A Review of Strategies for Solving Gas-Hydrate Problems in Subsea Pipelines

Mokhatab, Saeid; Wilkens, Robert; Leontaritis, Kosta J.

doi:10.1080/009083190933988

Cited by 120 publications

(96 citation statements)

References 5 publications

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“…Currently, four techniques are used to mitigate the gas hydrate formation: (i) system heating, (ii) depressurization, (iii) water removal, and (iv) inhibition. 6,29 Under many circumstances, the use of inhibitors for gas hydrate inhibition is the only feasible choice.…”

Section: Introductionmentioning

confidence: 99%

Gas Hydrate Inhibition: A Review of the Role of Ionic Liquids

Tariq

Rooney

Othman

et al. 2014

Ind. Eng. Chem. Res.

184

117

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Ionic liquids (ILs) are popular designer green chemicals with great potential for use in diverse energy-related applications. Apart from the well-known low vapor pressure, the physical properties of ILs, such as hydrogen-bond-forming capacity, physical state, shape, and size, can be fine-tuned for specific applications. Natural gas hydrates are easily formed in gas pipelines and pose potential problems to the oil and natural gas industry, particularly during deep-sea exploration and production. This review summarizes the recent advances in IL research as dual-function gas hydrate inhibitors. Almost all of the available thermodynamic and kinetic inhibition data in the presence of ILs have been systematically reviewed to evaluate the efficiency of ILs in gas hydrate inhibition, compared to other conventional thermodynamic and kinetic gas hydrate inhibitors. The principles of natural gas hydrate formation, types of gas hydrates and their inhibitors, apparatuses and methods used, reported experimental data, and theoretical methods are thoroughly and critically discussed. The studies in this field will facilitate the design of advanced ILs for energy savings through the development of efficient low-dosage gas hydrate inhibitors.

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Section: Introductionmentioning

confidence: 99%

Gas Hydrate Inhibition: A Review of the Role of Ionic Liquids

Tariq

Rooney

Othman

et al. 2014

Ind. Eng. Chem. Res.

184

117

View full text Add to dashboard Cite

show abstract

“…However, during the course of the experiment, it was found that TBAB hydrate is highly prone to coalescence and deposit, and can cause blockage of hydrate separation equipment extremely easily. The addition of anti-agglomerant to the hydrate system to prevent hydrate agglomeration is considered to be an effective way to improve the hydrate slurry flow [10,11]. The anti-agglomerant is usually a kind of surfactant that does not affect the nucleation and growth of hydrates but prevents hydrate particle agglomeration [12].…”

Section: Introductionmentioning

confidence: 99%

Anti-Agglomerator of Tetra-n-Butyl Ammonium Bromide Hydrate and Its Effect on Hydrate-Based CO2 Capture

Chen

et al. 2018

Energies

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Tetra-n-butyl ammonium bromide (TBAB) was widely used in the research fields of cold storage and CO 2 hydrate separation due to its high phase change latent heat and thermodynamic promotion for hydrate formation. Agglomeration always occurred in the process of TBAB hydrate generation, which led to the blockage in the pipeline and the separation apparatus. In this work, we screened out a kind of anti-agglomerant that can effectively solve the problem of TBAB hydrate agglomeration. The anti-agglomerant (AA) is composed of 90% cocamidopropyl dimethylamine and 10% glycerol, which can keep TBAB hydrate of 19.3-29.0 wt. % in a stable state of slurry over 72 h. The microscopic observation of the morphology of the TBAB hydrate particles showed that the addition of AA can greatly reduce the size of the TBAB hydrate particles. CO 2 gas separation experiments found that the addition of AA led to great improvement on gas storage capacity, CO 2 split fraction and separation factor, due to the increasing of contact area between gas phase and hydrate particles. The CO 2 split fraction and separation factor with AA addition reached up to 70.3% and 42.8%, respectively.

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“…The chemical method consists of injecting chemicals in the pipeline. These chemicals fall into three classes: thermodynamic hydrate inhibitors (THIs), kinetic hydrate inhibitors (KHIs), and anti-agglomerants (AAs) (Mokhatab et al, 2007). Unlike the THIs, the KHIs (generally polymers) do not alter the thermodynamics of hydrate formation, but instead modifies the kinetics of hydrate formation by preventing nucleation or by hindering or slowing down the crystal growth (Sloan, 1997).…”

Section: Introductionmentioning

confidence: 99%

The Prediction of Hydrate Formation Rate in the Presence of Inhibitors

Shadravanan

Schaffie

Ranjbar

2014

Energy Sources, Part A: Recovery, Utilization, and Environmenta

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The main objective of this study was to present a novel approach to access more accurate hydrate formation rate predicting models based on the combination of flow-loop experimental data with learning power of artificial neural networks. Therefore, more than 2,300 data of C 1 , C 3 , i-C 4 , and CO 2 hydrate formation rate in the presence of two kinetic inhibitors (PVP and L-Tyrosine) and two inhibitor intensifying additives (PPO and PEO) was used. It was found that such models can be used as powerful tools, with total errors less than 2% for the developed models, in predicting hydrate formation rate in these cases.

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A Review of Strategies for Solving Gas-Hydrate Problems in Subsea Pipelines

Cited by 120 publications

References 5 publications

Gas Hydrate Inhibition: A Review of the Role of Ionic Liquids

Gas Hydrate Inhibition: A Review of the Role of Ionic Liquids

Anti-Agglomerator of Tetra-n-Butyl Ammonium Bromide Hydrate and Its Effect on Hydrate-Based CO2 Capture

The Prediction of Hydrate Formation Rate in the Presence of Inhibitors

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