A model for estimating flow assurance of hydrate slurry in pipelines

Wang, Wuchang; Fan, Shuanshi; Liang, Deqing; Li, Yuxing

doi:10.1016/s1003-9953(09)60094-3

Cited by 20 publications

(7 citation statements)

References 10 publications

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“…The global reserves of natural gas in hydrate deposits are estimated to be about 20,000 trillion m 3 ; therefore, it is considered to be a potential energy source . In addition, hydrate based technology can be applied in the process of the hydrogen storage, , seawater desalination, the capture of carbon dioxide, and flow assurance in the pipeline. , …”

Section: Introductionmentioning

confidence: 99%

“…2 In addition, hydrate based technology can be applied in the process of the hydrogen storage, 3,4 seawater desalination, 5 the capture of carbon dioxide, 6 and flow assurance in the pipeline. 7,8 Nowadays, developing the methods for methane production from hydrate reservoirs and investigating production behaviors are attracting considerable attention of the governments and scientists all over the world. Recently, all known methods for hydrate decomposition are based on shifting the thermodynamic equilibrium in a multiphase system (water−hydrate− gas−ice).…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Large Scale Experimental Investigation on Influences of Reservoir Temperature and Production Pressure on Gas Production from Methane Hydrate in Sandy Sediment

Wang

Feng

et al. 2016

Energy Fuels

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The Pilot-Scale Hydrate Simulator (PHS), a three-dimensional 117.8 L pressure vessel, was applied to study the methane hydrate dissociation with different reservoir temperatures and different production pressures in the sandy sediment. The volume of the vessel is big enough to simulate the field-scale gas production from hydrate reservoir. The depressurization method and the depressurization assisted with heat stimulation method were performed as the hydrate dissociation methods. Three different temperatures, which are 4.7 °C, 8.8 °C, and 13.0 °C, were selected as the reservoir temperatures. The range of temperature in this work is the most common temperatures of hydrate reservoir in the ocean sediment. The experimental results indicate that, for the depressurization method, the temperature drop in the reservoir during hydrate dissociation is the key factor for the amount of hydrate dissociation in the depressurization (DP) stage and the rates of hydrate dissociation in the constant-pressure (CP) stage, which can be enhanced by the increase of the temperature drop. With the same production pressure, rate of hydrate dissociation in the experiment with higher reservoir temperature is quicker. With a same pressure drop below hydrate dissociation pressure, the rate of hydrate dissociation in the experiment with the lower reservoir temperature is quicker. For the depressurization assisted with heat stimulation method, the hydrate dissociation rate in the heat stimulation (HS) stage mainly depends on the temperature difference between the injection temperature and the hydrate dissociation temperature corresponding to the production pressure. The larger temperature difference causes the larger hydrate dissociation rate in the HS stage. In addition, the effect of reservoir temperature on the rate of hydrate dissociation is smaller than that of production pressure in the HS stage.

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Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Large Scale Experimental Investigation on Influences of Reservoir Temperature and Production Pressure on Gas Production from Methane Hydrate in Sandy Sediment

Wang

Feng

et al. 2016

Energy Fuels

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“…Hydrate slurry, as a suspension system, exhibits certain non-Newtonian properties. , Many factors affect hydrate viscosity, such as system temperature and pressure, shear rate or flow rate, water cut, particle form, and particle size distribution. Due to the limitation of methane hydrate formation conditions, TBAB, TBAF, TBPB, THF, HCFC-141b, and CO 2 hydrate slurry were selected to analyze its viscosity using the atmospheric rheology testing system. Subsequently, different high-pressure rheometers, such as Physica UDS200, , Physica MCR500, AR-G2, − Physica MCR301, and Anton Paar Mcr 101, ,,− were used to measure the viscosity of the NGH slurry directly.…”

Section: Hydrate Slurry Flow Behavior Research In Chinamentioning

confidence: 99%

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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“…There were many factors affecting slurry viscosity, 40 including system temperature, pressure, shear rate, flow rate, water cut, and so forth. Domestic and foreign scholars have carried out experiments on the viscosity of hydrate slurry in different systems such as TBAB, 41 TBAF, 42 TBPB, 43 THF, HCFC-141B, 44 and CO 2 45 with the help of experimental devices such as reactors, loop, or rheometers. Based on the power law, Herschel–Bulkley, and cross constitutive equations, some viscosity prediction models were proposed.…”

Section: Introductionmentioning

confidence: 99%

Experimental Study of the Growth Kinetics of Natural Gas Hydrates in an Oil–Water Emulsion System

Zhang

Zhao

et al. 2021

ACS Omega

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In order to explore the growth kinetics characteristics of NGH (natural gas hydrate) in an oil and gas mixed transportation pipeline and ensure the safe transportation of the pipeline, with the high-pressure hydrate experimental loop, an experimental study on the growth characteristics of NGH in an oil–water emulsion system was carried out, and the effects of pressure, flow rate, and water cut on the hydrate induction time, gas consumption, consumption rate, and hydrate volume fraction were explored, and important experimental rules were obtained. The experiment was divided into three stages: in the rapid formation stage of the hydrate, the temperature and gas consumption rose sharply, and the pressure dropped suddenly. The induction time decreased with the increase of pressure, flow rate, and water cut. The induction time of 6 MPa was 86.13 min, which was shortened by 39.68% compared with the induction time of 142.8 min of 5 MPa. The induction time of 1500 kg/h was 88.27 min, which was shorter by 13.91% than that 102.53 min of 550 kg/h. The induction time of 20% water cut was 58.53 min, which was shorter by 13.99% than that 68.4 min of 15% water cut. The gas consumption and hydrate volume fraction were both increased with the increase of pressure and water cut and decreased with the increase in the flow rate. In the whole process of the formation of NGH, the consumption rate first increased and then decreased. The pressure-drop and apparent viscosity increased with the increase of hydrate volume fraction in a certain range. The sensitivity analysis of hydrate induction time based on the standard regression coefficient method showed that the initial pressure played a major role, followed by the flow rate and the water cut. Based on the sensitivity analysis of hydrate volume fraction by the gray correlation method, it was found that the hydrate volume fraction had the closest relationship with the initial pressure, followed by the flow rate and the water cut. Finally, the empirical formulas of induction time and hydrate volume fraction in an oil–water emulsion system were established.

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A model for estimating flow assurance of hydrate slurry in pipelines

Cited by 20 publications

References 10 publications

Large Scale Experimental Investigation on Influences of Reservoir Temperature and Production Pressure on Gas Production from Methane Hydrate in Sandy Sediment

Large Scale Experimental Investigation on Influences of Reservoir Temperature and Production Pressure on Gas Production from Methane Hydrate in Sandy Sediment

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

Experimental Study of the Growth Kinetics of Natural Gas Hydrates in an Oil–Water Emulsion System

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