrosion inhibitors on hydrate formation temperature along the subsea natural gas pipelines

Obanijesu

Gubner

Barifcani

et al. 2014

Journal of Petroleum Science and Engineering

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“…Results of hydrate nucleation induction time vs. wax contents and stirring rates under the initial pressure of 7.0 MPa are shown in Figure . Although the number of trials conducted by this high‐pressure hydrate slurry rheological measurement system does not reach a statistically significant number, the inhibition influence of wax crystals on hydrate nucleation induction time is clearly defined. To analyze the influence of wax content on hydrate nucleation induction time more clearly, a wax content influence factor (WI) is defined as Eq.…”

Section: Resultsmentioning

confidence: 99%

An investigation on gas hydrate formation and slurry viscosity in the presence of wax crystals

et al. 2018

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Clarifying the interaction effect between hydrate and wax is of great significance to guarantee operation safety in deep water petroleum fields. Experiments in a high-pressure hydrate slurry rheological measurement system were carried out to investigate hydrate formation and slurry viscosity in the presence of wax crystals. Results indicate that the presence of wax crystals can prolong hydrate nucleation induction time, and its influence on hydrate growth depends on multiple factors. Higher stirring rate can obviously promote hydrate growth rate, while its influence on hydrate nucleation induction time is complicated. Higher initial pressure will promote hydrate formation. Gas hydrate slurry shows a shearthinning behavior, and slurry viscosity increases with the increase of wax content and initial pressure. A semiempirical viscosity model showing a well-fitting is established for hydrate slurry with wax crystals by considering the aggregation and breakage of hydrate particles, wax crystals, and water droplets.

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“…Figure shows schematically the first-generation high-pressure automated lag time apparatus (HP-ALTA MkI) used in this study. Both the instrumental capabilities and modes of operation of HP-ALTA MkI can be found in refs − . An HP-ALTA can apply a large number of linear (constant cooling rate) cooling ramps to a small quiescent water sample of well-defined dimensions under isobaric conditions, detect the formation of gas hydrate on the surface of the sample water, and record the temperature at which the hydrate formation occurred.…”

Section: Methodsmentioning

confidence: 99%

Nucleation Curve of Carbon Dioxide Hydrate from a Linear Cooling Ramp Method

Maeda

2019

J. Phys. Chem. A

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Formation of gas hydrate is a first-order phase transition that starts with nucleation. Understanding of nucleation is of interest to many in chemical and petroleum industries, as nucleation, while beneficial in many chemical processes, is detrimental in flow assurance of oil and natural gas pipelines. A primary difficulty in the investigation of gas hydrate nucleation has been the inability of researchers to compare nucleation rates of gas hydrates across various systems of different scales and complexities, which in turn has been limiting the ability of researchers to study the nucleation process itself. In this study, a first-generation high-pressure automated lag time apparatus (HP-ALTA MkI) was used to determine the nucleation curve of structure I (sI) - forming carbon dioxide hydrate. The instrument subjected a quiescent water sample of well-defined dimensions to a large number of linear cooling ramps under isobaric conditions, and detected and recorded carbon dioxide hydrate formation temperature distributions. A survival curve was constructed from the measured ensemble, and a nucleation curve was derived from the survival curve using the empirical model-independent method we had previously reported. The nucleation rate of carbon dioxide hydrate was found to be significantly greater than that of pure methane hydrate or that of natural gas hydrate over the entire range of subcooling investigated. We provide a new physical interpretation of an experimentally determined nucleation curve and, by doing so, solve one of the outstanding puzzles of the HP-ALTA technology.

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Probability distributions of gas hydrate formation

Cited by 46 publications

References 18 publications

The influence of corrosion inhibitors on hydrate formation temperature along the subsea natural gas pipelines

The influence of corrosion inhibitors on hydrate formation temperature along the subsea natural gas pipelines

An investigation on gas hydrate formation and slurry viscosity in the presence of wax crystals

Nucleation Curve of Carbon Dioxide Hydrate from a Linear Cooling Ramp Method

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