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Lianghui Guo; Yuan Xu; Yi Wang; Yongtu Liang. Modeling the solubility of CO2 in aqueous solutions of MDEA using the electrolyte–UNIQUAC and simplified-Kent-Eisenberg model. 2021, 1 .
AMA StyleLianghui Guo, Yuan Xu, Yi Wang, Yongtu Liang. Modeling the solubility of CO2 in aqueous solutions of MDEA using the electrolyte–UNIQUAC and simplified-Kent-Eisenberg model. . 2021; ():1.
Chicago/Turabian StyleLianghui Guo; Yuan Xu; Yi Wang; Yongtu Liang. 2021. "Modeling the solubility of CO2 in aqueous solutions of MDEA using the electrolyte–UNIQUAC and simplified-Kent-Eisenberg model." , no. : 1.
The steady-state hydraulic and thermal simulation of the gas gathering pipeline network with predicting methods of natural gas hydrates are discussed in this paper. Compressors, valves, heating furnaces and other equipment in pipeline network are also considered. Nodal analysis method accompanied by the linear approximation is implemented to solve the hydro thermal simulation equations. Chen-Guo model is used for calculating hydrate phase equilibria and secant line method is applied to solve this model. Steady-state simulation and hydrate prediction results of the pipeline network are compared with the calculation results of TGNET and literature respectively. The results show the effectiveness and accuracy of the pipeline network steady-state simulation and hydrate prediction methods.
Yuan Xu; Bowen Ren; Wei Zhao; Feng Xu; Yi Wang; Yongtu Liang. Preliminary Study on Integrated Simulation of Natural Gas Gathering Pipeline Network. Mechanical Engineering and Materials 2020, 287 -300.
AMA StyleYuan Xu, Bowen Ren, Wei Zhao, Feng Xu, Yi Wang, Yongtu Liang. Preliminary Study on Integrated Simulation of Natural Gas Gathering Pipeline Network. Mechanical Engineering and Materials. 2020; ():287-300.
Chicago/Turabian StyleYuan Xu; Bowen Ren; Wei Zhao; Feng Xu; Yi Wang; Yongtu Liang. 2020. "Preliminary Study on Integrated Simulation of Natural Gas Gathering Pipeline Network." Mechanical Engineering and Materials , no. : 287-300.
In the mid to late stages of gas field development, new blocks would be added to the existing gas gathering system (GGS) for stable production. Consequently, new compressor stations (CSs) and pipelines should be constructed to adjust the original gas pipeline networks (GPNs) for minimizing energy consumption. In this paper, an optimal design framework for GPNs is developed considering the future production capacity expansion and possible extensions of the pipeline network structures. The objective function of the present study includes investment and operating costs. A two-stage hybrid algorithm which is composed of a modified genetic algorithm (MGA) and a modified particle swarm optimization (MPSO) algorithm is proposed to solve this problem. The MGA is first used for layout optimization of new pipelines and then MPSO is employed to determine the design variables, including the diameter of each pipeline, the locations of new CSs, and the optimal operation conditions of compressor facilities. This method can also give the reconstruction scheme of the built CSs. Finally, a real pipeline network of a gas field in China is studied, size and operation conditions are optimized. The results illustrate that the model can tackle complex gas network reconstruction problems, and there is a 3.68% decrease in the total costs compared to the design scheme without modification of the original CSs.
Yuan Xu; Wei Zhao; Bowen Ren; Bohong Wang; Yi Wang; Yongtu Liang. Optimal Design of Natural Gas Gathering Systems with Production Capacity Expansion. Mechanical Engineering and Materials 2020, 258 -275.
AMA StyleYuan Xu, Wei Zhao, Bowen Ren, Bohong Wang, Yi Wang, Yongtu Liang. Optimal Design of Natural Gas Gathering Systems with Production Capacity Expansion. Mechanical Engineering and Materials. 2020; ():258-275.
Chicago/Turabian StyleYuan Xu; Wei Zhao; Bowen Ren; Bohong Wang; Yi Wang; Yongtu Liang. 2020. "Optimal Design of Natural Gas Gathering Systems with Production Capacity Expansion." Mechanical Engineering and Materials , no. : 258-275.
The natural gas purification plant is the upstream of the natural gas supply chain. Its operating parameters have an important influence on natural gas supply chain system analysis, pipeline scheduling, inventory management and other aspects of the natural gas supply chain. Energy Performance Index (EnPI) is introduced in this paper to judge the energy consumption of the purification plant. A detailed model is developed by Aspen HYSYS. The operating variables are optimized by the particle swarm algorithm, and then the operating variables are input into the model to calculate the unit energy consumption of the purification plant. Through the optimization, the purification plant can be operated with low energy consumption.
Yuan Xu; Yang Zhang; Lianghui Guo; Yi Wang; Yongtu Liang. Operating Parameters Optimization of Natural Gas Purification Plant. Mechanical Engineering and Materials 2020, 276 -286.
AMA StyleYuan Xu, Yang Zhang, Lianghui Guo, Yi Wang, Yongtu Liang. Operating Parameters Optimization of Natural Gas Purification Plant. Mechanical Engineering and Materials. 2020; ():276-286.
Chicago/Turabian StyleYuan Xu; Yang Zhang; Lianghui Guo; Yi Wang; Yongtu Liang. 2020. "Operating Parameters Optimization of Natural Gas Purification Plant." Mechanical Engineering and Materials , no. : 276-286.
Long-distance pipelines transporting multiple product oils such as gasoline, diesel and jet fuel, are important facilities for transporting fossil energy. One major concern in operation is the energy consumption of the pipeline. Energy consumption should be made optimized tracking batches of oils and cutting mixed oil, which requires an accurate prediction of concentration curve. In engineering, the concentration curve is usually assumed to be symmetric, but it is actually asymmetric, which may lead to estimation errors. Thus, the asymmetric concentration of mixed oil should be studied. The formation mechanism of the asymmetry of concentration curve has not been clearly clarified. A new method is proposed to measure the asymmetry of the concentration curve. Quantitative analysis is carried out for each factor on the asymmetry distribution of concentration curve. Based on the convection–diffusion equation, a modified oil-mixing model considering near wall adsorption effect is established. The model shows a good agreement with the Jablonski empirical formula. The error, compared with the experimental results, is less than 5%. The main findings are: (1) deviation volume has a negative correlation with pipe diameter and mean velocity; (2) adsorption coefficient has a greater impact on the length ratio of front and tail oil than diffusion coefficient; (3) the influence of all factors considered on the total length of mixed oil, front oil, tail oil and trail oil are basically the same; (4) if the limit of adsorption concentration in adsorption layer is 1, the reasonable value of adsorption coefficient a and b should be around 0.4. The results reveal the mechanism of asymmetric concentration of product oils and can provide practical suggestions to deal with the mixed oil.
Yi Wang; Baoying Wang; Yang Liu; Yongtu Liang. Study on Asymmetry Concentration of Mixed Oil in Products Pipeline. Energies 2020, 13, 6398 .
AMA StyleYi Wang, Baoying Wang, Yang Liu, Yongtu Liang. Study on Asymmetry Concentration of Mixed Oil in Products Pipeline. Energies. 2020; 13 (23):6398.
Chicago/Turabian StyleYi Wang; Baoying Wang; Yang Liu; Yongtu Liang. 2020. "Study on Asymmetry Concentration of Mixed Oil in Products Pipeline." Energies 13, no. 23: 6398.
Due to the interaction and corrosion of the seawater, submarine pipelines are easy to be broken to spill oil. The special environment of subsea restricts the technical development of pipeline maintenance. Therefore, the study on the oil spilling model of submarine pipeline is very important for predicting the movement and diffusion of spilled oil, so that oil spilling traces and relating strategies can be determined. This paper aims to establish an oil spilling model of a submarine pipeline, study the movement characteristics of spilled oil in seawater by numerical simulation, and determine the traces, diffusion range, time to sea surface, etc. Then, the maximum horizontal migration distance (MHMD) with corresponding time are analyzed under different oil densities, spilling speeds and seawater velocities. Results show that the MHMD decreases first and then increases while the time to achieve the MHMD increases along with increasing oil density. The MHMD increases while the time to achieve the MHMD decreases, along with increasing spilling speed. Both the MHMD and corresponding time increase along with increasing seawater velocity. Based on numerical results, a correlation of spilling distance and spilling time is proposed to give fast and accurate predictions. After the oil reaches sea surface, oil expansion and transport are simulated. Euler-Lagrange method is used in the simulation. Dynamic and non-dynamic factors are considered. Results show that wind velocity and water velocity are dominant in dynamic factors. When they are large, spilled oil moves very fast with variable directions in complex flow field. Nondynamic factors such as evaporation, emulsion and solution mainly reduce the volume of oil film. They almost do not affect the direction and displacement of spilled oil. Quick response should be made for large wind and water velocities when the placement of oil boom is given. With the correlation and simulation, emergency responses can be guided effectively to reduce the impact of submarine oil pollution. The computational results benefit pollution control and environmental protection in marine petroleum engineering.
Yi Wang; Mohan Lin. Numerical Simulation on Oil Spilling of Submarine Pipeline and Its Evolution on Sea Surface. Computer Modeling in Engineering & Sciences 2020, 124, 885 -914.
AMA StyleYi Wang, Mohan Lin. Numerical Simulation on Oil Spilling of Submarine Pipeline and Its Evolution on Sea Surface. Computer Modeling in Engineering & Sciences. 2020; 124 (3):885-914.
Chicago/Turabian StyleYi Wang; Mohan Lin. 2020. "Numerical Simulation on Oil Spilling of Submarine Pipeline and Its Evolution on Sea Surface." Computer Modeling in Engineering & Sciences 124, no. 3: 885-914.
Viscoelasticity drag-reducing flow by polymer solution can reduce pumping energy of pipe flow significantly. One of the simulation manners is direct numerical simulation (DNS). However, the computational time is too long to accept in engineering. Turbulent model is a powerful tool to solve engineering problems because of its fast computational ability. However, its precision is usually low. To solve this problem, we introduce DNS to provide accurate data to construct a high-precision turbulent model. A Reynolds stress model for viscoelastic polymer drag-reducing flow is established. The rheological behavior of the drag-reducing flow is described by the Giesekus constitutive Equation. Compared with the DNS data, mean velocity, mean conformation tensor, drag reduction, and stresses are predicted accurately in low Reynolds numbers and Weissenberg numbers but worsen as the two numbers increase. The computational time of the Reynolds stress model (RSM) is only 1/120,960 of DNS, showing the advantage of computational speed.
Yi Wang; Wang. Reynolds Stress Model for Viscoelastic Drag-Reducing Flow Induced by Polymer Solution. Polymers 2019, 11, 1659 .
AMA StyleYi Wang, Wang. Reynolds Stress Model for Viscoelastic Drag-Reducing Flow Induced by Polymer Solution. Polymers. 2019; 11 (10):1659.
Chicago/Turabian StyleYi Wang; Wang. 2019. "Reynolds Stress Model for Viscoelastic Drag-Reducing Flow Induced by Polymer Solution." Polymers 11, no. 10: 1659.
Drag reduction by polymer is an important energy-saving technology, which can reduce pumping pressure or promote the flow rate of the pipelines transporting fluid. It has been widely applied to single-phase pipelines, such as oil pipelining, district heating systems, and firefighting. However, the engineering application of the drag reduction technology in two-phase flow systems has not been reported. The reason is an unrevealed complex mechanism of two-phase drag reduction and lack of numerical tools for mechanism study. Therefore, we aim to propose governing equations and numerical methods of direct numerical simulation (DNS) for two-phase gas-liquid drag-reducing flow and try to explain the reason for the two-phase drag reduction. Efficient interface tracking method—coupled volume-of-fluid and level set (VOSET) and typical polymer constitutive model Giesekus are combined in the momentum equation of the two-phase turbulent flow. Interface smoothing for conformation tensor induced by polymer is used to ensure numerical stability of the DNS. Special features and corresponding explanations of the two-phase gas-liquid drag-reducing flow are found based on DNS results. High shear in a high Reynolds number flow depresses the efficiency of the gas-liquid drag reduction, while a high concentration of polymer promotes the efficiency. To guarantee efficient drag reduction, it is better to use a high concentration of polymer drag-reducing agents (DRAs) for high shear flow.
Yi Wang; Yan Wang; Zhe Cheng. Direct Numerical Simulation of Gas-Liquid Drag-Reducing Cavity Flow by the VOSET Method. Polymers 2019, 11, 596 .
AMA StyleYi Wang, Yan Wang, Zhe Cheng. Direct Numerical Simulation of Gas-Liquid Drag-Reducing Cavity Flow by the VOSET Method. Polymers. 2019; 11 (4):596.
Chicago/Turabian StyleYi Wang; Yan Wang; Zhe Cheng. 2019. "Direct Numerical Simulation of Gas-Liquid Drag-Reducing Cavity Flow by the VOSET Method." Polymers 11, no. 4: 596.
In this paper, we firstly study numerical methods for gas flow simulation in dual-continuum porous media. Typical methods for oil flow simulation in dual-continuum porous media cannot be used straightforward to this kind of simulation due to the artificial mass loss caused by the compressibility and the non-robustness caused by the non-linear source term. To avoid these two problems, corrected numerical methods are proposed using mass balance equations and local linearization of the non-linear source term. The improved numerical methods are successful for the computation of gas flow in the double-porosity double-permeability porous media. After this improvement, temporal advancement for each time step includes three fractional steps: (i) advance matrix pressure and fracture pressure using the typical computation; (ii) solve the mass balance equation system for mean pressures; (iii) correct pressures in (i) by mean pressures in (ii). Numerical results show that mass conservation of gas for the whole domain is guaranteed while the numerical computation is robust.
Yi Wang; Shuyu Sun; Liang Gong. Study on Numerical Methods for Gas Flow Simulation Using Double-Porosity Double-Permeability Model. Computer Vision 2018, 129 -138.
AMA StyleYi Wang, Shuyu Sun, Liang Gong. Study on Numerical Methods for Gas Flow Simulation Using Double-Porosity Double-Permeability Model. Computer Vision. 2018; ():129-138.
Chicago/Turabian StyleYi Wang; Shuyu Sun; Liang Gong. 2018. "Study on Numerical Methods for Gas Flow Simulation Using Double-Porosity Double-Permeability Model." Computer Vision , no. : 129-138.
High-precision and high-speed reservoir simulation is important in engineering. Proper orthogonal decomposition (POD) is introduced to accelerate the reservoir simulation of gas flow in single-continuum porous media via establishing a reduced-order model by POD combined with Galerkin projection. Determination of the optimal mode number in the reduced-order model is discussed to ensure high-precision reconstruction with large acceleration. The typical POD model can achieve high precision for both ideal gas and real gas using only 10 POD modes. However, acceleration of computation can only be achieved for ideal gas. The obstacle of POD acceleration for real gas is that the computational time is mainly occupied by the equation of state (EOS). An approximation method is proposed to largely promote the computational speed of the POD model for real gas flow without decreasing the precision. The improved POD model shows much higher acceleration of computation with high precision for different reservoirs and different pressures. It is confirmed that the acceleration of the real gas reservoir simulation should use the approximation method instead of the computation of EOS.
Yi Wang; Bo Yu; Ye Wang. Acceleration of Gas Reservoir Simulation Using Proper Orthogonal Decomposition. Geofluids 2018, 2018, 1 -15.
AMA StyleYi Wang, Bo Yu, Ye Wang. Acceleration of Gas Reservoir Simulation Using Proper Orthogonal Decomposition. Geofluids. 2018; 2018 ():1-15.
Chicago/Turabian StyleYi Wang; Bo Yu; Ye Wang. 2018. "Acceleration of Gas Reservoir Simulation Using Proper Orthogonal Decomposition." Geofluids 2018, no. : 1-15.
Amgad Salama; Shuyu Sun; Mohamed El-Amin; Yi Wang; Kundan Kumar. Flow and Transport in Porous Media: A Multiscale Focus. Geofluids 2017, 2017, 1 -3.
AMA StyleAmgad Salama, Shuyu Sun, Mohamed El-Amin, Yi Wang, Kundan Kumar. Flow and Transport in Porous Media: A Multiscale Focus. Geofluids. 2017; 2017 ():1-3.
Chicago/Turabian StyleAmgad Salama; Shuyu Sun; Mohamed El-Amin; Yi Wang; Kundan Kumar. 2017. "Flow and Transport in Porous Media: A Multiscale Focus." Geofluids 2017, no. : 1-3.
Reduced-order modeling approaches for gas flow in dual-porosity dual-permeability porous media are studied based on the proper orthogonal decomposition (POD) method combined with Galerkin projection. The typical modeling approach for non-porous-medium liquid flow problems is not appropriate for this compressible gas flow in a dual-continuum porous media. The reason is that non-zero mass transfer for the dual-continuum system can be generated artificially via the typical POD projection, violating the mass-conservation nature and causing the failure of the POD modeling. A new POD modeling approach is proposed considering the mass conservation of the whole matrix fracture system. Computation can be accelerated as much as 720 times with high precision (reconstruction errors as slow as 7.69 × 10−4%~3.87% for the matrix and 8.27 × 10−4%~2.84% for the fracture).
Yi Wang; Shuyu Sun; Bo Yu. Acceleration of Gas Flow Simulations in Dual-Continuum Porous Media Based on the Mass-Conservation POD Method. Energies 2017, 10, 1380 .
AMA StyleYi Wang, Shuyu Sun, Bo Yu. Acceleration of Gas Flow Simulations in Dual-Continuum Porous Media Based on the Mass-Conservation POD Method. Energies. 2017; 10 (9):1380.
Chicago/Turabian StyleYi Wang; Shuyu Sun; Bo Yu. 2017. "Acceleration of Gas Flow Simulations in Dual-Continuum Porous Media Based on the Mass-Conservation POD Method." Energies 10, no. 9: 1380.
Velocity of fluid flow in underground porous media is 6~12 orders of magnitudes lower than that in pipelines. If numerical errors are not carefully controlled in this kind of simulations, high distortion of the final results may occur [1–4]. To fit the high accuracy demands of fluid flow simulations in porous media, traditional finite difference methods and numerical integration methods are discussed and corresponding high-accurate methods are developed. When applied to the direct calculation of full-tensor permeability for underground flow, the high-accurate finite difference method is confirmed to have numerical error as low as 10–5% while the high-accurate numerical integration method has numerical error around 0%. Thus, the approach combining the high-accurate finite difference and numerical integration methods is a reliable way to efficiently determine the characteristics of general full-tensor permeability such as maximum and minimum permeability components, principal direction and anisotropic ratio.
Yi Wang; Shuyu Sun. Direct Calculation of Permeability by High-Accurate Finite Difference and Numerical Integration Methods. Communications in Computational Physics 2016, 20, 405 -440.
AMA StyleYi Wang, Shuyu Sun. Direct Calculation of Permeability by High-Accurate Finite Difference and Numerical Integration Methods. Communications in Computational Physics. 2016; 20 (2):405-440.
Chicago/Turabian StyleYi Wang; Shuyu Sun. 2016. "Direct Calculation of Permeability by High-Accurate Finite Difference and Numerical Integration Methods." Communications in Computational Physics 20, no. 2: 405-440.