This page has only limited features, please log in for full access.
Hydrate-based technologies (HBTs) have high potential in many fields. The industrial application of HBTs is limited by the low conversion rate of the water into hydrate (RWH), and sodium lignin sulfonate (SLS) has the potential to solve the above problem. In order to make the HBTs in the presence of SLS applied in industry and promote the advances of commercial HBTs, the effect of SLS on the thermodynamic equilibrium hydrate formation pressure (Peq) was investigated for the first time, and a new model (which can predict the Peq) was proposed to quantitatively describe the thermodynamic effect of SLS on the hydrate formation. Then, the effects of pressure and initial SLS concentration on the hydrate formation rate (rR) at different stages in the process of hydrate formation were investigated for the first time to reveal the kinetic effect of SLS on hydrate formation. The experimental results show that SLS caused little negative thermodynamic effect on hydrate formation. The Peq of the ethylene-SLS solution system predicted by the model proposed in this work matches the experimental data well, with an average relative deviation of 1.6% and a maximum relative deviation of 4.7%. SLS increased RWH: the final RWH increased from 57.6 ± 1.6% to higher than 70.0% by using SLS, and the highest final RWH (77.0 ± 2.1%) was achieved when the initial SLS concentration was 0.1 mass%. The rR did not significantly change as RWH increased from 35% to 65% in the formation process in the presence of SLS. The effect of increasing pressure on increasing rR decreased with the increase in RWH when RWH was lower than 30%, and the difference in pressure led to little difference in the rR when RWH was higher than 30%.
Yiwei Wang; Lin Wang; Zhen Hu; Youli Li; Qiang Sun; Aixian Liu; Lanying Yang; Jing Gong; Xuqiang Guo. The Thermodynamic and Kinetic Effects of Sodium Lignin Sulfonate on Ethylene Hydrate Formation. Energies 2021, 14, 3291 .
AMA StyleYiwei Wang, Lin Wang, Zhen Hu, Youli Li, Qiang Sun, Aixian Liu, Lanying Yang, Jing Gong, Xuqiang Guo. The Thermodynamic and Kinetic Effects of Sodium Lignin Sulfonate on Ethylene Hydrate Formation. Energies. 2021; 14 (11):3291.
Chicago/Turabian StyleYiwei Wang; Lin Wang; Zhen Hu; Youli Li; Qiang Sun; Aixian Liu; Lanying Yang; Jing Gong; Xuqiang Guo. 2021. "The Thermodynamic and Kinetic Effects of Sodium Lignin Sulfonate on Ethylene Hydrate Formation." Energies 14, no. 11: 3291.
This paper investigated the bubble migration and evolution during gas-liquid flow in oil-pipelines. Multi-scale bubbles migrated in the pipe while interacting with each other, causing coalescence and disintegration. The bubbles collided and coalesced, forming a new air pocket in the downward inclined pipe that blocked the transportation of both the gas and liquid phases. Consequently, the buoyance weakened the migration ability of the bubbles, which is known as re-coalescence. To investigate, a new transient model applied with the population balance model (PBM), and Eulerian-Lagrangian coupling scheme is proposed. The complex flow field was modeled using the Eulerian scheme, while the migration of the bubbles was designed in the Lagrangian mesh. Furthermore, the PBM was employed to describe the multi-scale bubble interaction and migration. Smooth particle hydrodynamics were applied to connect the bubble-dimension and pipe-dimension descriptions. Therefore, the bubble fraction could be described to predict the re-coalescence of air pockets. The required unknown model parameters were extracted from the published experimental data, while the simulation results corresponded well with the measured results. During the simulation, the effect of the liquid Froude number and pipe inclination on the size distribution of the multi-scale bubbles were investigated. The results indicated that an increase in the pipe inclination and liquid Froude number improved the bubble migration capacity, leading to a broader distribution of bubbles of all sizes.
Sihang Chen; Jing Gong; Wang Li; Qi Yang; Guoyun Shi; Xiaoping Li; Bohui Shi; Shangfei Song; Pengfei Lv; Di Fan; Xu Duan. A new transient model of multi-scale bubble migration and evolution during gas-liquid flow in pipelines. Journal of Petroleum Science and Engineering 2021, 205, 108888 .
AMA StyleSihang Chen, Jing Gong, Wang Li, Qi Yang, Guoyun Shi, Xiaoping Li, Bohui Shi, Shangfei Song, Pengfei Lv, Di Fan, Xu Duan. A new transient model of multi-scale bubble migration and evolution during gas-liquid flow in pipelines. Journal of Petroleum Science and Engineering. 2021; 205 ():108888.
Chicago/Turabian StyleSihang Chen; Jing Gong; Wang Li; Qi Yang; Guoyun Shi; Xiaoping Li; Bohui Shi; Shangfei Song; Pengfei Lv; Di Fan; Xu Duan. 2021. "A new transient model of multi-scale bubble migration and evolution during gas-liquid flow in pipelines." Journal of Petroleum Science and Engineering 205, no. : 108888.
The coexistence of wax deposition and gas hydrate in deep-water submarine pipelines enhances blockage risk, which is a serious threat to pipeline security. This work applied molecular dynamics (MD) simulations to explore the effect of wax molecules on methane hydrate formation. The growth trajectories, the main structural properties, potential energy, and hydrate cage information of methane hydrate in the absence/presence of wax molecules were analyzed. The simulation results show that the presence of ten C17 n-alkane wax molecules promoted the growth of methane hydrate throughout the simulation, while the presence of one C17 n-alkane wax molecule and one C50 n-alkane wax molecule promoted hydrate growth before 40 ns, subsequently inhibiting it. According to the snapshot information and coordination number of wax molecules, it was concluded that the addition of wax molecule(s) advanced the formation of gas bubbles, while the crystallization of ten C17 n-alkane wax molecules occurred before bubble formation. Additionally, gas–liquid-solid three-phase contact is beneficial to the growth of methane hydrate, while the gas–solid interface distance could be affected by the presence of the wax molecule(s) in the gas bubble. Therefore, the molecular level analysis based on MD simulations showed that the effect of wax molecules on methane hydrate formation was complex, depending on the distribution of the wax molecules and the gas bubble in the system.
Qingyun Liao; Bohui Shi; Sha Li; Shangfei Song; Yuchuan Chen; Jinjun Zhang; Haiyuan Yao; Qingping Li; Jing Gong. Molecular dynamics simulation of the effect of wax molecules on methane hydrate formation. Fuel 2021, 297, 120778 .
AMA StyleQingyun Liao, Bohui Shi, Sha Li, Shangfei Song, Yuchuan Chen, Jinjun Zhang, Haiyuan Yao, Qingping Li, Jing Gong. Molecular dynamics simulation of the effect of wax molecules on methane hydrate formation. Fuel. 2021; 297 ():120778.
Chicago/Turabian StyleQingyun Liao; Bohui Shi; Sha Li; Shangfei Song; Yuchuan Chen; Jinjun Zhang; Haiyuan Yao; Qingping Li; Jing Gong. 2021. "Molecular dynamics simulation of the effect of wax molecules on methane hydrate formation." Fuel 297, no. : 120778.
In this study, a subset simulation-based methodology is developed to evaluate the time-dependent reliability of the corroding pipeline with multiple correlated corrosion defects. Two competing failure modes, namely small leak and burst, are considered in the methodology. Firstly, the time-dependent structural reliability model of the two competing failure modes is established. Then, the computational framework for implementing subset simulation for failure probability estimation of the individual corrosion defect is presented. Thereafter, a procedure to calculate the system reliability of the entire pipeline with correlated corrosion defects is proposed. Moreover, a numerical example based on a real natural gas pipeline is proposed, and the time-dependent failure probabilities of both the small leak and burst are predicted, which are compared with the evaluation results produced by the direct Monte Carlo simulation and Kriging method. By means of numerical example, the accuracy and efficiency of our methodology are demonstrated. Furthermore, a sensitivity analysis is performed to investigated the effect of the correlation of the corrosion defects on the system reliability, and the results indicate that the correlation exert great impact on system reliability.
Weichao Yu; Weihe Huang; Kai Wen; Jie Zhang; Hongfei Liu; Kun Wang; Jing Gong; Chunxu Qu. Subset simulation-based reliability analysis of the corroding natural gas pipeline. Reliability Engineering & System Safety 2021, 213, 107661 .
AMA StyleWeichao Yu, Weihe Huang, Kai Wen, Jie Zhang, Hongfei Liu, Kun Wang, Jing Gong, Chunxu Qu. Subset simulation-based reliability analysis of the corroding natural gas pipeline. Reliability Engineering & System Safety. 2021; 213 ():107661.
Chicago/Turabian StyleWeichao Yu; Weihe Huang; Kai Wen; Jie Zhang; Hongfei Liu; Kun Wang; Jing Gong; Chunxu Qu. 2021. "Subset simulation-based reliability analysis of the corroding natural gas pipeline." Reliability Engineering & System Safety 213, no. : 107661.
The fluctuation characteristics of the gas demand and the effect of the user importance are usually ignored in previous gas supply reliability research. With the intent of overcoming these deficiencies, an integrated method based on the demand-side analysis is proposed in this study to assess the gas supply reliability of the large-scale and complex natural gas pipeline network. The method is composed of the establishment of the indicator system, the demand-side analysis, the estimation of the unit failure probability, and the calculation of the gas supply. Among them, the demand-side analysis focuses on the market demand forecasting and user importance research. Moreover, the coupling effect of the user importance, the hydraulic and pressure constraints, and the unit failure on the gas supply calculation is considered. Furthermore, a real natural gas pipeline network located in China is applied to confirm the feasibility of the method. According to the evaluation results of the gas supply reliability, the weakest nodes and key links of the natural gas pipeline network are identified, and the suggestions to improve the gas supply reliability are proposed as well. At last, the significance of the demand side in the gas supply reliability is elaborated and validated.
Weichao Yu; Weihe Huang; Yunhao Wen; Yichen Li; Hongfei Liu; Kai Wen; Jing Gong; Yanan Lu. An integrated gas supply reliability evaluation method of the large-scale and complex natural gas pipeline network based on demand-side analysis. Reliability Engineering & System Safety 2021, 212, 107651 .
AMA StyleWeichao Yu, Weihe Huang, Yunhao Wen, Yichen Li, Hongfei Liu, Kai Wen, Jing Gong, Yanan Lu. An integrated gas supply reliability evaluation method of the large-scale and complex natural gas pipeline network based on demand-side analysis. Reliability Engineering & System Safety. 2021; 212 ():107651.
Chicago/Turabian StyleWeichao Yu; Weihe Huang; Yunhao Wen; Yichen Li; Hongfei Liu; Kai Wen; Jing Gong; Yanan Lu. 2021. "An integrated gas supply reliability evaluation method of the large-scale and complex natural gas pipeline network based on demand-side analysis." Reliability Engineering & System Safety 212, no. : 107651.
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.
Bohui Shi; Shangfei Song; Yuchuan Chen; Xu Duan; Qingyun Liao; Shunkang Fu; Lihao Liu; Jinhao Sui; Junpeng Jia; Haotian Liu; Yumo Zhu; Chenxi Song; Decai Lin; Ting Wang; Junao Wang; Haiyuan Yao; Jing Gong. Status of Natural Gas Hydrate Flow Assurance Research in China: A Review. Energy & Fuels 2021, 35, 3611 -3658.
AMA StyleBohui Shi, Shangfei Song, Yuchuan Chen, Xu Duan, Qingyun Liao, Shunkang Fu, Lihao Liu, Jinhao Sui, Junpeng Jia, Haotian Liu, Yumo Zhu, Chenxi Song, Decai Lin, Ting Wang, Junao Wang, Haiyuan Yao, Jing Gong. Status of Natural Gas Hydrate Flow Assurance Research in China: A Review. Energy & Fuels. 2021; 35 (5):3611-3658.
Chicago/Turabian StyleBohui Shi; Shangfei Song; Yuchuan Chen; Xu Duan; Qingyun Liao; Shunkang Fu; Lihao Liu; Jinhao Sui; Junpeng Jia; Haotian Liu; Yumo Zhu; Chenxi Song; Decai Lin; Ting Wang; Junao Wang; Haiyuan Yao; Jing Gong. 2021. "Status of Natural Gas Hydrate Flow Assurance Research in China: A Review." Energy & Fuels 35, no. 5: 3611-3658.
In this study, we have analyzed the impact of COVID-19 on natural gas supply reliability. Natural gas supply reliability is defined as the ability to satisfy the market demand and is determined by both supply-side and demand-side policy. To evaluate the gas supply reliability of the natural gas pipeline system, we have applied the method of gas supply capacity calculation based on the results of the previous gas supply reliability studies. The method combines the unsteady flow hydraulic analysis, simulation of the state transition process, and the forecasting analysis of the demand and consumption. The analysis presents a case study based on the gas pipeline system in China. The analysis results indicate that the COVID-19 consequences will cause a decrease in gas supply reliability.
Yichen Li; Weichao Yu; Zihui Han; Shuang Shi; Weihe Huang; Kai Wen; Jing Gong. Analysis of COVID-19 Impact on Natural Gas Supply Reliability. Chemistry and Technology of Fuels and Oils 2021, 56, 994 -999.
AMA StyleYichen Li, Weichao Yu, Zihui Han, Shuang Shi, Weihe Huang, Kai Wen, Jing Gong. Analysis of COVID-19 Impact on Natural Gas Supply Reliability. Chemistry and Technology of Fuels and Oils. 2021; 56 (6):994-999.
Chicago/Turabian StyleYichen Li; Weichao Yu; Zihui Han; Shuang Shi; Weihe Huang; Kai Wen; Jing Gong. 2021. "Analysis of COVID-19 Impact on Natural Gas Supply Reliability." Chemistry and Technology of Fuels and Oils 56, no. 6: 994-999.
Hydrate slurry decomposition in flow systems is a significant subject that involves flow assurance and development of marine natural gas hydrates.
Xiaofang Lv; Yang Liu; Shidong Zhou; Bohui Shi; Kele Yan. Study on the decomposition mechanism and kinetic model of natural gas hydrate slurry in water-in-oil emulsion flowing systems. RSC Advances 2021, 11, 3879 -3889.
AMA StyleXiaofang Lv, Yang Liu, Shidong Zhou, Bohui Shi, Kele Yan. Study on the decomposition mechanism and kinetic model of natural gas hydrate slurry in water-in-oil emulsion flowing systems. RSC Advances. 2021; 11 (7):3879-3889.
Chicago/Turabian StyleXiaofang Lv; Yang Liu; Shidong Zhou; Bohui Shi; Kele Yan. 2021. "Study on the decomposition mechanism and kinetic model of natural gas hydrate slurry in water-in-oil emulsion flowing systems." RSC Advances 11, no. 7: 3879-3889.
The oil tank can form a considerable amount of sludge deposition after continuous accumulation, which cause a seriously negative impact on both the storage capacity and the safe operation of the oil tank. Therefore, it is important to anticipate the rate of sludge deposition in advance so that proper measures can be planned to remove this heavy layer on the bottom. This paper proposes a method using a relatively simple formula for predicting the sludge deposits. The sedimentation mechanism of wax and asphaltene is introduced and summarized from both the micro and macro aspects, the factors causing the interaction between particles and the influence on coalescence were analyzed. We applied our prediction methods to calculate the sludge deposition of four oil tanks in Mo-he Station and compared our results with the data measured by experiments. The results show that our method had a good general accuracy to experimental data and can be used directly for on-site engineers to anticipate real sludge height before measuring the oil level inside the tank.
Huayu Jiang; Yumo Wang; Chaofei Nie; Feng Yan; Xin Ouyang; Jing Gong. Oil Sludge Deposition in Storage Tanks: A Case Study for Russian Crude Oil in Mo-he Station. Applied Sciences 2020, 11, 321 .
AMA StyleHuayu Jiang, Yumo Wang, Chaofei Nie, Feng Yan, Xin Ouyang, Jing Gong. Oil Sludge Deposition in Storage Tanks: A Case Study for Russian Crude Oil in Mo-he Station. Applied Sciences. 2020; 11 (1):321.
Chicago/Turabian StyleHuayu Jiang; Yumo Wang; Chaofei Nie; Feng Yan; Xin Ouyang; Jing Gong. 2020. "Oil Sludge Deposition in Storage Tanks: A Case Study for Russian Crude Oil in Mo-he Station." Applied Sciences 11, no. 1: 321.
Hydrates and waxes are supposed to coexist in the deep-water pipelines under suitable conditions of low temperature and high pressure. Understanding the effect of precipitated wax crystals on hydrate formation and rheological properties of hydrate slurry is crucial to the flow assurance in offshore petroleum production. In this work, a stress-controlled rheometer was used to carry out the rheological experiments for investigating the impact of wax crystals on hydrate formation and yield property of hydrate slurry. The effects of wax content and water cut on cyclopentane (CP) hydrate nucleation and growth were investigated in terms of the measured viscosity data. Log-normal distribution could well fit the probability density histogram of CP hydrate critical time. The logarithmic mean values of CP hydrate critical time decreased with increasing water cut but increased with increasing wax content in water-in-oil (w/o) emulsions. Semi-empirical models were proposed to describe the inhibitory effect of wax crystals on CP hydrate nucleation kinetics by considering the inhibition of mass transfer based on the Freundlich and Langmuir adsorption functions, respectively. Hydrate slurry viscosity rate showed the two-stage characteristics in wax-free w/o emulsions, while four stages could be clearly observed in waxy w/o emulsions. The maximum values of hydrate slurry viscosity rate and calculated hydrate effective volume fraction decreased with increasing wax content. Hydrate growth time was gradually extended as wax content increased. Furthermore, the measured yield stress and yield strain increased with increasing wax content at different water cuts, which was associated with the multiple effect of capillary bridge between hydrate particles, spatial network of wax crystals and coalescence of water droplets. At last, compared to the stress ramp rate, the influence of annealing time on yield stress was more significant.
Yuchuan Chen; Bohui Shi; Shunkang Fu; Qingping Li; Haiyuan Yao; Yang Liu; Xiaofang Lv; Junao Wang; Qingyun Liao; Xu Duan; Jing Gong. Kinetic and rheological investigation of cyclopentane hydrate formation in waxy water-in-oil emulsions. Fuel 2020, 287, 119568 .
AMA StyleYuchuan Chen, Bohui Shi, Shunkang Fu, Qingping Li, Haiyuan Yao, Yang Liu, Xiaofang Lv, Junao Wang, Qingyun Liao, Xu Duan, Jing Gong. Kinetic and rheological investigation of cyclopentane hydrate formation in waxy water-in-oil emulsions. Fuel. 2020; 287 ():119568.
Chicago/Turabian StyleYuchuan Chen; Bohui Shi; Shunkang Fu; Qingping Li; Haiyuan Yao; Yang Liu; Xiaofang Lv; Junao Wang; Qingyun Liao; Xu Duan; Jing Gong. 2020. "Kinetic and rheological investigation of cyclopentane hydrate formation in waxy water-in-oil emulsions." Fuel 287, no. : 119568.
A transient composition tracking method is developed for natural gas pipe networks. It adopts the control volume method for hydraulic simulation and a one-dimensional unsteady heat transfer model for thermal simulation. In order to model the junction in the network, a special grid is proposed to connect all adjacent pipes together. Under this grid, the momentum equation could be discretized by the first-order upwind scheme while the mass equation could be discretized just like an ordinary pipe node. To track the composition, the advective concentration equation is given for each component. Therefore, the gas composition in the pipe network could be predicted in real time and its influence on the calculation of property parameters could be taken into consideration. Based on these models, a transient composition tracking algorithm is developed for natural gas pipe networks. It consists of three parts: transient flow simulation, composition tracking and parameters calculation. Case studies show that the proposed method can provide reliable results for transient flow simulation. Compared with the measured data, the composition outcomes given by this method are also very accurate. In addition, the impact of injecting LNG/H2 into the pipe network is quite complicated and should be treated with caution.
Di Fan; Jing Gong; Shengnan Zhang; Guoyun Shi; Qi Kang; Yaqi Xiao; Changchun Wu. A transient composition tracking method for natural gas pipe networks. Energy 2020, 215, 119131 .
AMA StyleDi Fan, Jing Gong, Shengnan Zhang, Guoyun Shi, Qi Kang, Yaqi Xiao, Changchun Wu. A transient composition tracking method for natural gas pipe networks. Energy. 2020; 215 ():119131.
Chicago/Turabian StyleDi Fan; Jing Gong; Shengnan Zhang; Guoyun Shi; Qi Kang; Yaqi Xiao; Changchun Wu. 2020. "A transient composition tracking method for natural gas pipe networks." Energy 215, no. : 119131.
Electric submersible pumps (ESPs) are widely used in the oil and gas industry for crude-oil lifting, especially in subsea oil fields or underground storage caverns. The failure of ESPs causes a large economic cost mainly attributed to a break in production continuity, as the ESP cannot be easily replaced. Therefore, the assurance of safe and efficient operation of ESPs has attracted high attention in recent years, although the problem still remains challenging given the complexity of carrying fluid and the mechanical structure of the ESP. In this article, we systematically review both the high-impact, classic contributions and the most up-to-date, current opinions in experimental and numerical advances of viscous effects and two-phase flow in ESPs. We specifically focus on the applications in the oil and gas industry and point out a few current challenges in the operation of ESPs. We aim to guide the audience which is new to the area of ESPs to the correct articles related to their interests, including classic work and recent advances.
Peng Liu; Yumo Wang; Feng Yan; Chaofei Nie; Xin Ouyang; Jiashuang Xu; Jing Gong. Effects of Fluid Viscosity and Two-Phase Flow on Performance of ESP. Energies 2020, 13, 5486 .
AMA StylePeng Liu, Yumo Wang, Feng Yan, Chaofei Nie, Xin Ouyang, Jiashuang Xu, Jing Gong. Effects of Fluid Viscosity and Two-Phase Flow on Performance of ESP. Energies. 2020; 13 (20):5486.
Chicago/Turabian StylePeng Liu; Yumo Wang; Feng Yan; Chaofei Nie; Xin Ouyang; Jiashuang Xu; Jing Gong. 2020. "Effects of Fluid Viscosity and Two-Phase Flow on Performance of ESP." Energies 13, no. 20: 5486.
A transient simulation tool for the gas hydrate slurry flow is crucial for hydrate flow assurance in the petroleum industry. In this work, we propose a new transient model for gas hydrate slurry flow in oil-dominated flowlines. A two-fluid model and a temperature equation are used to describe the gas-slurry two-phase flow. For the modeling of particulate phase flow, number density conservation equation and diameter conservation equation of the hydrate particles are established by Eulerian approach, a momentum conservation equation is established by Lagrangian approach. Furthermore, combining with the hydrate formation model, the transient gas hydrate slurry flow in oil-dominated flowlines can be numerically simulated. This model is verified by experimental data and field data, respectively. Afterwards, it is applied to analyze the transient behavior of the gas-hydrate slurry multiphase flow upon reduced gas well production. Finally, the sensitivity analysis of effects of flowrate, initial average size of water droplets and drag force on the hydrate slurry multiphase flow is performed. These results are of great practical value to give a deeper understanding of hydrate slurry multiphase flow, and contribute to better hydrate management in the petroleum industry by using hydrate slurry flow technology.
Guoyun Shi; Shangfei Song; Bohui Shi; Jing Gong; Dongliang Chen. A new transient model for hydrate slurry flow in oil-dominated flowlines. Journal of Petroleum Science and Engineering 2020, 196, 108003 .
AMA StyleGuoyun Shi, Shangfei Song, Bohui Shi, Jing Gong, Dongliang Chen. A new transient model for hydrate slurry flow in oil-dominated flowlines. Journal of Petroleum Science and Engineering. 2020; 196 ():108003.
Chicago/Turabian StyleGuoyun Shi; Shangfei Song; Bohui Shi; Jing Gong; Dongliang Chen. 2020. "A new transient model for hydrate slurry flow in oil-dominated flowlines." Journal of Petroleum Science and Engineering 196, no. : 108003.
A methodology to quantify the economic risk of a natural gas transmission pipeline system is developed in this study, and the effect of the line pack is considered. The methodology is based on the risk theory and hydraulic analysis of the transmission pipeline system. In the methodology, the failure probability of the key components in the transmission pipeline system are estimated firstly. Moreover, the transient compressible model for the pipeline system is employed to perform the consequence analysis, and the model is solved by the Semi-Implicit Method for Pressure-Linked Equation (SIMPLE) algorithm in the process of the consequence analysis. By combining the failure probability estimation with the consequence analysis, the economic risk when an accident happens can be evaluated. A detailed procedure for economic risk evaluation of a natural gas transmission pipeline system is presented, and its feasibility is confirmed with a real transmission pipeline system. Furthermore, impacts of the line pack on the economic risk are investigated, and suggestions to decrease the economy risk are proposed.
Guoyun Shi; Weichao Yu; Kun Wang; Fuhua Dang; Jing Gong; Yanan Lu. Time-dependent economic risk analysis of the natural gas transmission pipeline system. Process Safety and Environmental Protection 2020, 146, 432 -440.
AMA StyleGuoyun Shi, Weichao Yu, Kun Wang, Fuhua Dang, Jing Gong, Yanan Lu. Time-dependent economic risk analysis of the natural gas transmission pipeline system. Process Safety and Environmental Protection. 2020; 146 ():432-440.
Chicago/Turabian StyleGuoyun Shi; Weichao Yu; Kun Wang; Fuhua Dang; Jing Gong; Yanan Lu. 2020. "Time-dependent economic risk analysis of the natural gas transmission pipeline system." Process Safety and Environmental Protection 146, no. : 432-440.
To inhibit wall sticking during gathering of high water cut crude oil, based on the deposition characteristics of the complexes by reaction of phytic acid (PA) with ferric chloride (FC), a simple and environmentally friendly method for carbon steel plate modification was adopted in this study. The effects of reaction time, FC concentration, and deposition times on surface wettability and morphology were investigated. It appeared in the results that the wettability of the surface no longer changed after 1 min of reaction. After two times of deposition, the carbon steel exhibited superhydrophilicity in air and superoleophobicity under water, and more pronounced nano-structures were observed. Comparing with similar works, no electroplating, heating and other devices are required during the entire coating process. Moreover, for the sake of clearly explaining the mechanism of wettability conversion during PA-FC modification, the theory of surface energy and adhesion work were used to quantitatively calculate the adhesion strength of oil droplet on solid surfaces. It was found that the hydrophilization and underwater oleophobicization of materials were essentially a process of increasing the polar component of surface energies, and the opposite adhesion state of oil in air and under water was demonstrated theoretically. Finally, the anti-sticking ability at low temperatures of treated carbon steel was evaluated experimentally. The PA-FC coating showed good oil gel prevention performance below the pour point of crude oil. In conclusion, the wall sticking prevention method proposed in our work provides another way for flow assurance of the transportation of high water cut crude oil.
Ang Li; Mengqi Zhu; Pengfei Hao; Haihao Wu; Jing Gong; Kun Wang; Weichao Yu; Yaorong Feng. Wall sticking inhibition of high water cut crude oil (below pour point) by underwater superoleophobic PA-FC modification. Colloids and Surfaces A: Physicochemical and Engineering Aspects 2020, 607, 125427 .
AMA StyleAng Li, Mengqi Zhu, Pengfei Hao, Haihao Wu, Jing Gong, Kun Wang, Weichao Yu, Yaorong Feng. Wall sticking inhibition of high water cut crude oil (below pour point) by underwater superoleophobic PA-FC modification. Colloids and Surfaces A: Physicochemical and Engineering Aspects. 2020; 607 ():125427.
Chicago/Turabian StyleAng Li; Mengqi Zhu; Pengfei Hao; Haihao Wu; Jing Gong; Kun Wang; Weichao Yu; Yaorong Feng. 2020. "Wall sticking inhibition of high water cut crude oil (below pour point) by underwater superoleophobic PA-FC modification." Colloids and Surfaces A: Physicochemical and Engineering Aspects 607, no. : 125427.
In this study, a systematic and comprehensive methodology to assess the operating reliability of the underground gas storage in multiple salt caverns is developed, and both the thermal-hydraulic characteristic and the operating states uncertainties of the gas storage are considered. This method consists of the thermal-hydraulic analysis of the gas storage, the unit failure probability estimation, and the operating reliability assessment of the entire system. Firstly, the thermal-hydraulic analysis of the underground gas storage during the gas injection and production cycle is undertaken, which is used to obtain the operating parameters and determine whether the operational constraints are met. Thereafter, the failure criterions and the corresponding limit state functions of the salt cavern and gas injection-production well are established to calculate their failure probabilities. Finally, the reliability calculation algorithm of the k-out-of-n: G system is employed to assess the operating reliability of the gas storage in multiple caverns. Furthermore, a numerical example based on a real underground gas storage is applied to confirm the feasibility of the methodology, and the ability of the gas storage to perform the specified gas injection and production function is evaluated. The assessment results indicate that the operation scheme about the number of caverns selected to perform the required task, has a significant impact on the operating reliability of the underground gas storage.
Weichao Yu; Weihe Huang; Hongfei Liu; Kun Wang; Kai Wen; Jing Gong; Mohan Zhang. A systematic method for assessing the operating reliability of the underground gas storage in multiple salt caverns. Journal of Energy Storage 2020, 31, 101675 .
AMA StyleWeichao Yu, Weihe Huang, Hongfei Liu, Kun Wang, Kai Wen, Jing Gong, Mohan Zhang. A systematic method for assessing the operating reliability of the underground gas storage in multiple salt caverns. Journal of Energy Storage. 2020; 31 ():101675.
Chicago/Turabian StyleWeichao Yu; Weihe Huang; Hongfei Liu; Kun Wang; Kai Wen; Jing Gong; Mohan Zhang. 2020. "A systematic method for assessing the operating reliability of the underground gas storage in multiple salt caverns." Journal of Energy Storage 31, no. : 101675.
Onshore gas field gathering pipeline system (GPS) plays a key role in the onshore gas field production and is often constructed in stages due to the phased development of the gas field. However, the influence of phased development on the optimal design of GPS has been neglected in previous studies. Although some research on the optimization of gas field development strategy involves the multi-period construction of GPS, they simplify the characteristics of the gathering network and ignore some very important parameters. This study develops an integrated mixed-integer linear programming (MILP) model for optimizing multi-period GPS to determine the central processing facility (CPF) location, pipeline (routes and diameters) installation and expansions, well site-CPF connections, the flowrate of each pipeline, and the operating pressure of each node in each time period simultaneously. Taking minimum total construction cost as the objective function, the proposed model considers various operational and technical constraints related to multi-period construction and hydraulic characteristics, such as obstacles, three-dimensional terrain, pipeline topological structures, pipeline diameters, and wellhead pressure. Ant colony optimization is used for route optimization to provide parameters for the proposed model. A piecewise approximation method is employed to deal with the nonlinear terms of hydraulic equations. Therefore, the MILP model can be solved by the branch-and-bound algorithm to obtain the global optimal solution integrally. Finally, the model is successfully applied to three real-world gas fields. Compared with the actual construction scheme and other literature methods, the results prove the superiority of multi-period planning considering time.
Bingyuan Hong; Xiaoping Li; Guojia Di; Shangfei Song; Weichao Yu; Shilin Chen; Yu Li; Jing Gong. An integrated MILP model for optimal planning of multi-period onshore gas field gathering pipeline system. Computers & Industrial Engineering 2020, 146, 106479 .
AMA StyleBingyuan Hong, Xiaoping Li, Guojia Di, Shangfei Song, Weichao Yu, Shilin Chen, Yu Li, Jing Gong. An integrated MILP model for optimal planning of multi-period onshore gas field gathering pipeline system. Computers & Industrial Engineering. 2020; 146 ():106479.
Chicago/Turabian StyleBingyuan Hong; Xiaoping Li; Guojia Di; Shangfei Song; Weichao Yu; Shilin Chen; Yu Li; Jing Gong. 2020. "An integrated MILP model for optimal planning of multi-period onshore gas field gathering pipeline system." Computers & Industrial Engineering 146, no. : 106479.
Two-phase flow in pipeline network plays a significant role in the gathering system of the offshore natural gas-condensate field. However, the study of the transient numerical simulation of pipeline network is insufficient for flow assurance. Therefore, a transient simulation method is developed. The transient two-fluid model including an energy equation for two-phase flow is established firstly. Moreover, unlike pipeline, the node is an extra structure in the network. A corresponding method of discretizing the node domain and governing equations is therefore developed. In this way, the node pressure can be calculated directly rather than iteratively solved through a mass balance equation. Finally, a predict-correct two-phase flow algorithm is proposed. Moreover, a natural gas-condensate field pipeline network is applied to validate and verify the proposed method. Furthermore, a more complex network is simulated. The proposed method provides a reasonable result while the commercial code OLGA gives a divergent result.
Guoyun Shi; Di Fan; Jing Gong. A new transient simulation method of natural gas-condensate two-phase flow in pipeline network. Chemical Engineering Science 2020, 223, 115742 .
AMA StyleGuoyun Shi, Di Fan, Jing Gong. A new transient simulation method of natural gas-condensate two-phase flow in pipeline network. Chemical Engineering Science. 2020; 223 ():115742.
Chicago/Turabian StyleGuoyun Shi; Di Fan; Jing Gong. 2020. "A new transient simulation method of natural gas-condensate two-phase flow in pipeline network." Chemical Engineering Science 223, no. : 115742.
Real-time flow estimation plays a vital role in multi-product pipeline operations, and the accuracy of real-time flow estimation is affected by noise interference and instrument accuracy and cannot be performed by direct observation of flow meter. Pipeline flow models based on the first principle method are established and employed as soft sensors of pipeline real-time flow rate. However, these models are validated by the controlled experimental pipeline, which may be ineffective regarding actual pipelines with uncertain physical parameters. In this paper, a novel approach integrating data-driven and model-driven method is proposed to estimate the flow rate of petroleum products on-line. The difference between the theoretical model and actual state of a pipeline is accounted for by the friction coefficient, and on-line calibration is achieved by solving multi-objective optimisation problems with asynchronous operation data. The flow state of the pipeline is obtained in real time by the particle filter when new pressure observations with noise become available. The estimation performance of local pressure mutation points is improved by adopting the recurrent nonlinear autoregressive neural network modelling blue of the data-driven method. The effectiveness of the proposed method is evaluated blue by examining actual data of the pipeline over a period of time. The prediction results of some other model-driven and data-driven methods are also compared to blue that of the proposed method. The results blue indicate that the proposed method improves the accuracy and reliability of the product flow rate estimations even under unforeseen operation conditions.
Lei He; Kai Wen; Changchun Wu; Jing Gong; Xie Ping. Hybrid method based on particle filter and NARX for real-time flow rate estimation in multi-product pipelines. Journal of Process Control 2020, 88, 19 -31.
AMA StyleLei He, Kai Wen, Changchun Wu, Jing Gong, Xie Ping. Hybrid method based on particle filter and NARX for real-time flow rate estimation in multi-product pipelines. Journal of Process Control. 2020; 88 ():19-31.
Chicago/Turabian StyleLei He; Kai Wen; Changchun Wu; Jing Gong; Xie Ping. 2020. "Hybrid method based on particle filter and NARX for real-time flow rate estimation in multi-product pipelines." Journal of Process Control 88, no. : 19-31.
Yield stress, as the key parameter to characterize the network strength of waxy oil, is important to the petroleum pipeline safety. Reducing the yield stress of waxy oil is of great significance for flow assurance. In this study, the effect of alternating magnetic field (intensity, frequency) on the yield stress of a waxy model oil with nanocomposite pour point depressant (NPPD) is systematically investigated. An optimum magnetic field intensity and frequency is found for the reduction in yield stress. When adding with NPPD, the heterogeneous nucleation of NPPD contributes to the reduction in yield stress for waxy model oil. Interestingly, the magnetic field is helpful for the modification of yield stress at a lower frequency and intensity before the optimal value; however, the modification is found to be weakened when the magnetic field is further increased after the optimal value. Possible explanation is proposed that the aggregation morphology of wax crystal would be altered and results in the release of wrapped oil phase from the network structure under the magnetic field.
Hui-Rong Huang; Wei Wang; Ze-Heng Peng; Kai Li; Yan-Fen Ding; Wei-Jie Yu; Dong-Ying Gan; Chuan-Shuo Wang; Yi-Han Xue; Jing Gong. Synergistic effect of magnetic field and nanocomposite pour point depressant on the yield stress of waxy model oil. Petroleum Science 2020, 17, 838 -848.
AMA StyleHui-Rong Huang, Wei Wang, Ze-Heng Peng, Kai Li, Yan-Fen Ding, Wei-Jie Yu, Dong-Ying Gan, Chuan-Shuo Wang, Yi-Han Xue, Jing Gong. Synergistic effect of magnetic field and nanocomposite pour point depressant on the yield stress of waxy model oil. Petroleum Science. 2020; 17 (3):838-848.
Chicago/Turabian StyleHui-Rong Huang; Wei Wang; Ze-Heng Peng; Kai Li; Yan-Fen Ding; Wei-Jie Yu; Dong-Ying Gan; Chuan-Shuo Wang; Yi-Han Xue; Jing Gong. 2020. "Synergistic effect of magnetic field and nanocomposite pour point depressant on the yield stress of waxy model oil." Petroleum Science 17, no. 3: 838-848.