Hydrate plug prevention by anti-agglomeration

Huo, Zhongxin; Freer, Erik M.; Lamar, M; Sannigrahi, Biswajit; Knauss, Dan; Sloan, E. Dendy

doi:10.1016/s0009-2509(01)00188-9

Cited by 219 publications

(163 citation statements)

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“…In general, thermodynamic inhibitors or low dosage hydrate inhibitors, such as kinetic inhibitors (KIs) and anti-agglomerants (AAs) [1][2][3][4], are injected to inhibit or control the formation of hydrates. On the other hand, hydrate slurry might become an alternative approach for oil and gas transportation, as large amounts of natural gas can be stored in the form of hydrates.…”

Section: Introductionmentioning

confidence: 99%

Hydrate Formation/Dissociation in (Natural Gas + Water + Diesel Oil) Emulsion Systems

et al. 2013

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Abstract:Hydrate formation/dissociation of natural gas in (diesel oil + water) emulsion systems containing 3 wt% anti-agglomerant were performed for five water cuts: 5, 10, 15, 20, and 25 vol%. The natural gas solubilities in the emulsion systems were also examined. The experimental results showed that the solubility of natural gas in emulsion systems increases almost linearly with the increase of pressure, and decreases with the increase of water cut. There exists an initial slow hydrate formation stage for systems with lower water cut, while rapid hydrate formation takes place and the process of the gas-liquid dissolution equilibrium at higher water cut does not appear in the pressure curve. The gas consumption amount due to hydrate formation at high water cut is significantly higher than that at low water cut. Fractional distillation for natural gas components also exists during the hydrate formation process. The experiments on hydrate dissociation showed that the dissociation rate and the amount of dissociated gas increase with the increase of water cut. The variations of temperature in the process of natural gas hydrate formation and dissociation in emulsion systems were also examined.

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Section: Introductionmentioning

confidence: 99%

Hydrate Formation/Dissociation in (Natural Gas + Water + Diesel Oil) Emulsion Systems

et al. 2013

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“…Sloan and coworkers explored the performance of Span 20, Span 40, Span 60 and Span 80 in contrast to analogous synthetic surfactants in order to monitor the ability to suspend 65 hydrate particles. 128 As a measure of performance, high pressure apparatus was used with a change in the stirrer motor current being indicative of plug formation. 128 In the case of antiagglomerants, simply measuring the gas consumption does not give a good representation of the inhibitor performance, as 70 hydrates are allowed to form and thus gas consumption will increase, but this does not necessarily mean that a plug has resulted.…”

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confidence: 99%

The chemistry of low dosage clathrate hydrate inhibitors

2013

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The full-text may be used and/or reproduced, and given to third parties in any format or medium, without prior permission or charge, for personal research or study, educational, or not-for-prot purposes provided that:• a full bibliographic reference is made to the original source • a link is made to the metadata record in DRO • the full-text is not changed in any way The full-text must not be sold in any format or medium without the formal permission of the copyright holders.Please consult the full DRO policy for further details. This review aims to introduce the chemistry of low dosage inhibitors of clathrate hydrate formation 5 within the context of their role in the oil and gas industry. The review covers both kinetic hydrate inhibitors and anti-agglomerants from the point of view of structure-function relationships, focussing on recent refinements in mechanistic understanding and chemical design, and the consequently evolving and increasingly fine-tuned properties of these fascinating compounds. Clathrate hydrates 10Clathrate hydrates are crystalline, non-stoichiometric host-guest compounds comprising a hydrogen bonded water framework, into which small molecular guest species such as methane are included within cavities formed by the water cages. Because there are no strong directional interactions between guest and host the 15 guests are free to vibrate and rotate but possess limited translational motion. 1 Typically common clathrate hydrates comprise 85 mol% water and 15 mol% guest(s) when all of the cavities are occupied.2 These materials form when the components are subjected to ambient temperatures (generally less 20 than 300 K) and moderate pressures (>0.6 MPa); conditions frequently found in oil and gas pipelines. 3 The initial reporting of gas hydrates is accredited to Sir Humphrey Davy in 1811, who focussed upon the crystallisation 25 of a cold aqueous solution of chlorine (known as oxymuriatic gas at the time). 4 In 1934 a pivotal report by Hammerschmidt acted as a catalyst for stimulating research in this area, by confirming that clathrate hydrates are responsible for the plugging of gas and oil pipelines and thereby dramatically increasing industrial 30 investment and research on the topic. 5 Today clathrate hydrates pose a major problem to the oil and gas industry with pipeline blockage causing many safety concerns in addition to requiring the shutdown of the pipeline for a time 35 whilst the plug is removed. This shutdown period results in reduced field site performance and may cause significant financial loss. Avoidance of pipeline shutdown is a priority to many oil and gas companies, and as such considerable investment is being made into research into clathrate hydrate inhibition to 40 circumvent such potentially catastrophic effects. Problems associated with gas hydrate formation reached the headlines in 2010 due to their destructive effects during BP's efforts to contain the oil spillage after the Deepwater Horizon blowout, thereby illustrating the importance of research in this area. While...

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“…Such surfactant additives, in the first place, have been used and investigated to prevent hydrate plug, namely hydrate inhibitor, in pipelines under certain pressure and temperature conditions because hydrate is a problem to the oil and gas industry (Huo et al, 2001). Effects of surfactant such as SDS on gas hydrate formation have been widely investigated by many researchers, and the author has also investigated the ability of SDS to accelerate hydrate formation (Tajima et al, 2010b).…”

Section: Chemical Conditionsmentioning

confidence: 99%

Gas Hydrate Formation Kinetics in Semi-Batch Flow Reactor Equipped with Static Mixer

Tajima¹

2011

Hydrodynamics - Optimizing Methods and Tools

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Hydrate plug prevention by anti-agglomeration

Cited by 219 publications

References 5 publications

Hydrate Formation/Dissociation in (Natural Gas + Water + Diesel Oil) Emulsion Systems

Hydrate Formation/Dissociation in (Natural Gas + Water + Diesel Oil) Emulsion Systems

The chemistry of low dosage clathrate hydrate inhibitors

Gas Hydrate Formation Kinetics in Semi-Batch Flow Reactor Equipped with Static Mixer

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