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Influence of Wellbore Trajectory on Pressure Drop and Fluid Discharge

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Fluid Dynamics & Materials Processing 2023年第8期19卷 2053-2066页

作者： Ruidong Wu Guowei Wang Zhixing Yang Ruiquan Liao Yang Cheng Shanghai Branch of CNOOC(China)Co. Ltd.Shanghai200335 CNPC Key Laboratory of Oil and Gas Productions on Yangtze University Jingzhou434023China Petrochina Multiphase Flow Laboratory of Gas Lift Innovation Center Wuhan430100China Petroleum Engineering College of Yangtze University Wuhan430100China

An experimental analysis has been conducted to study the process of fluid accumulation for different borehole trajectories.More specifically,five heel angles have been experimentally realized to simulate the borehole trajectory of the sloping section of the formation.The fluid-carrying capacity,pressure drop and fluid discharge volatility have been investigated for these conditions and,accordingly,the relationship between heel angle and wellbore pressure drop fluid-carrying capacity has been determined.The results show that while the reasonable roll angle can increase the pressure loss in the wellbore,it is beneficial to drainage.In terms of pressure loss and liquid-carrying capacity,when the heeling angle is 50°,the latter is increased while the former becomes very high,which indicates that when drilling and completing wells on site,a 50°roll angle should be avoided.It is found that the main reason for the increase of the total pressure drop in the wellbore is the increase of the local pressure loss in the inclined section.From the perspective of drainage stability,when there is heeling in the inclined section of the horizontal well,the fluctuation of the wellbore drainage tends to be enhanced.Through the comparison of the Beggs-Brill(B-B)and Mukherjee-Brill liquid holdup methods,it is found that B-B method better predicts liquid holdup.A new method for calculating the pressure drop in the inclined section in the presence of lateral inclination is obtained by taking into account the pressure drop in the curved section.Through comparison with experimental data,it is found that the error is within 20%,and the prediction accuracy is high.

关键词： Horizontal well slant section heel angle pressure drop drainage quantity

Improving Existing Drainage and Gas Recovery Technologies: An Experimental Study on the Wellbore Flow in a Horizontal Well

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Fluid Dynamics & Materials Processing 2020年第6期16卷 162-175页

作者： Shan Jin Xiaohong Bai Wei Luo Li Li Ruiquan Liao School of Petroleum Engineering Yangtze UniversityWuhan430100China Laboratory of Multiphase Pipe Flow of Gas Lift Innovation Center CNPC(Yangtze University)WuhanChina The Branch of Key Laboratory of CNPC for Oil and Gas Production Yangtze UniversityJingzhouChina Oil&Gas Technology Research Institute Changqing Oilfield Branch CompanyPetroChinaXi’anChina

With the increasing number of horizontal wells with low pressure,low yield,and water production,the phenomenon of water and liquid accumulation in gas wells is becoming progressively more serious.In order to fix these issues,it is necessary to improve existing drainage and gas recovery technologies,increase the fluid carrying capacity of these wells,and ensure that the bottom-hole airflow has enough energy to transport the liquid to the wellhead.Among the many techniques of drainage and gas recovery,the gas lift has recently become a popular method.In the present study,through the simulation of the entire horizontal well,the flow regularity of the whole wellbore during the lift of low-pressure gas has been analyzed.The pressure distribution,liquid holdup rate,flow pattern,and energy loss(including gravity loss and friction loss)have been determined using the Beggs-brill approach.It has been found that the total pressure drop of the wellbore decreases first and increases gradually after reaching a minimum value when gas extraction is carried out via gas lift.Based on the analysis of the influence of the injection volume on wellbore pressure drop and the influence of flow pattern on the lifting efficiency,the optimal gas-lift injection parameters have been determined by taking the minimum pressure loss of wellbore as the judgment criterion.

关键词： Horizontal well gas-liquid two-phase flow gas lift flow pattern pressure pressure drop

On the Development of a Model for the Prediction of Liquid Loading in Gas Wells with an Inclined Section

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Fluid Dynamics & Materials Processing 2019年第5期15卷 527-544页

作者： Mengna liao Ruiquan Liao Jie Liu Shuangquan Liu Li Li Xiuwu Wang Yang Cheng School of Petroleum Engineering Yangtze UniversityWuhan430100China Laboratory of Multiphase Pipe Flow of Gas Lift Innovation Center CNPC(Yangtze University)Wuhan430100China Oil and Gas Technology Research Institute of Changqing Oilfield Company Xi’an710000China

The ability to predict liquid loading in horizontal gas wells is of great importance for determining the time of drainage and optimizing the related production technology.In the present work,we describe the outcomes of experiments conducted using air-water mixtures in a horizontal well.The results show that the configuration with an inclined section is the most susceptible to liquid loading.Laboratory experiments in an inclined pipe were also conducted to analyze the variation of the critical gas flow rate under different angles,pressure and liquid volume(taking the equal liquid volume at inlet and outlet as the criterion for judging on the critical state).According to these results,the related angle of the inclined section ranges from 45°to 60°.Finally,a modified approach based on the Belfroid model has been used to predict the critical gas flow rate for the inclined section.After comparison with field data,this modified model shows an accuracy of 96%,indicating that it has better performances with respect to other models used in the past to predict liquid loading.

关键词： Horizontal gas well inclined section liquid loading critical gas flow rate air-water flow

Slug Flow Characteristics in Inclined and Vertical Channels

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Fluid Dynamics & Materials Processing 2019年第5期15卷 583-595页

作者： Zhihui Wang Wei Luo Ruiquan Liao Xiangwei Xie Fuwei Han Hongying Wang Petroleum Engineering Institute of Yangtze University WuhanChina Laboratory of Multiphase Pipe Flow Gas Lift Innovation CenterChina National Petroleum CorpWuhanChina The Branch of Key Laboratory of CNPC for Oil and Gas Production Yangtze UniversityJingzhouChina Exploration Department of Petro China Tarim Oilfield Company KorlaChina The Third Drilling Company of Bohai Drilling Engineering Co. Ltd.of CNPCTianjinChina Research and Development Center Tuha Oilfield CompanyCNPCTulufanChina

Horizontal well production technology gradually occupies a dominant position in the petroleum field.With the rise in water production in the later stage of exploitation,slug flow phenomena will exist in horizontal,inclined and even vertical sections of gas wells.To grasp the flow law of slug flow and guide engineering practice,the flow law of slug flow at various inclination angles(30°~90°)is studied by means of the combination of laboratory experiments(including high frequency pressure data acquisition system)and finite element numerical simulation.The results reveal that because of the delay of pressure variation at the corresponding position of pipeline resulting from gas expansion,the highest point of pressure change curve corresponds not to the highest point of liquid holdup curve(pressure change lags behind 0.125 s of liquid holdup change).Thus,the delay of pressure should be highlighted in predicting slug flow using pressure parameter change;otherwise the accuracy of prediction will be affected when slug flow occurs.It is generally known that liquid holdup and pressure drop are the major factors affecting the pressure variation and stable operation of pipelines.Accordingly,the results of finite element numerical simulation and Beggs-Brill model calculation are compared with those of laboratory experiments.The numerical simulation method is applicable to predicting the pressure drop of the pipeline,while the Beggs-Brill model is more suitable for predicting the liquid holdup variation of the pipeline.The research conclusion helps reveal the slug flow law,and it is of a scientific guiding implication to the prediction method of flow parameters under slug flow pattern in the process of gas well exploitation.

关键词： Slug flow volume liquid holdup pressure pressure drop flow pattern numerical simulation

An Experimental Study on the Pressure Distribution in Horizontal Gas Wells

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Fluid Dynamics & Materials Processing 2020年第6期16卷 176-191页

作者： Jinbo Liu Ziheng Jiang Xuezhang Feng Ruiquan Liao Dianfang Feng Xingkai Zhang Hasimu Aikeremu No.1 Gas Production Plant of Xinjiang Oilfield Company Karamay834000China School of Petroleum Engineering Yangtze UniversityWuhan430100China

Laboratory experiments have been carried out to study the fluid flow in the wellbore of a horizontal gas well during the production process.The related pressure distribution has been determined considering different cases(different inflow media,different perforation opening methods and different liquid holdup).It has been found that the larger the fluid flow rate,the greater the pressure changes in the wellbore under the same hole opening mode.The uniformity of the perforation opening method was also an important factor affecting the magnitude of the wellbore pressure change.The liquid holdup also affected the pressure distribution,especially when the gas volumetric flow rate exceeded 200 m3/h.Comparison of the outcomes of the present experimental study with the predictions of a theoretical model available in the literature has provided a relative error smaller than 20%.

关键词： Horizontal gas well laboratory experiment pressure distribution

A Pressure-Drop Model for Oil-Gas Two-Phase Flow in Horizontal Pipes

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Fluid Dynamics & Materials Processing 2021年第2期17卷 371-383页

作者： Xinke Yang Shanzhi Shi Hui Zhang Yuzhe Yang Zilong Liu Ruiquan Liao Joseph X.F.Ribeiro Engineer Technology Research Institute of Xinjiang Oilfield Company Karamay834000China School of Petroleum Engineering Yangtze UniversityWuhan430100China Laboratory of Multiphase Pipe Flow of Gas Lift Innovation Center CNPC(Yangtze University)Wuhan430100China Kumasi Technical University KumasiGhana

The accurate prediction of the pressure distribution of highly viscous fluids in wellbores and pipelines is of great significance for heavy oil production and transportation.The flow behavior of high-viscosity fluids is quite different with respect to that of low-viscosity fluids.Currently,the performances of existing pressure-drop models seem to be relatively limited when they are applied to high-viscosity fluids.In this study,a gas-liquid two-phase flow experiment has been carried out using a 60 mm ID horizontal pipe with air and white oil.The experimental results indicate that viscosity exerts a significant influence on the liquid holdup and pressure drop.At the same gas and liquid volume,both the liquid holdup and pressure drop increase with an increase in the viscosity.Combining two existing models,a modified pressure drop method is developed,which is applicable to horizontal pipes for different viscosities and does not depend on the flow pattern.This new method displays a high accuracy in predicting the new experimental data presented here and other published data in literature.

关键词： Horizontal pipe different viscosities pressure drop model gas-liquid two-phase flow

Effect of the Inclination Angle on Slippage Loss in Gas-Liquid Two-Phase Flow

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Fluid Dynamics & Materials Processing 2020年第3期16卷 475-488页

作者： Yushan Liu Yubin Su Zhenhua Wu Wei Luo Ruiquan Liao School of Petroleum Engineering Yangtze UniversityWuhan430100China Laboratory of Multiphase Pipe Flow of Gas Lift Innovation Center CNPC(Yangtze University)Wuhan430100China Oil&Gas Technology Research Institute Changqing Oilfield Branch CompanyPetroChinaXi’an710021China Research and Development Center Tuha Oilfield CompanyTulufan838202China

The lifting efficiency and stability of gas lift well are affected by the socalled slippage-loss effect in gas-liquid two-phase flow.The existing studies on this subject have generally been based on vertical and horizontal wells.Only a few of them have considered inclined pipes.In the present work a new focused study is presented along these lines.More specifically,we use the non-slip pressure drop model with Flanigan’s fluctuation correction coefficient formula(together with the parameters of slippage density,slippage pressure drop and slippage ratio)to analyze the influence of the inclination angle on slippage loss for different conditions(different gas-liquid superficial velocity and pipe diameters).Moreover,the“standard regression coefficient method”is used for multi-factor sensitivity analysis.The experimental results indicate that slippage loss is affected by multiple factors,and the influence of the inclination angle on slippage loss is less significant than other factors.The change of the slippage pressure drop with the superficial velocity of gas-liquid is similar to that of the total pressure drop.The inclination angles of 45°and 60°have the greatest influence on slippage loss.The correlation between slippage density and slippage ratio is not obvious.Using the so-called slippage ratio seems to be a more accurate option to evaluate the degree of slippage loss.

关键词： Inclined pipes gas-liquid flow slippage loss pressure drop gas-liquid ratio

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带压作业用自降解凝胶性能的评价

油田化学 2023年第2期40卷 211-216页

作者：杨雪廖锐全汪瀛荆州学院湖北荆州434023 CNPC气举试验基地湖北武汉430000 长江大学石油工程学院湖北武汉430100

凝胶带压封隔技术要求凝胶所需的强度与其破胶性能的矛盾性限制了该技术的发展。鉴于外部破胶困难,通过引入不稳定交联剂PLG与丙烯酰胺、丙烯酸共聚合成了一种PLG自降解凝胶,采用单一变量法研究了配方组分浓度对凝胶降解时间的影响,通... 详细信息

凝胶带压封隔技术要求凝胶所需的强度与其破胶性能的矛盾性限制了该技术的发展。鉴于外部破胶困难,通过引入不稳定交联剂PLG与丙烯酰胺、丙烯酸共聚合成了一种PLG自降解凝胶,采用单一变量法研究了配方组分浓度对凝胶降解时间的影响,通过单轴压缩实验探究了凝胶强度,通过热重分析与PEGDA凝胶对比分析了PLGN凝胶的降解性能,探究了PLG凝胶的封堵性能。结果表明,PLG凝胶优化配方为:丙烯酸加量为7%、丙烯酰胺加量为7%、不稳定交联剂PLG加量为0.4%、APS加量为0.3%。PLG凝胶的本体强度为55.1 N;热重分析表明PLG凝胶具有优异的降解性能,相比PEGDA凝胶,PLG凝胶具有更短的降解时间。凝胶在60~100℃均可实现降解,温度越高降解时间越短。此外,凝胶封堵实验表明,凝胶在60~100℃均有较好的封堵能力,且在凝胶封堵作业结束后不需要额外注入破胶剂。凝胶降解时间可以通过设计配方来控制,以实现凝胶的快速破胶。该自降解凝胶可以作为油气井带压作业封堵剂。

关键词：带压作业凝胶破胶自降解封堵

Study on Temperature Distribution of Perforated Horizontal Wellbore

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Journal of Thermal Science 2020年第1期29卷 194-205页

作者： ZHANG Xingkai JIANG Ziheng liao ruiquan SHI Baocheng WU Lijuan LIU Kai ZHANG Yindi Petroleum Engineering College Yangtze UniversityWuhan 430100China The Branch of Key Laboratory of CNPC for Oil and Gas Production Yangtze UniversityJingzhou 434023China

The temperature distribution in the wellbore under different conditions was studied by using a designed horizontal well simulation experimental device.The experimental results showed that the Joule-Thomson effect was significant in perforated wellbore.When the opening mode was the same,the larger the gas flow rate,the lower the temperature in the wellbore.Furthermore,with the increase of liquid volume,the temperature drop effect decreased gradually.The more uniform the perforation distribution,the smaller the temperature change in the wellbore.With the increase of liquid volume,the influence of gas flow rate on temperature distribution decreased.The temperature gradient caused by Joule-Thomson effect decreased with the increase of wellbore holdup.At the same time,the experimental results were compared with the theoretical values.It was found that the error of the model was within 4%,which showed the reliability of predictions of the model.

关键词： horizontal well simulation experiment perforation Joule-Thomson effect temperature distribution