Investigation of rheological properties of methane hydrate slurry with carboxmethylcellulose

Fu, Weiqi; Wang, Zhiyuan; Zhang, Jianbo; Cao, Yueying; Sun, Baojiang

doi:10.1016/j.petrol.2019.106504

Cited by 64 publications

(32 citation statements)

References 40 publications

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“…Up to date, research focused on oil-water two-phase flow performance can be categorized by the following three types, encompassing theoretical mathematical model, numerical simulation, and laboratory experiments. Thanks to the rapid advances in computational capacity in recent years, the numerical simulation approach has developed at an impressive speed [5,6]. Several physics fully-coupled commercial numerical simulator have been massively utilized for analysis, like CFD and FLUENT [7].…”

Section: Introductionmentioning

confidence: 99%

A Unified Model of Oil/Water Two-Phase Flow through the Complex Pipeline

2021

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Oil-water two-phase flow through the complex pipeline, consisting of varying pipes and fittings in series or parallel, is commonly encountered in the petroleum industry. However, the majority of the current study is mainly limited to single constant-radius pipe. In this paper, a unified model of oil-water two-phase flow in the complex pipeline is developed based on the combination of pipe serial-parallel theory, flow pattern transformation criterion, two-fluid model, and homogenous model. A case is present to verify the unified model and compare with CFD results. The results show that the proposed unified model can achieve excellent performance in predicting both the flow distributions and pressure drops of oil-water two-phase flow in the complex pipeline. Compared with CFD results for water volumetric fractions ranging from 0% to 100%, the highest absolute percentage error of the proposed model is 14.4% and the average is 9.8%.

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Section: Introductionmentioning

confidence: 99%

A Unified Model of Oil/Water Two-Phase Flow through the Complex Pipeline

2021

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“…[3][4][5][6] MEG is also used to prevent the formation of gas hydrates during the offshore oil and gas deep water drilling. 4,[7][8][9] Significant volumes of MEG are used annually in different gas fields to inhibit hydrate formation in the pipelines. After delivering the gas safely to the processing plant, these volumes require an effective separation and disposal process.…”

Section: Introductionmentioning

confidence: 99%

“…Monoethylene glycol (MEG) is used in different gas fields as the primary HI due to its high efficiency in preventing hydrate formation compared to other chemicals 3-6 . MEG is also used to prevent the formation of gas hydrates during the offshore oil and gas deep water drilling 4,7-9 . Significant volumes of MEG are used annually in different gas fields to inhibit hydrate formation in the pipelines.…”

Section: Introductionmentioning

confidence: 99%

A systematic approach for design and simulation of monoethylene glycol (MEG) recovery in oil and gas industry

et al. 2020

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Monoethylene glycol (MEG) is a widely used hydrate inhibitor in the oil and gas industry to reduce the risk of hydrate formation in pipelines that could cause a blockage. For flow assurance and hydrate inhibition purposes, large volumes of MEG are required to control the hydrate formation conditions in pipelines. Disposal of rich MEG after separation has considerable costs and poses significant environmental concerns. Therefore, the development of an effective process for MEG recovery has been gaining importance. The current study presents a systematic approach to develop, simulate, and optimize MEG recovery using Aspen Plus and ELEC-NRTL thermodynamic package. Two distinct MEG recovery process (MEG-R-P) designs, namely, the vacuum (design I) and atmospheric (design II) distillation, were tested. Both designs have demonstrated exceptional performance in recovering MEG from salts and water and producing lean MEG at a purity of 90 wt%. Design I operating at vacuum conditions outweighs design II in terms of MEG purity and energy requirements. The addition of MEG-R-P has the advantage of recovering and reusing significant amounts of MEG and removing the burden on the environment.

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“…However, the formation of CO 2 hydrates becomes a major problem, affecting the safety of CO 2 pipeline transportation . The formation and deposition of hydrate shrinks the passageway of the airflow and reduces the transportation efficiency, and the huge volume of hydrate causes pipeline blockage and rupture accidents . Moreover, compared with natural gas, which is mainly composed of methane, CO 2 can form solid hydrates at relatively lower pressures and higher temperatures.…”

Section: Introductionmentioning

confidence: 99%

“…[14][15][16][17] The formation and deposition of hydrate shrinks the passageway of the airflow and reduces the transportation efficiency, and the huge volume of hydrate causes pipeline blockage and rupture accidents. [18][19][20][21][22][23][24][25][26][27][28][29][30][31][32] Moreover, compared with natural gas, which is mainly composed of methane, CO 2 can form solid hydrates at relatively lower pressures and higher temperatures. It seems that the hydrate risk in CO 2 pipelines is significantly more serious than that in natural gas pipelines.…”

Section: Introductionmentioning

confidence: 99%

A numerical study on the non‐isothermal flow characteristics and hydrate risk of CO₂ in buried transmission pipelines under the gas‐phase transportation mode

Liu

Sun

et al. 2019

Greenhouse Gases

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With the development and progress of carbon dioxide (CO2) capture and storage technology, the study of the flow assurance of CO2 in transmission pipelines needs to be further deepened. In this study, aiming at the gas‐phase transportation mode of CO2, first, a new prediction model of temperature, pressure as well as hydrate formation risk in buried CO2 transmission pipelines is established. Second, the model solving methods of differential discretization and piecewise iteration are introduced in detail. Third, model validation and sensitivity analysis of typical transmission parameters are performed. The results show that: (a) there is good agreement between the model prediction results and software simulation results. (b) The subcooling and the length of the hydrate formation region increase with the increase in the transmission rate. Appropriate increase in the CO2 transmission rate can reduce the risk of hydrate formation in CO2 transmission pipelines. (c) The subcooling and the length of the hydrate formation region decrease as the transmission temperature increases. In order to prevent hydrate risk in the CO2 transmission process, low transmission temperatures should be avoided. (d) The subcooling and the length of the hydrate‐formation area increase first and then decrease as the transmission pressure increases. Appropriate increase in CO2 transmission pressure is conducive to avoiding hydrate formation risk. This study provides basic theoretical guidance for optimizing transmission parameters and risk assessment of hydrate formation in CO2 transmission pipelines. © 2019 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Investigation of rheological properties of methane hydrate slurry with carboxmethylcellulose

Cited by 64 publications

References 40 publications

A Unified Model of Oil/Water Two-Phase Flow through the Complex Pipeline

A Unified Model of Oil/Water Two-Phase Flow through the Complex Pipeline

A systematic approach for design and simulation of monoethylene glycol (MEG) recovery in oil and gas industry

A numerical study on the non‐isothermal flow characteristics and hydrate risk of CO₂ in buried transmission pipelines under the gas‐phase transportation mode

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Investigation of rheological properties of methane hydrate slurry with carboxmethylcellulose

Cited by 64 publications

References 40 publications

A Unified Model of Oil/Water Two-Phase Flow through the Complex Pipeline

A Unified Model of Oil/Water Two-Phase Flow through the Complex Pipeline

A systematic approach for design and simulation of monoethylene glycol (MEG) recovery in oil and gas industry

A numerical study on the non‐isothermal flow characteristics and hydrate risk of CO2 in buried transmission pipelines under the gas‐phase transportation mode

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A numerical study on the non‐isothermal flow characteristics and hydrate risk of CO₂ in buried transmission pipelines under the gas‐phase transportation mode