Effect of monoethylene glycol and kinetic hydrate inhibitor on hydrate blockage formation during cold restart operation

Sohn, Young Hoon; Seo, Yutaek

doi:10.1016/j.ces.2017.05.010

Cited by 28 publications

(14 citation statements)

References 25 publications

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“…A new solution is hydrate risk control strategy, which allows hydrate formation in oil and gas pipelines with the injection of low dose hydrate inhibitors, such as antiagglomerants (AAs) [12][13][14] and kinetic inhibitors (KHIs). 15,16 This new strategy has attracted the attention of academia and industry. Therefore, it is critical to explore the hydrate formation and ow characteristics of high pressure ow systems for the implementation of hydrate risk control strategy.…”

Section: Introductionmentioning

confidence: 99%

Experimental study of growth kinetics of CO₂ hydrates and multiphase flow properties of slurries in high pressure flow systems

Zuo

Liu

et al. 2019

RSC Adv.

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Section: Introductionmentioning

confidence: 99%

Experimental study of growth kinetics of CO₂ hydrates and multiphase flow properties of slurries in high pressure flow systems

Zuo

Liu

et al. 2019

RSC Adv.

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“…The subcooling to which PVP delays gas hydrate formation is fairly low compared to the best KHI polymers on the market today such as those based on N-vinylcaprolactam (VCap), N-isopropylmethacrylamide, or poly(ester amide)s. However, PVP has a high cloud and deposition point, compared to some KHI polymers, even in high salinity waters and is therefore used in some KHI formulations. 19 The cloud point temperature (T Cl ) is important for the production and transport of oil and gas as the production fluids are often very hot. However, these will cool down if there is a shut-in of the flow lines or as the transport lines stretch over longer distances, for example across the seabed offshore.…”

Section: ■ Introductionmentioning

confidence: 99%

First Study of Poly(3-methylene-2-pyrrolidone) as a Kinetic Hydrate Inhibitor

et al. 2017

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Formation of gas hydrates is a problem in the petroleum industry where the gas hydrates can cause blockage of the flowlines. Kinetic hydrate inhibitors (KHIs) are water-soluble polymers, sometimes used in combination synergistically or with non-polymeric synergists, that are used to prevent gas hydrate blockages. They have been used in the field successfully since 1995. In this paper, we present the first KHI results for the polymer, poly(3-methylene-Page 1 of 21 ACS Paragon Plus Environment Energy & Fuels 2-pyrrolidone) (P(3M2P)), which is structurally similar to poly(N-vinylpyrrolidone) (PVP), one of the first KHIs to be discovered. 3M2P polymers with different molecular weights (5500 and 2500 g/mole) and at different concentrations (2500, 5000 and 7500 ppm) were investigated for their KHI performance on SII hydrates in high-pressure rocking cells. We also investigated the synergistic effect of P(3M2P) with n-butyl glycol ether (BGE), a known synergist for some KHI polymers. At the lower concentrations, P(3M2P) gives a similar performance to PVP (M w = 8000-9000 g/mole). However, PVP outperforms both samples of P(3M2P) at 7500 ppm, with and without BGE. We suggest that the reasons for the performance level of P(3M2P) are related to greater resonance stabilization of the amide group in P(3M2P) compared to PVP. Also, the pyrrolidone ring of the PVP repeat unit has a larger hydrophobic sequence of three methylene units compared to the two methylene units in the pyrrolidone ring of P(3M2P). This relates well to previous studies where larger hydrophobic groups are preferable in KHI polymers as long as they are water-soluble at hydrate-forming temperatures.

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“…When mixing KHIs with MEG, the observed synergistic effect with reduced MEG dosage and maintained inhibition power could be seen as a joint effort from both sides. As a typical THI, MEG would lower the fugacity coefficient of water and change the hydrate phase boundary via hydrogen bonding with water . In both systems, we observed that the inhibitive effect of mixed KHI–MEG formulations was increased with the increased concentration of MEG when the amount of KHI remained constant.…”

Section: Resultsmentioning

confidence: 76%

“…As a typical THI, MEG would lower the fugacity coefficient of water 29 and change the hydrate phase boundary via hydrogen bonding with water. 48 In both systems, we observed that the inhibitive effect of mixed KHI−MEG formulations was increased with the increased concentration of MEG when the amount of KHI remained constant. Therefore, the synergistic effect from the MEG side mostly related to the shifted equilibrium boundary was undeniable.…”

Section: Meg When Used Alonementioning

confidence: 77%

Experimental Evaluation of Kinetic Hydrate Inhibitors and Mixed Formulations with Monoethylene Glycol for Hydrate Prevention in Pure Water and Brine–Oil Systems

Yang¹,

Zhao³

et al. 2020

Energy Fuels

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Thermodynamic hydrate inhibitors (THIs) and kinetic hydrate inhibitors (KHIs) are widely studied and used in the oil & gas industry for hydrate prevention. In this experimental study, we applied an isothermal procedure and tested four different KHIspoly(vinylpyrrolidone) (PVP), Inhibex 501, Luvicap EG, and VC-713KHI−KHI mixtures, and KHI−MEG (monoethylene glycol) mixtures to evaluate their inhibitive performance on structure II methane−propane hydrate formation in stirred reactors. Two liquid systems (pure water and brine−oil−water), two cooling rates (6 and 4.5 K/h), and two subcooling levels (12.8 and 7.8 K) were examined. The results showed that, with single KHI dosing, Inhibex 501 has the best inhibitive effect in the pure water system, while Luvicap EG and VC-713 performed better in the brine−oil−water system. The performance of KHI−KHI mixtures was found to be similar to that of the single KHI composition of lower molecular weight. In experiments with KHI−MEG mixtures, MEG contributed to the combined inhibitive effect mostly for its thermodynamic effect on the system equilibrium; on the other hand, low concentration KHIs in the mixed formulations showed a synergistic effect that could not only reduce the dosage of MEG but also maintain the overall inhibitive effect on hydrate formation. The addition of NaCl and mineral oil may also prevent hydrate growth owing to water−salt ion interactions and interfacial barrier effects of the mineral oil.

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Effect of monoethylene glycol and kinetic hydrate inhibitor on hydrate blockage formation during cold restart operation

Cited by 28 publications

References 25 publications

Experimental study of growth kinetics of CO₂ hydrates and multiphase flow properties of slurries in high pressure flow systems

Experimental study of growth kinetics of CO₂ hydrates and multiphase flow properties of slurries in high pressure flow systems

First Study of Poly(3-methylene-2-pyrrolidone) as a Kinetic Hydrate Inhibitor

Experimental Evaluation of Kinetic Hydrate Inhibitors and Mixed Formulations with Monoethylene Glycol for Hydrate Prevention in Pure Water and Brine–Oil Systems

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Effect of monoethylene glycol and kinetic hydrate inhibitor on hydrate blockage formation during cold restart operation

Cited by 28 publications

References 25 publications

Experimental study of growth kinetics of CO2 hydrates and multiphase flow properties of slurries in high pressure flow systems

Experimental study of growth kinetics of CO2 hydrates and multiphase flow properties of slurries in high pressure flow systems

First Study of Poly(3-methylene-2-pyrrolidone) as a Kinetic Hydrate Inhibitor

Experimental Evaluation of Kinetic Hydrate Inhibitors and Mixed Formulations with Monoethylene Glycol for Hydrate Prevention in Pure Water and Brine–Oil Systems

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Experimental study of growth kinetics of CO₂ hydrates and multiphase flow properties of slurries in high pressure flow systems

Experimental study of growth kinetics of CO₂ hydrates and multiphase flow properties of slurries in high pressure flow systems