Research on evaluation method of wellbore hydrate blocking degree during deepwater gas well testing

Liu, Wenyuan; Hu, Jinqiu; Li, Xiangfang; Sun, Fengrui; Sun, Zheng; Yu, Zhou

doi:10.1016/j.jngse.2018.08.027

Cited by 36 publications

(10 citation statements)

References 30 publications

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“…Liu and co-workers 293,294 proposed an evaluation model for the degree of wellbore hydrate plugging, which could calculate the amount and location of hydrate formation and the degree of blockage characterized by the thickness of the sedimentary layer in the wellbore. Sensitivity analysis of natural gas production, inhibitor concentration, water content, and shutin time in gas wells was carried out to facilitate hydrate prevention and provide control measures.…”

Section: Hydrate Particle Deposition Researchmentioning

confidence: 99%

“…Sensitivity analysis of natural gas production, inhibitor concentration, water content, and shutin time in gas wells was carried out to facilitate hydrate prevention and provide control measures. 293,295,296 The method was subsequently applied to long-distance, natural gas transmission pipelines to evaluate the risk of hydrate blockage and conduct a sensitivity analysis of the temperature, flow, and dew point of natural gas. 297−300 In addition, Wei et al 301 established a set of prediction methods for hydrate formation and decomposition in wellbores.…”

Section: Hydrate Particle Deposition Researchmentioning

confidence: 99%

“…Liu and co-workers , proposed an evaluation model for the degree of wellbore hydrate plugging, which could calculate the amount and location of hydrate formation and the degree of blockage characterized by the thickness of the sedimentary layer in the wellbore. Sensitivity analysis of natural gas production, inhibitor concentration, water content, and shut-in time in gas wells was carried out to facilitate hydrate prevention and provide control measures. ,, The method was subsequently applied to long-distance, natural gas transmission pipelines to evaluate the risk of hydrate blockage and conduct a sensitivity analysis of the temperature, flow, and dew point of natural gas. − In addition, Wei et al established a set of prediction methods for hydrate formation and decomposition in wellbores.…”

Section: Hydrate Slurry Flow Behavior Research In Chinamentioning

confidence: 99%

See 2 more Smart Citations

Status of Natural Gas Hydrate Flow Assurance Research in China: A Review

Shi¹,

Song²,

Duan³

et al. 2021

Energy Fuels

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Natural gas hydrates (NGH) are prone to causing pipeline blockage in flow assurance, attracting considerable attention in the petroleum industry. This work reviews the significant progress in hydrate flow assurance research in China. Gas hydrate structures are briefly introduced to provide a basic understanding, while the application and development of hydrate management strategies in China are summarized. Subsequently, the development and improvement of hydrate phase equilibrium models are presented, which have been widely applied to the practical challenges of flow assurance. Moreover, kinetics research involving hydrate nucleation, growth, and decomposition are summarized, including nucleation mechanisms, induction time, memory effect, hydrate growth at different interfaces, hydrate growth at a microscopic level, and hydrate decomposition under different systems. The current research status of hydrate slurry flow is also analyzed in detail, covering the viscosity and flow resistance of hydrate slurry and the mechanisms of hydrate particle aggregation, deposition, and blockage. In addition, even though the numerical models of hydrate slurry multiphase flow have been sorted out, the accurate quantitative calculations and risk assessments are still in the initial stage, presenting significant room for improvement. Although substantial research progress has been made in China regarding gas hydrate flow assurance, considerable effort should be devoted to further understanding the intrinsic mechanism work to improve the applicability of various models. This review discusses the current developments, existing problems, and future prospects in the various basic hydrate flow assurance fields in China. It aims to provide readers with an overview of hydrate flow assurance research in China, hoping to provide a reference for developing this field.

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Section: Hydrate Particle Deposition Researchmentioning

confidence: 99%

Section: Hydrate Particle Deposition Researchmentioning

confidence: 99%

Section: Hydrate Slurry Flow Behavior Research In Chinamentioning

confidence: 99%

See 1 more Smart Citation

Status of Natural Gas Hydrate Flow Assurance Research in China: A Review

Shi¹,

Song²,

Duan³

et al. 2021

Energy Fuels

View full text Add to dashboard Cite

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“…In Eqn (3), the shear stress in the pipelines is mentioned, which can be calculated by the classical hydrodynamics method 60,61 as:…”

Section: Appendix B Heat Loss Ratementioning

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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“…Then, Wang et al proposed a prediction method of gas hydrate formation area in deepwater gas wells by combining the wellbore temperature field equation and hydrate phase equilibrium equation, and analyzed the sensitivity of test parameters to hydrate formation region, including gas production, natural gas composition, geothermal gradient, water depth, inhibitor content, and throttling effect. To solve the problem of hydrate blockage during deepwater gas well testing, Liu and Wang − established a prediction model describing hydrate formation, deposition, and blockage behavior in wellbore, respectively. Later, Liu et al also predicted the hydrate risk in deepwater submarine pipeline and analyzed the hydrate blockage risk under different pipeline transportation conditions, which provided a theoretical guarantee for the safe transportation of natural gas in a submarine pipeline.…”

Section: Introductionmentioning

confidence: 99%

Prediction of Hydrate Formation Risk Based on Temperature–Pressure Field Coupling in the Deepwater Gas Well Cleanup Process

Liu

Sun

et al. 2021

Energy Fuels

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Deepwater oil and gas exploitation has become an important field in the petroleum industry development. However, there are still no mature methods for hydrate prevention in the deepwater wells cleanup stage, and the excessive use of inhibitors has severely increased the construction costs. In our study, based on the hydrate phase equilibrium equation, the common influencing factors of hydrate formation were analyzed. Then, combined with the hydrate phase equilibrium equation and heat transfer equation, the temperature–pressure coupling model of the wellbore field during the deepwater gas wells cleanup process is established. Then, taking a deepwater gas well as an example, the temperature distribution and hydrate formation area distribution characteristics along the wellbore are analyzed. The study shows the following: the increase of heavy gas hydrocarbons and hydrogen sulfide content, the decrease of formation water mineralization degree, and the decrease of condensate oil content will promote hydrate formation; alcohol is a better choice as a hydrate inhibitor for deepwater operation; properly increasing the gas–liquid flow rate and increasing the ratio of liquid to gas, the use of high salinity completion liquid will help to reduce the risk of hydrate formation in the process of well cleanup stage. This work can help to reduce the cost of operations while ensuring the security of the deepwater gas testing.

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Research on evaluation method of wellbore hydrate blocking degree during deepwater gas well testing

Cited by 36 publications

References 30 publications

Status of Natural Gas Hydrate Flow Assurance Research in China: A Review

Status of Natural Gas Hydrate Flow Assurance Research in China: A Review

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

Prediction of Hydrate Formation Risk Based on Temperature–Pressure Field Coupling in the Deepwater Gas Well Cleanup Process

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Research on evaluation method of wellbore hydrate blocking degree during deepwater gas well testing

Cited by 36 publications

References 30 publications

Status of Natural Gas Hydrate Flow Assurance Research in China: A Review

Status of Natural Gas Hydrate Flow Assurance Research in China: A Review

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

Prediction of Hydrate Formation Risk Based on Temperature–Pressure Field Coupling in the Deepwater Gas Well Cleanup Process

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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