Generation of methane gas hydrate equilibrium curve for the thermodynamic gas hydrate inhibitor propylene glycol

Deka, Barasha; Barifcani, Ahmed; Helal, Ammar Al; Badi, Dana; Mahto, Vikas; Vuthaluru, Hari

doi:10.1016/j.petrol.2020.108312

Cited by 14 publications

(3 citation statements)

References 89 publications

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“…The hydrate formation temperature was first estimated using Aspen Hysys software. The temperature was then reduced close to the software value then, by more gradual cooling, in steps of 0.5 °C per 20 min (1.5 °C per h) until hydrate formation was observed, − while others were used at a rate of 2 °C per hour. , The most important aspect of hydrate testing was to ensure that sufficient time was taken to attain temperature stability, repeatability, and equilibrium.…”

Section: Materials Laboratory Equipment and Research Methodologymentioning

confidence: 99%

Influence of Injecting Some Chemicals on MEG Inhibition Performance for Less Recycled MEG

et al. 2023

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Monoethylene glycol (MEG) is often injected into submarine transportation pipelines, from offshore oil and gas platforms, to suppress hydrate formation. MEG can be recovered, for recycling, through a MEG regeneration plant, onshore. The costs related to hydrate inhibition operations are significant; thus, introducing new methods of reducing the volumes of MEG required by the system potentially will provide significant economic benefits for the operation. The objectives of this study were to evaluate the influence of ammonium hydroxide (NH 4 OH), sodium hydroxide (NaOH), potassium hydroxide (KOH), and methyl diethanolamine (MDEA) on inhibition performance when separately combined with a MEG 20 wt % solution in a methane gas system. The pH levels applied were 10.

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Section: Materials Laboratory Equipment and Research Methodologymentioning

confidence: 99%

Influence of Injecting Some Chemicals on MEG Inhibition Performance for Less Recycled MEG

et al. 2023

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“…3 However, the high-pressure and low-temperature conditions of subsea pipelines in deepwater− oil and gas fields are suitable for natural gas hydrate formation, which would lead to pipeline blockage in the absence of an appropriate measure. 4−6 To prevent hydrate blockage in multiphase transportation flowlines, natural gas hydrate inhibitors are commonly injected in oil and gas fields, 7−10 including thermodynamic hydrate inhibitors (THIs), 11 kinetic hydrate inhibitors (KHIs), 12 and antiagglomerants (AAs). 13 THIs mainly comprise alcohols, such as methanol and ethylene glycol, which prevent hydrate formation by altering the thermodynamic phase equilibrium.…”

Section: Introductionmentioning

confidence: 99%

Hydrate Antiagglomerants Performance by Characterizing Particle Size Distribution In Situ Flow Condition

Yao,

Ding,

Guo

et al. 2024

Energy Fuels

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Hydrate slurry technology is recognized as one of the suitable methods to solve hydrate blockage problems in deepwater field exploitation and development. The key to applying this technology is to inject high-performance hydrate antiagglomerants (AAs) to prevent hydrate particle agglomeration and ensure fluid flow under good flowable conditions. It is better to evaluate the performance of AAs by field tests; however, effective measurements in the laboratory should be carried out before their industrial application. In this work, the performance of AAs was evaluated by particle size distribution data measured in situ by focused beam reflectance measurement (FBRM) from a high-pressure hydrate slurry flow loop under flow conditions, including unweighted mean particle chord length, square weighted mean particle chord length, and count-based chord length distribution (CLD). Meanwhile, a macroscopic index named effective antiagglomerant time was proposed to combine microscopic particle data to evaluate the performance of AAs. The effects of water content, water bath temperature, and AA dosage on the performance of AAs were studied. The results showed that the unweighted mean particle chord length showing the fine particle information changed slightly according to different experimental conditions, while the squared weighted mean particle chord length displaying the large particle status increased with an increase in the water content as well as a decrease in water bath temperature and AAs dosage, resulting in an upward shifting of count-based CLD, a reduced effective antiagglomeration time, and a weakened performance of AAs. The performance mechanisms of AAs affected by water content, water bath temperature, and AA dosage were addressed. These findings provided a valuable reference for promoting the application of hydrate slurry technology to ensure the safety of multiphase flow pipelines by using AAs under suitable conditions with effective and high performance.

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“…Thermodynamic hydrate inhibitors (THIs) and low-dosage hydrate inhibitors (LDHIs) are the main classes of effective inhibitors [12][13][14]. THIs, such as glycol compounds, methanol, and some inorganic salts at high concentrations (<20%), mainly affect the chemical activity of water and change the equilibrium phase of hydrate formation [15,16]. The exacerbation of corrosion, impact on hydrocarbon quality, storage tank requirement and regeneration equipment, flammability, and toxicity of methanol are the technical challenges of using THIs [4,17].…”

Section: Introductionmentioning

confidence: 99%

Simultaneous inhibition of natural gas hydrate formation and CO2/H2S corrosion for flow assurance inside the oil and gas pipelines

Farhadian

Zhao

Naeiji

et al. 2023

Energy

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Generation of methane gas hydrate equilibrium curve for the thermodynamic gas hydrate inhibitor propylene glycol

Cited by 14 publications

References 89 publications

Influence of Injecting Some Chemicals on MEG Inhibition Performance for Less Recycled MEG

Influence of Injecting Some Chemicals on MEG Inhibition Performance for Less Recycled MEG

Hydrate Antiagglomerants Performance by Characterizing Particle Size Distribution In Situ Flow Condition

Simultaneous inhibition of natural gas hydrate formation and CO2/H2S corrosion for flow assurance inside the oil and gas pipelines

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