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< Page ,Total 17 >
Tri-level optimal hardening plan for a resilient distribution system considering reconfiguration and DG islanding EI SCIE Scopus
期刊论文 | 2018 , 210 , 1266-1279 | APPLIED ENERGY
WoS CC Cited Count: 6
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Abstract :

There is an increasing awareness of resilience in the face of extreme natural disasters and man-made attacks. Power system resilience includes hardening measures and operational restoration measures. These two aspects of resilience measures are innovatively combined in this paper to improve power system resilience. A tri-level defender-attacker-defender (DAD) model is built to find the best hardening plan under malicious attacks given the available defending resources and operational restoration measures for a distribution system. On the first level, the system defender makes hardening decisions. On the second level, the attacker finds the attack scenario with maximum damage. Given the hardening and attack plans, on the third level, the system operator undertakes resilient operational measures including optimal DG islanding formation and topology reconfiguration. This new model overcomes the limitations of existing DAD models by integrating these operational measures into the mathematical model; the produced hardening strategy is more practical for today's fast-developing smart distribution system. The DAD problem is formed as a tri-level mixed integer optimization problem and the Column Constraint Generation (CCG) method is adopted to accurately achieve the optimal solution. The proposed methodology is applied on an IEEE 33-bus system and a real 94-bus system. Its effectiveness is verified by numerical case studies. (C) 2017 Elsevier Ltd. All rights reserved.

Keyword :

DG Defender-attacker-defender (DAD) Distribution system Resilience

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GB/T 7714 Lin, Yanling , Bie, Zhaohong . Tri-level optimal hardening plan for a resilient distribution system considering reconfiguration and DG islanding [J]. | APPLIED ENERGY , 2018 , 210 : 1266-1279 .
MLA Lin, Yanling 等. "Tri-level optimal hardening plan for a resilient distribution system considering reconfiguration and DG islanding" . | APPLIED ENERGY 210 (2018) : 1266-1279 .
APA Lin, Yanling , Bie, Zhaohong . Tri-level optimal hardening plan for a resilient distribution system considering reconfiguration and DG islanding . | APPLIED ENERGY , 2018 , 210 , 1266-1279 .
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Integrated demand response for multi-energy load serving entity Scopus
会议论文 | 2018
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Abstract :

© 2018 IEEE. In the context of the energy internet, traditional demand response (DR) in electricity-only market has difficulty in satisfying diverse energy supplies and demands. This paper proposes an optimal multi-energy bidding strategy to maximize the total profit of the LSE considering integrated demand response (IDR). Finally, case studies have been performed to demonstrate that LSEs can benefit from the IDRs under various circumstances. Specifically, all IDR participants in the multi-energy market sending their bidding curves and capacity to LSEs according to their preferences. Then, the LSE determines the optimal bidding strategy in wholesale market as well as the amount of diverse energies.

Keyword :

Energy conversion Integrated Demand Response Load Serving Entity Multi-energy Market

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GB/T 7714 Liu, Peiyun , Ding, Tao , Bie, Zhaohong et al. Integrated demand response for multi-energy load serving entity [C] . 2018 .
MLA Liu, Peiyun et al. "Integrated demand response for multi-energy load serving entity" . (2018) .
APA Liu, Peiyun , Ding, Tao , Bie, Zhaohong , Ma, Zhoujun . Integrated demand response for multi-energy load serving entity . (2018) .
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Energy-Reserve Co-Optimization for Energy Internet Considering Reserve Control Zone Determination EI CPCI-S Scopus CSSCI-E
会议论文 | 2017 , 83-88 | 1st IEEE International Conference on Energy Internet (ICEI)
WoS CC Cited Count: 1
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Abstract :

Considering complicated existing couplings between different networks, the operating and dispatching under Energy Internet meet more difficulties. This paper presents an energy-reserve co-optimization model for Energy Internet to balance various load demand while withstand N-1 outages with the least operational cost. To address the problem of computational complexity, a reserve control zone determination method based on kruskal's algorithm has been proposed to narrow responsive reserve zone and simplify N-1 outage constraints. The energy-reserve co-optimization model with simplified N-1 outage constraints has been performed on a test energy system including IEEE 39-bus power system and a 15-node natural gas network. According to the optimal results, though the simplified method increases 7% operational cost, it can also totally reduce 27% N-1 constraints, which demonstrates the effectiveness of proposed method in improving the computation efficiency.

Keyword :

N-1 outage constraints Kruskal's algorithm reserve control zones Energy Internet energy-reserve co-optimization

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GB/T 7714 Liu, Fan , Bie, Zhaohong , Wang, Can et al. Energy-Reserve Co-Optimization for Energy Internet Considering Reserve Control Zone Determination [C] . 2017 : 83-88 .
MLA Liu, Fan et al. "Energy-Reserve Co-Optimization for Energy Internet Considering Reserve Control Zone Determination" . (2017) : 83-88 .
APA Liu, Fan , Bie, Zhaohong , Wang, Can , Ding, Tao . Energy-Reserve Co-Optimization for Energy Internet Considering Reserve Control Zone Determination . (2017) : 83-88 .
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A Two-Stage Robust Optimization for Centralized-Optimal Dispatch of Photovoltaic Inverters in Active Distribution Networks EI SCIE Scopus
期刊论文 | 2017 , 8 (2) , 744-754 | IEEE TRANSACTIONS ON SUSTAINABLE ENERGY | IF: 6.235
WoS CC Cited Count: 8
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Abstract :

Optimally dispatching photovoltaic (PV) inverters is an efficient way to avoid overvoltage in active distribution networks, which may occur in the case of the PV generation surplus load demand. Typically, the dispatching optimization objective is to identify critical PV inverters that have the most significant impact on the network voltage level. Following, it ensures the optimal set-points of both active power and reactive power for the selected inverters, guaranteeing the entire system operating constraints (e.g., the network voltage magnitude) within reasonable ranges. However, the intermittent nature of solar PV energy may affect the selection of the critical PV inverters and also the final optimal objective value. In order to address this issue, a two-stage robust centralized-optimal dispatch model is proposed in this paper to achieve a robust PV inverter dispatch solution considering the PV output uncertainties. In addition, the conic relaxation-based branch flow formulation and the column-and-constraint generation algorithm are employed to deal with the proposed robust optimization model. Case studies on a 33-bus distribution network and comparisons with the deterministic optimization approach have demonstrated the effectiveness of the proposed method.

Keyword :

Two-stage robust optimization column-and-constraint generation algorithm photovoltaic generation Active distribution network optimal inverter dispatch (OID)

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GB/T 7714 Ding, Tao , Li, Cheng , Yang, Yongheng et al. A Two-Stage Robust Optimization for Centralized-Optimal Dispatch of Photovoltaic Inverters in Active Distribution Networks [J]. | IEEE TRANSACTIONS ON SUSTAINABLE ENERGY , 2017 , 8 (2) : 744-754 .
MLA Ding, Tao et al. "A Two-Stage Robust Optimization for Centralized-Optimal Dispatch of Photovoltaic Inverters in Active Distribution Networks" . | IEEE TRANSACTIONS ON SUSTAINABLE ENERGY 8 . 2 (2017) : 744-754 .
APA Ding, Tao , Li, Cheng , Yang, Yongheng , Jiang, Jiangfeng , Bie, Zhaohong , Blaabjerg, Frede . A Two-Stage Robust Optimization for Centralized-Optimal Dispatch of Photovoltaic Inverters in Active Distribution Networks . | IEEE TRANSACTIONS ON SUSTAINABLE ENERGY , 2017 , 8 (2) , 744-754 .
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Reliability Model of MMC Considering Periodic Preventive Maintenance EI SCIE Scopus
期刊论文 | 2017 , 32 (3) , 1535-1544 | IEEE TRANSACTIONS ON POWER DELIVERY | IF: 3.35
WoS CC Cited Count: 5
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Abstract :

Periodic preventive maintenance (PPM) is a significant measure to ensure reliable operation of the modular multilevel converter (MMC), but to date has always been neglected in the reliability evaluation. A mathematical reliability model of MMC considering PPM is proposed in this paper. The model is derived rigorously by the reliability function and finally described by the indices equivalent failure rate and the forced outage rate. Two operation modes related to redundant submodules are considered and described by the standby model and k-out-of-n model, respectively. Employing this model, we can analyze the sensitivity of reliability to redundancy and maintenance interval and provide some reliability indices for planning, which is especially valuable for the offshore cases. The necessity of the considered PPM and the effectiveness of the proposed model are verified by case studies. A method to include PPM in reliability modeling is provided.

Keyword :

reliability MMC HVDC maintenance

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GB/T 7714 Wang, Biyang , Wang, Xifan , Bie, Zhaohong et al. Reliability Model of MMC Considering Periodic Preventive Maintenance [J]. | IEEE TRANSACTIONS ON POWER DELIVERY , 2017 , 32 (3) : 1535-1544 .
MLA Wang, Biyang et al. "Reliability Model of MMC Considering Periodic Preventive Maintenance" . | IEEE TRANSACTIONS ON POWER DELIVERY 32 . 3 (2017) : 1535-1544 .
APA Wang, Biyang , Wang, Xifan , Bie, Zhaohong , Judge, Paul D. , Wang, Xiuli , Green, T. C. . Reliability Model of MMC Considering Periodic Preventive Maintenance . | IEEE TRANSACTIONS ON POWER DELIVERY , 2017 , 32 (3) , 1535-1544 .
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An effective Lightning Flash Algorithm solution to large scale non-convex economic dispatch with valve-point and multiple fuel options on generation units EI SCIE Scopus
期刊论文 | 2017 , 129 , 1-15 | ENERGY | IF: 4.968
WoS CC Cited Count: 8
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Abstract :

Generation units with multiple fuel options and valve-point loading effects on the generators are fundamental parts of power system generation. However, economic dispatch (ED) of these units have non-convex, non-continuous generation cost functions. In this paper, a new Lightning Flash Algorithm (LFA) is proposed to solve complex non-convex ED problems in large scale power systems considering multiple fuel options and valve point effects on the generators. Five case study systems including 10 units, 40-units, 80-units, 160-units and 640-units are conducted to validate the applicability and effectiveness of the proposed LFA method for solving ED problems. The results are compared with other published methods in literature and confirm the applicability and effectiveness of LFA against other existing methods. LFA can successfully conduct the best fuel types of the generators and adjust the optimum settings to allocate load demand to the online generation units in power system. The results demonstrate that using proposed LFA method can minimize the total generation costs and optimally satisfy the load demands in the power grid. (C) 2017 Elsevier Ltd. All rights reserved.

Keyword :

Economic dispatch Power generation Optimization Valve-point effects Multiple fuel option

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GB/T 7714 Kheshti, Mostafa , Kang, Xiaoning , Bie, Zhaohong et al. An effective Lightning Flash Algorithm solution to large scale non-convex economic dispatch with valve-point and multiple fuel options on generation units [J]. | ENERGY , 2017 , 129 : 1-15 .
MLA Kheshti, Mostafa et al. "An effective Lightning Flash Algorithm solution to large scale non-convex economic dispatch with valve-point and multiple fuel options on generation units" . | ENERGY 129 (2017) : 1-15 .
APA Kheshti, Mostafa , Kang, Xiaoning , Bie, Zhaohong , Jiao, Zaibin , Wang, Xiuli . An effective Lightning Flash Algorithm solution to large scale non-convex economic dispatch with valve-point and multiple fuel options on generation units . | ENERGY , 2017 , 129 , 1-15 .
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Sensitivity-based relaxation and decomposition method to dynamic reactive power optimisation considering DGs in active distribution networks EI SCIE Scopus
期刊论文 | 2017 , 11 (1) , 37-48 | IET GENERATION TRANSMISSION & DISTRIBUTION | IF: 2.618
WoS CC Cited Count: 6
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Abstract :

With the development of active distribution networks, new challenges such as overvoltage and power loss become critical. The reactive power optimisation serves as a voltage control measure to minimise the total transmission loss by coordinating the continuous and discrete reactive power compensators while guaranteeing the specific physical and operating constraints. To address the daily operating times of discrete control variables, the dynamic reactive power optimisation (DRPO) is set up to minimise total energy loss over several time periods when considering the inter-temporal constraints. However, DRPO is in fact a large-scale mixed integer non-linear non-convex programming that is difficult to solve. Therefore, second-order cones are employed to relax the non-convex power flow equations to obtain a mixed integer second order cone programming model. Furthermore, a sensitivity-based relaxation and decomposition method is proposed to further improve the computational performance. Solution quality and computational performance are compared with traditional methods on IEEE-33, 123 and 615-bus systems as well as two real-world distribution networks in China. The Results demonstrate that the fast performance and effectiveness of the proposed technique.

Keyword :

IEEE-615-bus systems voltage control DG dynamic reactive power optimisation continuous reactive power compensators sensitivity-based relaxation power loss transmission loss computational performance mixed integer non-linear non-convex programming active distribution networks China integer programming concave programming nonconvex power flow equations reactive power inter-temporal constraints discrete reactive power compensators distribution networks decomposition method reactive power optimisation mixed integer second order cone programming model IEEE 615-bus systems

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GB/T 7714 Ding, Tao , Liu, Shiyu , Wu, Zhongyu et al. Sensitivity-based relaxation and decomposition method to dynamic reactive power optimisation considering DGs in active distribution networks [J]. | IET GENERATION TRANSMISSION & DISTRIBUTION , 2017 , 11 (1) : 37-48 .
MLA Ding, Tao et al. "Sensitivity-based relaxation and decomposition method to dynamic reactive power optimisation considering DGs in active distribution networks" . | IET GENERATION TRANSMISSION & DISTRIBUTION 11 . 1 (2017) : 37-48 .
APA Ding, Tao , Liu, Shiyu , Wu, Zhongyu , Bie, Zhaohong . Sensitivity-based relaxation and decomposition method to dynamic reactive power optimisation considering DGs in active distribution networks . | IET GENERATION TRANSMISSION & DISTRIBUTION , 2017 , 11 (1) , 37-48 .
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Day-ahead optimal dispatch for wind integrated power system considering zonal reserve requirements SCIE Scopus
期刊论文 | 2017 , 188 , 399-408 | APPLIED ENERGY | IF: 7.9
WoS CC Cited Count: 12
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Abstract :

Large-scale integration of renewable power presents a great challenge for day-ahead dispatch to manage renewable resources while provide available reserve for system security. Considering zonal reserve is an effective way to ensure reserve deliverability when network congested, a random day-ahead dispatch optimization of wind integrated power system for a least operational cost is modeled including zonal reserve requirements and N - 1 security constraints. The random model is transformed into a deterministic one based on the theory of chance constrained programming and a determination method of optimal zonal reserve demand is proposed using the minimum confidence interval. After solving the deterministic model, the stochastic simulation is conducted to verify the validity of solution. Numerical tests and results on the IEEE 39 bus system and a large-scale real-life power system demonstrate the optimal day-ahead dispatch scheme is available and the proposed method is effective for improving reserve deliverability and reducing load shedding after large-capacity power outage. (C) 2016 Elsevier Ltd. All rights reserved.

Keyword :

Day-ahead optimal dispatch Zonal reserve requirements N-1 security constrains Stochastic programming Wind integrated power system

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GB/T 7714 Liu, Fan , Bie, Zhaohong , Liu, Shiyu et al. Day-ahead optimal dispatch for wind integrated power system considering zonal reserve requirements [J]. | APPLIED ENERGY , 2017 , 188 : 399-408 .
MLA Liu, Fan et al. "Day-ahead optimal dispatch for wind integrated power system considering zonal reserve requirements" . | APPLIED ENERGY 188 (2017) : 399-408 .
APA Liu, Fan , Bie, Zhaohong , Liu, Shiyu , Ding, Tao . Day-ahead optimal dispatch for wind integrated power system considering zonal reserve requirements . | APPLIED ENERGY , 2017 , 188 , 399-408 .
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Microgrids for Enhancing the Power Grid Resilience in Extreme Conditions EI SCIE Scopus
期刊论文 | 2017 , 8 (2) , 589-597 | IEEE TRANSACTIONS ON SMART GRID | IF: 7.364
WoS CC Cited Count: 20
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Abstract :

This paper presents a framework for analyzing the resilience of an electric power grid with integrated microgrids in extreme conditions. The objective of this paper is to demonstrate that controllable and islandable microgrids can help improve the resiliency of power grids in extreme conditions. Four resilience indices are introduced to measure the impact of extreme events. Index K measures the expected number of lines on outage due to extreme events. Index loss of load probability measures the probability of load not being fully supplied. Index expected demand not supplied measures the expected demand that cannot be supplied. Index G measures the difficulty level of grid recovery. The mechanism of extreme events affecting power grid operation is analyzed based on the proposed mesh grid approach. The relationship among transmission grid, distribution grid, and microgrid in extreme conditions is discussed. The Markov chain is utilized to represent the state transition of a power grid with integrated microgrids in extreme conditions. The Monte Carlo method is employed to calculate the resilience indices. The proposed power grid resilience analysis framework is demonstrated using the IEEE 30-bus and 118-bus systems assuming all loads are within microgrids.

Keyword :

extreme events microgrids resilience Power system operation

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GB/T 7714 Liu, Xindong , Shahidehpour, Mohammad , Li, Zuyi et al. Microgrids for Enhancing the Power Grid Resilience in Extreme Conditions [J]. | IEEE TRANSACTIONS ON SMART GRID , 2017 , 8 (2) : 589-597 .
MLA Liu, Xindong et al. "Microgrids for Enhancing the Power Grid Resilience in Extreme Conditions" . | IEEE TRANSACTIONS ON SMART GRID 8 . 2 (2017) : 589-597 .
APA Liu, Xindong , Shahidehpour, Mohammad , Li, Zuyi , Liu, Xuan , Cao, Yijia , Bie, Zhaohong . Microgrids for Enhancing the Power Grid Resilience in Extreme Conditions . | IEEE TRANSACTIONS ON SMART GRID , 2017 , 8 (2) , 589-597 .
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A Geometric Programming to Importance Sampling for Power System Reliability Evaluation EI SCIE Scopus
期刊论文 | 2017 , 32 (2) , 1568-1569 | IEEE TRANSACTIONS ON POWER SYSTEMS | IF: 5.255
WoS CC Cited Count: 1
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Abstract :

A novel Geometric Programming (GP) is presented in the first time by the optimization model of importance sampling parameters (ISP) in Variance Minimization (VM) for importance sampling (IS) of power system reliability evaluation. The key point of the proposed method is that the equality constraints of VM optimization model can be relaxed into inequalities because of its special structure, thus a new GP-VM convex optimization model can be built exactly to solve the difficulty of obtaining the optimal ISP. Numerical results of two test systems verify the effectiveness of the proposed method.

Keyword :

variance minimization (VM) Geometric programming (GP) power system reliability importance sampling (IS)

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GB/T 7714 Yan, Chao , Ding, Tao , Bie, Zhaohong et al. A Geometric Programming to Importance Sampling for Power System Reliability Evaluation [J]. | IEEE TRANSACTIONS ON POWER SYSTEMS , 2017 , 32 (2) : 1568-1569 .
MLA Yan, Chao et al. "A Geometric Programming to Importance Sampling for Power System Reliability Evaluation" . | IEEE TRANSACTIONS ON POWER SYSTEMS 32 . 2 (2017) : 1568-1569 .
APA Yan, Chao , Ding, Tao , Bie, Zhaohong , Wang, Xifan . A Geometric Programming to Importance Sampling for Power System Reliability Evaluation . | IEEE TRANSACTIONS ON POWER SYSTEMS , 2017 , 32 (2) , 1568-1569 .
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