A bench-scale flow loop study on hydrate deposition under multiphase flow conditions

Zhang, Xianwei; Straume, Erlend Oddvin; Grasso, Giovanny; Morales, Rigoberto E. M.; Sum, Amadeu K.

doi:10.1016/j.fuel.2019.116558

Cited by 22 publications

(12 citation statements)

References 27 publications

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“…Natural gas hydrates (NGHs) are crystalline compounds composed of water and hydrocarbon gas molecules . NGHs are readily formed under the low-temperature and high-pressure conditions in oil and gas industry and could therefore pose a great threat to subsea flow assurance by agglomerating, jamming, bedding, and depositing in the transmission pipelines. − So far, NGHs in subsea flow assurance have been extensively investigated, and several hydrate prevention/management strategies have been proposed. − Except for NGHs, another big concern in subsea flow assurance is about wax. When the pipeline operating temperature falls below the wax appearance temperature (WAT), wax molecules dissolved in the crude oil will gradually precipitate and may deposit on the pipe wall, which may further lead to pipeline plugging.…”

Section: Introductionmentioning

confidence: 99%

Investigation on Hydrate Growth at the Oil–Water Interface: In the Presence of Wax and Kinetic Hydrate Inhibitor

Song

Ning

et al. 2020

Langmuir

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In oil industry, the coexistence of hydrate and wax can result in a severe challenge to subsea flow assurance. In order to study the effects of wax on hydrate growth at the oil–water interface, a series of microexperiments were conducted in a self-made reactor, where hydrates gradually nucleated and grew on the surface of a water droplet immersed in wax-containing oil. According to the micro-observations, hydrate shells formed at the oil–water interface in the absence of kinetic hydrate inhibitor (KHI). The roughness and growth rate of hydrate shells were analyzed, and the effects of wax were investigated. In addition, vertical growth of the hydrate shell was observed in the presence of wax, and a mechanism was proposed for illustration. In the presence of KHI, small hydrate crystals formed separately at the oil–water interface instead of hydrate shells. The presence of KHI reduced the growth rate of hydrates and changed the wettability of hydrates. Moreover, the presence of wax showed no obvious effect on the effectiveness of KHI under experimental conditions.

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Section: Introductionmentioning

confidence: 99%

Investigation on Hydrate Growth at the Oil–Water Interface: In the Presence of Wax and Kinetic Hydrate Inhibitor

Song

Ning

et al. 2020

Langmuir

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“…When 4 wt % SiO 2 was added, the hydrate growth process was completed in 120 s without a coated surface. At this time, the hydrate growth area of the coating layer was 4.714 cm 2 , which was 89.8% of the uncoated surface hydrate growth area of 5.25 cm 2 .…”

Section: Coatings Effect On Adhesion Forcementioning

confidence: 89%

“…Hydrate accretion in certain locations, such as in oil and gas pipeline systems, on throttles, and on expansion valves, may lead to substantial safety risks and enormous economic losses. , Hydrate formation on the interior surfaces of pipelines has been a persistent nuisance and hazard for oil and gas exploration and transportation activities, such as in offshore and deep sea oil and gas pipelines . Hydrate removal is typically accomplished via active de-icing techniques, such as thermal, mechanical, and/or chemical techniques, which require continued reapplication.…”

Section: Introductionmentioning

confidence: 99%

Reduction Clathrate Hydrates Growth Rates and Adhesion Forces on Surfaces of Inorganic or Polymer Coatings

Fan

Zhang

Yang³

et al. 2020

Energy Fuels

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Hydrate plugging is one of the major risks for oil and gas transportation in pipelines. To mitigate the adhesion between hydrate particles and pipeline walls, hexagonal boron nitride (HBN), polydimethylsiloxane (PDMS), and fluoro-coating (F-coating) were added with hydrophobic fuming SiO2 as coating materials, which were coated on four different substrates (X70 steel, X80 steel, zirconia plate (ZrO2), and tinplate). The adhesion force between tetrahydrofuran (THF) hydrate particles and coated substrates was measured by a micromechanical force apparatus (MMF). For the X70 substrate with F-coating, the adhesion force was reduced by 80.3% when the mass fraction of SiO2 was increased from 1 wt % (0.0152 N/m) to 4 wt % (0.0030 N/m). SiO2 exhibits hydrate-phobic properties. The adhesion forces were 0.0105, 0.0027, and 0.0043 N/m for X80 (bare), X80+HBN, and X80+PDMS. PDMS+SiO2(1–4 wt %) coating was found able to slow the growth rate of hydrate. In a high-pressure reactor, methane hydrate growth on PDMS+SiO2(4 wt %) coating on the tinplate substrate was studied. No growth of methane hydrate on the coated layer was observed, while there was full coverage on the noncoated layer. The presence of coating was found effective for hindering the growth and attachment of both THF and methane hydrates. Surface morphology was believed to be one of the main factors affecting the adhesion and growth characteristics of hydrate particles. Hydrate-phobic coating has been put forward in this work that refers to a functional coating that prevents hydrates.

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“…Several researchers have addressed possible solutions to minimize these issues. [31][32][33][34][35][36][37][38][39]…”

Section: Gas Hydratesmentioning

confidence: 99%

Enrichment of gas storage in clathrate hydrates by optimizing the molar liquid water–gas ratio

Kiran

Prasad

2022

RSC Adv.

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A bench-scale flow loop study on hydrate deposition under multiphase flow conditions

Cited by 22 publications

References 27 publications

Investigation on Hydrate Growth at the Oil–Water Interface: In the Presence of Wax and Kinetic Hydrate Inhibitor

Investigation on Hydrate Growth at the Oil–Water Interface: In the Presence of Wax and Kinetic Hydrate Inhibitor

Reduction Clathrate Hydrates Growth Rates and Adhesion Forces on Surfaces of Inorganic or Polymer Coatings

Enrichment of gas storage in clathrate hydrates by optimizing the molar liquid water–gas ratio

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