A study of hydrate plug formation in a subsea natural gas pipeline using a novel high-pressure flow loop

Li, Wenqing; Gong, Jing; Lu, Xiaoqing; Zhao, Junfang; Feng, Yaorong; Yu, Dingwen

doi:10.1007/s12182-013-0255-8

Cited by 41 publications

(40 citation statements)

References 16 publications

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“…After each formation, it was generally observed that the temperature dropped further below the formation temperature value before the hydrate started agglomerating, it was however observed that the temperatures at each concentration followed the trend of 50 bar < 100bar < 150 bar. This also agreed with established literature that the hydrate growth rate directly is proportional to operating pressure (DelleCase et al, 2008;Li et at, 2013). Specific observations concerning each pressure are further presented below.…”

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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“…In these circumstances, it is preferable to use SPCs based on regulated electrical drives for subsea transportation of hydrocarbons (Parks, & Pack, 2013, Li, Gong et al, 2013.…”

Section: Methodsmentioning

confidence: 99%

Technologies for transporting hydrocarbons from offshore Arctic seas

Vasilev¹

2017

European Proceedings of Social and Behavioural Sciences

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* Corresponding author(a) Saint-Petersburg Mining University, 2, 21 line, Saint Petersburg, Russia, vasilev.bu@yandex.ru, +7 (952) 384-97-25 (b) Saint-Petersburg Mining University, 2, 21 line, Saint Petersburg, Russia, slava19887@yandex.ru, +7 (952) 249-67-07 AbstractThe largest deposits of hydrocarbons (oil, gas and condensate) are located on the shelf of the Arctic seas, characterized by difficult natural climatic conditions (ice conditions, temperature, wind and currents) that limit access to the deposit during the year. This circumstance brings up-to-date and requires research and development in the search for alternative technical means of exploration of offshore hydrocarbon deposits for existing ones (floating production platforms, tankers, etc.). Year-round exploitation and transport of hydrocarbons from the offshore may be ensured by subsea pumping complexes (SPC). The subject of research in this article is SPC electrical mechanical systems of hydrocarbons transportation from offshore deposits. The main objective is to identify operation issues of existing electrical mechanical systems of pumping complexes of the continental pipelines, make up proposals how to handle them when used as a part of SPC to ensure high reliability and develop prospective structures and components of SPC electrical mechanical systems. Also, the article considers existing SPCs and projects where they are used to explore offshore hydrocarbon deposits.

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“…This trend has been conrmed by some researchers. 23,29,[31][32][33][34][35][36] 3.4.2 The distribution of the average and square weighted particle chord length. In order to better understand the particle chord length at different time during the CO 2 hydrate formation, we specially studied the average particle chord length and square weighted particle chord length in this process, as shown in Fig.…”

Section: The Inuence Of Pressure On the Blockage Of Hydratementioning

confidence: 99%

Study on the blockage mechanism of carbon dioxide hydrate slurry and its microscopic particle characteristics

Shi

et al. 2018

RSC Adv.

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A study of hydrate plug formation in a subsea natural gas pipeline using a novel high-pressure flow loop

Abstract: The natural gas pipeline from Platform QK18-1 in the southwest of Bohai Bay to the onshore processing facility is a subsea wet gas pipeline exposed to high pressure and low temperature management of the subsea pipeline.

Cited by 41 publications

References 16 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

Technologies for transporting hydrocarbons from offshore Arctic seas

Study on the blockage mechanism of carbon dioxide hydrate slurry and its microscopic particle characteristics

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