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Advances in Power System Operations and Planning
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Advances in Power System Operations and Planning

A special issue of Energies (ISSN 1996-1073).

Deadline for manuscript submissions: closed (30 November 2016) | Viewed by 97598

Special Issue Editor

Prof. Dr. Gianfranco Chicco

E-Mail Website
Guest Editor
Department of Energy, Politecnico di Torino, Torino, Italy
Interests: power systems analysis; distribution system optimization; distributed generation; energy management; energy efficiency; power system reliability; microgrids optimization; cogeneration; multi-energy systems; distributed systems; energy systems, storage
Special Issues, Collections and Topics in MDPI journals

Special Issue Information

Dear Colleagues,

it is my pleasure to introduce a Special Issue of Energies on "Power Systems Operations and Planning", and to invite interested authors to upload original contributions on the related topics.

Power systems are living in an era of major changes, pushed forward by the emergence of new technical issues and the availability of innovative technologies, enabling new functions for monitoring and control of transmission network operation and stability. The widespread diffusion of Distributed Energy Resources (DER), involving local generation, storage and demand, has reached considerable levels, and their effects are heavily impacting the operation of transmission systems. The increasing amount of generation connected to the grid with power electronic converters is reducing system inertia, causing higher variations in system frequency, and reducing short circuit capacity. Furthermore, operational practices have to take into account the effects of the variable energy generation mix and the related uncertainties. New opportunities are provided by information and communication technologies, handling a huge amount of data gathered from the bulk power system, yet also facing cyber-security issues. Power system planning has to cope with restrictions for the installation of new infrastructure, and a more uncertain definition of planning scenarios, including DER and large generation plants (including decommissioning of traditional plants). Contributions for this Special Issue are expected to address the most advanced topics referring to today’s power system operation and control practices, and emergent planning strategies.

The main topics of interest for this Special Issue include, but are not limited to:

  • Effects of large-scale integration of distributed resources on the short circuit capacity in transmission systems
  • Frequency control in low-inertia systems
  • Effects of uncertainty on power systems operations
  • Mitigation of oscillations in transmission networks by using storage and demand
  • Control of HVDC grids and links
  • Security-constrained stochastic scheduling
  • Risk-based identification of reserve margins and definition of the operating reserves
  • Information and communications systems, SCADA and decision-making tools in control centers
  • Wide area control and protection
  • Vulnerability and security of power system infrastructure and communications
  • Reliability and maintenance scheduling of power system components
  • Transmission system planning under uncertainty
  • Joint expansion planning of power systems and other energy networks
  • Reserve planning

Prof. Dr. Gianfranco Chicco
Guest Editor

Manuscript Submission Information

Manuscripts should be submitted online at www.mdpi.com by registering and logging in to this website. Once you are registered, click here to go to the submission form. Manuscripts can be submitted until the deadline. All submissions that pass pre-check are peer-reviewed. Accepted papers will be published continuously in the journal (as soon as accepted) and will be listed together on the special issue website. Research articles, review articles as well as short communications are invited. For planned papers, a title and short abstract (about 100 words) can be sent to the Editorial Office for announcement on this website.

Submitted manuscripts should not have been published previously, nor be under consideration for publication elsewhere (except conference proceedings papers). All manuscripts are thoroughly refereed through a single-blind peer-review process. A guide for authors and other relevant information for submission of manuscripts is available on the Instructions for Authors page. Energies is an international peer-reviewed open access semimonthly journal published by MDPI.

Please visit the Instructions for Authors page before submitting a manuscript. The Article Processing Charge (APC) for publication in this open access journal is 2600 CHF (Swiss Francs). Submitted papers should be well formatted and use good English. Authors may use MDPI's English editing service prior to publication or during author revisions.

Keywords

  • power system operation
  • power system planning
  • transmission systems
  • smart grid
  • wide area control
  • frequency control
  • low inertia systems
  • power system stability
  • distributed energy resources
  • uncertainty
  • operating reserves
  • security
  • stochastic modeling

Published Papers (17 papers)

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Research

6685 KiB  
Article
System-Level Operational and Adequacy Impact Assessment of Photovoltaic and Distributed Energy Storage, with Consideration of Inertial Constraints, Dynamic Reserve and Interconnection Flexibility
by Lingxi Zhang, Yutian Zhou, Damian Flynn, Joseph Mutale and Pierluigi Mancarella
Energies 2017, 10(7), 989; https://doi.org/10.3390/en10070989 - 13 Jul 2017
Cited by 18 | Viewed by 6716
Abstract
The growing penetration of solar photovoltaic (PV) systems requires a fundamental understanding of its impact at a system-level. Furthermore, distributed energy storage (DES) technologies, such as batteries, are attracting great interest owing to their ability to provide support to systems with large-scale renewable [...] Read more.
The growing penetration of solar photovoltaic (PV) systems requires a fundamental understanding of its impact at a system-level. Furthermore, distributed energy storage (DES) technologies, such as batteries, are attracting great interest owing to their ability to provide support to systems with large-scale renewable generation, such as PV. In this light, the system-level impacts of PV and DES are assessed from both operational and adequacy perspectives. Different control strategies for DES are proposed, namely: (1) centralised, to support system operation in the presence of increasing requirements on system ramping and frequency control; and (2) decentralised, to maximise the harnessing of solar energy from individual households while storing electricity generated by PV panels to provide system capacity on request. The operational impacts are assessed by deploying a multi-service unit commitment model with consideration of inertial constraints, dynamic reserve allocation, and interconnection flexibility, while the impacts on adequacy of supply are analysed by assessing the capacity credit of PV and DES through different metrics. The models developed are then applied to different future scenarios for the Great Britain power system, whereby an electricity demand increase due to electrification is also considered. The numerical results highlight the importance of interconnectors to provide flexibility. On the other hand, provision of reserves, as opposed to energy arbitrage, from DES that are integrated into system operation is seen as the most effective contribution to improve system performance, which in turn also decreases the role of interconnectors. DES can also contribute to providing system capacity, but to an extent that is limited by their individual and aggregated energy availability under different control strategies. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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2453 KiB  
Article
Synchronization of Low-Frequency Oscillation in Power Systems
by Kwan-Shik Shim, Seon-Ju Ahn and Joon-Ho Choi
Energies 2017, 10(4), 558; https://doi.org/10.3390/en10040558 - 19 Apr 2017
Cited by 9 | Viewed by 4601
Abstract
This paper presents the well-documented concept of synchronization of low frequency oscillation occurring in power systems and describes the characteristics of sync occurring in basic electrical circuits. The theory of sync, observed in basic circuits, is extended to analyze the dynamic characteristics of [...] Read more.
This paper presents the well-documented concept of synchronization of low frequency oscillation occurring in power systems and describes the characteristics of sync occurring in basic electrical circuits. The theory of sync, observed in basic circuits, is extended to analyze the dynamic characteristics of low-frequency oscillation in power systems. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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3079 KiB  
Article
Risk-Based Dynamic Security Assessment for Power System Operation and Operational Planning
by Emanuele Ciapessoni, Diego Cirio, Stefano Massucco, Andrea Morini, Andrea Pitto and Federico Silvestro
Energies 2017, 10(4), 475; https://doi.org/10.3390/en10040475 - 01 Apr 2017
Cited by 24 | Viewed by 4431
Abstract
Assessment of dynamic stability in a modern power system (PS) is becoming a stringent requirement both in operational planning and in on-line operation, due to the increasingly complex dynamics of a PS. Further, growing uncertainties in forecast state and in the response to [...] Read more.
Assessment of dynamic stability in a modern power system (PS) is becoming a stringent requirement both in operational planning and in on-line operation, due to the increasingly complex dynamics of a PS. Further, growing uncertainties in forecast state and in the response to disturbances suggests the adoption of risk-based approaches in Dynamic Security Assessment (DSA). The present paper describes a probabilistic risk-based DSA, which provides instability risk indicators by combining an innovative probabilistic hazard/vulnerability analysis with the assessment of contingency impacts via time domain simulation. The tool implementing the method can be applied to both current and forecast PS states, the latter characterized in terms of renewable and load forecast uncertainties, providing valuable results for operation and operational planning contexts. Some results from a real PS model are discussed. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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5480 KiB  
Article
Spatial and Temporal Wind Power Forecasting by Case-Based Reasoning Using Big-Data
by Fabrizio De Caro, Alfredo Vaccaro and Domenico Villacci
Energies 2017, 10(2), 252; https://doi.org/10.3390/en10020252 - 20 Feb 2017
Cited by 8 | Viewed by 4733
Abstract
The massive penetration of wind generators in electrical power systems asks for effective wind power forecasting tools, which should be high reliable, in order to mitigate the effects of the uncertain generation profiles, and fast enough to enhance power system operation. To address [...] Read more.
The massive penetration of wind generators in electrical power systems asks for effective wind power forecasting tools, which should be high reliable, in order to mitigate the effects of the uncertain generation profiles, and fast enough to enhance power system operation. To address these two conflicting objectives, this paper advocates the role of knowledge discovery from big-data, by proposing the integration of adaptive Case Based Reasoning models, and cardinality reduction techniques based on Partial Least Squares Regression, and Principal Component Analysis. The main idea is to learn from a large database of historical climatic observations, how to solve the windforecasting problem, avoiding complex and time-consuming computations. To assess the benefits derived by the application of the proposed methodology in complex application scenarios, the experimental results obtained in a real case study will be presented and discussed. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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1590 KiB  
Article
Stochastic and Deterministic Unit Commitment Considering Uncertainty and Variability Reserves for High Renewable Integration
by Ilias G. Marneris, Pandelis N. Biskas and Anastasios G. Bakirtzis
Energies 2017, 10(1), 140; https://doi.org/10.3390/en10010140 - 23 Jan 2017
Cited by 31 | Viewed by 6822
Abstract
The uncertain and variable nature of renewable energy sources in modern power systems raises significant challenges in achieving the dual objective of reliable and economically efficient system operation. To address these challenges, advanced scheduling strategies have evolved during the past years, including the [...] Read more.
The uncertain and variable nature of renewable energy sources in modern power systems raises significant challenges in achieving the dual objective of reliable and economically efficient system operation. To address these challenges, advanced scheduling strategies have evolved during the past years, including the co-optimization of energy and reserves under deterministic or stochastic Unit Commitment (UC) modeling frameworks. This paper presents different deterministic and stochastic day-ahead UC formulations, with focus on the determination, allocation and deployment of reserves. An explicit distinction is proposed between the uncertainty and the variability reserve, capturing the twofold nature of renewable generation. The concept of multi-timing scheduling is proposed and applied in all UC policies, which allows for the optimal procurement of such reserves based on intra-hourly (real-time) intervals, when concurrently optimizing energy and commitments over hourly intervals. The day-ahead scheduling results are tested against different real-time dispatch regimes, with none or limited look-ahead capability, or with the use of the variability reserve, utilizing a modified version of the Greek power system. The results demonstrate the enhanced reliability achieved by applying the multi-timing scheduling concept and explicitly considering the variability reserve, and certain features regarding the allocation and deployment of reserves are discussed. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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4839 KiB  
Article
Integration of Lithium-Ion Battery Storage Systems in Hydroelectric Plants for Supplying Primary Control Reserve
by Fabio Bignucolo, Roberto Caldon, Massimiliano Coppo, Fabio Pasut and Martino Pettinà
Energies 2017, 10(1), 98; https://doi.org/10.3390/en10010098 - 14 Jan 2017
Cited by 24 | Viewed by 7771
Abstract
The ever-growing diffusion of renewables as electrical generation sources is forcing the electrical power system to face new and challenging regulation problems to preserve grid stability. Among these, the primary control reserve is reckoned to be one of the most important issues, since [...] Read more.
The ever-growing diffusion of renewables as electrical generation sources is forcing the electrical power system to face new and challenging regulation problems to preserve grid stability. Among these, the primary control reserve is reckoned to be one of the most important issues, since the introduction of generators based on renewable energies and interconnected through static converters, if relieved from the primary reserve contribution, reduces both the system inertia and the available power reserve in case of network events involving frequency perturbations. In this scenario, renewable plants such as hydroelectric run-of-river generators could be required to provide the primary control reserve ancillary service. In this paper, the integration between a multi-unit run-of-river power plant and a lithium-ion based battery storage system is investigated, suitably accounting for the ancillary service characteristics as required by present grid codes. The storage system is studied in terms of maximum economic profitability, taking into account its operating constraints. Dynamic simulations are carried out within the DIgSILENT PowerFactory 2016 software environment in order to analyse the plant response in case of network frequency contingencies, comparing the pure hydroelectric plant with the hybrid one, in which the primary reserve is partially or completely supplied by the storage system. Results confirm that the battery storage system response to frequency perturbations is clearly faster and more accurate during the transient phase compared to a traditional plant, since time delays due to hydraulic and mechanical regulations are overpassed. A case study, based on data from an existing hydropower plant and referring to the Italian context in terms of operational constraints and ancillary service remuneration, is presented. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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1989 KiB  
Article
Risk Assessment Method of UHV AC/DC Power System under Serious Disasters
by Rishang Long and Jianhua Zhang
Energies 2017, 10(1), 13; https://doi.org/10.3390/en10010013 - 23 Dec 2016
Cited by 8 | Viewed by 5676
Abstract
Based on the theory of risk assessment, the risk assessment method for an ultra-high voltage (UHV) AC/DC hybrid power system under severe disaster is studied. Firstly, considering the whole process of cascading failure, a fast failure probability calculation method is proposed, and the [...] Read more.
Based on the theory of risk assessment, the risk assessment method for an ultra-high voltage (UHV) AC/DC hybrid power system under severe disaster is studied. Firstly, considering the whole process of cascading failure, a fast failure probability calculation method is proposed, and the whole process risk assessment model is established considering the loss of both fault stage and recovery stage based on Monte Carlo method and BPA software. Secondly, the comprehensive evaluation index system is proposed from the aspects of power system structure, fault state and economic loss, and the quantitative assessment of system risk is carried out by an entropy weight model. Finally, the risk assessment of two UHV planning schemes are carried out and compared, which proves the effectiveness of the research work. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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5172 KiB  
Article
HVDC-System-Interaction Assessment through Line-Flow Change-Distribution Factor and Transient-Stability Analysis at Planning Stage
by Sungchul Hwang, Jaegul Lee and Gilsoo Jang
Energies 2016, 9(12), 1068; https://doi.org/10.3390/en9121068 - 16 Dec 2016
Cited by 8 | Viewed by 5121
Abstract
Many of the recent projects for new transmission line have considered the high-voltage direct current (HVDC) system, owing to the many advantages of the direct current (DC) system. The most noteworthy advantage is that a cable can serve as a substitute for the [...] Read more.
Many of the recent projects for new transmission line have considered the high-voltage direct current (HVDC) system, owing to the many advantages of the direct current (DC) system. The most noteworthy advantage is that a cable can serve as a substitute for the overhead transmission line in residential areas; therefore, the HVDC system application is increasing, and as the number of DC systems in the power system increases, the interaction assessment regarding the HVDC system gains importance. An index named multi-infeed interaction factor (MIIF) is commonly used to estimate the interaction between power converters; however, the HVDC system is composed of two converters and a transmission line. The MIIF represents the interaction between the rectifiers and inverters, but not for the whole system. In this work, a method to assess the interaction of the whole system was therefore studied. To decide on the location of the new HVDC transmission system at the planning stage, in consideration of the interaction of the existing DC system, the line flow change distribution factor, according to the HVDC-transmission capacity change, was examined. Also, a power system transient -stability analysis was performed with different HVDC system locations, depending on the distribution factor. The simulation results indicate that when the factor is higher, two HVDC systems have a stronger interaction and are less stable in the transient state. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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6744 KiB  
Article
A Parallel Probabilistic Load Flow Method Considering Nodal Correlations
by Jun Liu, Xudong Hao, Peifen Cheng, Wanliang Fang and Shuanbao Niu
Energies 2016, 9(12), 1041; https://doi.org/10.3390/en9121041 - 10 Dec 2016
Cited by 15 | Viewed by 4067
Abstract
With the introduction of more and more random factors in power systems, probabilistic load flow (PLF) has become one of the most important tasks for power system planning and operation. Cumulants-based PLF is an effective algorithm to calculate PLF in an analytical way, [...] Read more.
With the introduction of more and more random factors in power systems, probabilistic load flow (PLF) has become one of the most important tasks for power system planning and operation. Cumulants-based PLF is an effective algorithm to calculate PLF in an analytical way, however, the correlations among the nodal injections to the system level have rarely been studied. A novel parallel cumulants-based PLF method considering nodal correlations is proposed in this paper, which is able to deal with the correlations among all system nodes, and avoid the Jacobian matrix inversion in the traditional cumulants-based PLF as well. In addition, parallel computing is introduced to improve the efficiency of the numerical calculations. The accuracy of the proposed method is validated by numerical tests on the standard IEEE-14 system, comparing with the results from Correlation Latin hypercube sampling Monte Carlo Simulation (CLMCS) method. And the efficiency and parallel performance is proven by the tests on the modified IEEE-300, C703, N1047 systems with distributed generation (DG). Numerical simulations show that the proposed parallel cumulants-based PLF method considering nodal correlations is able to get more accurate results using less computational time and physical memory, and have higher efficiency and better parallel performance than the traditional one. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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2255 KiB  
Article
A Comparison of Impedance-Based Fault Location Methods for Power Underground Distribution Systems
by Enrique Personal, Antonio García, Antonio Parejo, Diego Francisco Larios, Félix Biscarri and Carlos León
Energies 2016, 9(12), 1022; https://doi.org/10.3390/en9121022 - 07 Dec 2016
Cited by 33 | Viewed by 6237
Abstract
In the last few decades, the Smart Grid paradigm presence has increased within power systems. These new kinds of networks demand new Operations and Planning approaches, following improvements in the quality of service. In this sense, the role of the Distribution Management System, [...] Read more.
In the last few decades, the Smart Grid paradigm presence has increased within power systems. These new kinds of networks demand new Operations and Planning approaches, following improvements in the quality of service. In this sense, the role of the Distribution Management System, through its Outage Management System, is essential to guarantee the network reliability. This system is responsible for minimizing the consequences arising from a fault event (or network failure). Obviously, knowing where the fault appears is critical for a good reaction of this system. Therefore, several fault location techniques have been proposed. However, most of them provide individual results, associated with specific testbeds, which make the comparison between them difficult. Due to this, a review of fault location methods has been done in this paper, analyzing them for their use on underground distribution lines. Specifically, this study is focused on an impedance-based method because their requirements are in line with the typical instrumentation deployed in distribution networks. This work is completed with an exhaustive analysis of these methods over a PSCADTM X4 implementation of the standard IEEE Node Test Feeder, which truly allows us to consistently compare the results of these location methods and to determine the advantages and drawbacks of each of them. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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1915 KiB  
Article
Robust Unit Commitment Including Frequency Stability Constraints
by Felipe Pérez-Illanes, Eduardo Álvarez-Miranda, Claudia Rahmann and Camilo Campos-Valdés
Energies 2016, 9(11), 957; https://doi.org/10.3390/en9110957 - 16 Nov 2016
Cited by 15 | Viewed by 4493
Abstract
An increased use of variable generation technologies such as wind power and photovoltaic generation can have important effects on system frequency performance during normal operation as well as contingencies. The main reasons are the operational principles and inherent characteristics of these power plants [...] Read more.
An increased use of variable generation technologies such as wind power and photovoltaic generation can have important effects on system frequency performance during normal operation as well as contingencies. The main reasons are the operational principles and inherent characteristics of these power plants like operation at maximum power point and no inertial response during power system imbalances. This has led to new challenges for Transmission System Operators in terms of ensuring system security during contingencies. In this context, this paper proposes a Robust Unit Commitment including a set of additional frequency stability constraints. To do this, a simplified dynamic model of the initial system frequency response is used in combination with historical frequency nadir data during contingencies. The proposed approach is especially suitable for power systems with cost-based economic dispatch like those in most Latin American countries. The study is done considering the Northern Interconnected System of Chile, a 50-Hz medium size isolated power system. The results obtained were validated by means of dynamic simulations of different system contingencies. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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5106 KiB  
Article
Auto-Mapping and Configuration Method of IEC 61850 Information Model Based on OPC UA
by In-Jae Shin, Byung-Kwen Song and Doo-Seop Eom
Energies 2016, 9(11), 901; https://doi.org/10.3390/en9110901 - 01 Nov 2016
Cited by 15 | Viewed by 8189
Abstract
The open-platform communication (OPC) unified architecture (UA) (IEC62541) is introduced as a key technology for realizing a variety of smart grid (SG) use cases enabling relevant automation and control tasks. The OPC UA can expand interoperability between power systems. The top-level SG management [...] Read more.
The open-platform communication (OPC) unified architecture (UA) (IEC62541) is introduced as a key technology for realizing a variety of smart grid (SG) use cases enabling relevant automation and control tasks. The OPC UA can expand interoperability between power systems. The top-level SG management platform needs independent middleware to transparently manage the power information technology (IT) systems, including the IEC 61850. To expand interoperability between the power system for a large number of stakeholders and various standards, this paper focuses on the IEC 61850 for the digital substation. In this paper, we propose the interconnection method to integrate communication with OPC UA and convert OPC UA AddressSpace using system configuration description language (SCL) of IEC 61850. We implemented the mapping process for the verification of the interconnection method. The interconnection method in this paper can expand interoperability between power systems for OPC UA integration for various data structures in the smart grid. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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4758 KiB  
Article
Communication Channel Reconstruction for Transmission Line Differential Protection: System Arrangement and Routing Protocol
by Xu Chen, Xianggen Yin, Bin Yu and Zhe Zhang
Energies 2016, 9(11), 893; https://doi.org/10.3390/en9110893 - 29 Oct 2016
Cited by 3 | Viewed by 5798
Abstract
Natural disasters may be of significant impact on overhead transmission lines and cause communication outage related to pilot protection. This paper aims at reconstructing communication channels and maintaining functions of pilot-wire differential protections after the main channel fails. With the development of smart [...] Read more.
Natural disasters may be of significant impact on overhead transmission lines and cause communication outage related to pilot protection. This paper aims at reconstructing communication channels and maintaining functions of pilot-wire differential protections after the main channel fails. With the development of smart grids as well as new communication technologies, wireless sensor networks (WSNs) have been potential means for realizing reconstructed communication channels (RCCs) without further installation. For a reliable design, system arrangement and the communication structure were presented. Theoretical planning of sensor nodes was formulated, which enjoys advantages such as high reliability, cost optimization, and capacity of satisfying the connectivity of the communication network. To meet the need of time delay, a novel routing protocol for WSNs was proposed with three stages including route establishment, route discovery and route maintenance, which ensured the directional propagation of data packets. Practical experiments and simulation results indicate that the proposed RCC scheme can satisfy time delay of protection relaying in emergency communication channel, as well as guarantee the connectivity of networks when some WSN nodes are damaged. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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4272 KiB  
Article
A Novel Modulation Function-Based Control of Modular Multilevel Converters for High Voltage Direct Current Transmission Systems
by Majid Mehrasa, Edris Pouresmaeil, Sasan Zabihi, Juan C. Trujillo Caballero and João P. S. Catalão
Energies 2016, 9(11), 867; https://doi.org/10.3390/en9110867 - 25 Oct 2016
Cited by 21 | Viewed by 4103
Abstract
In this paper, a novel modulation function-based method including analyses of the modulation index and phase is proposed for operation of modular multilevel converters (MMCs) in high voltage direct current (HVDC) transmission systems. The proposed modulation function-based control technique is developed based on [...] Read more.
In this paper, a novel modulation function-based method including analyses of the modulation index and phase is proposed for operation of modular multilevel converters (MMCs) in high voltage direct current (HVDC) transmission systems. The proposed modulation function-based control technique is developed based on thorough and precise analyses of all MMC voltages and currents in the a-b-c reference frame in which the alternating current (AC)-side voltage is the first target to be obtained. Using the AC-side voltage, the combination of the MMC upper and lower arm voltages is achieved as the main structure of the proposed modulation function. The main contribution of this paper is to obtain two very simple new modulation functions to control MMC performance in different operating conditions. The features of the modulation function-based control technique are as follows: (1) this control technique is very simple and can be easily achieved in a-b-c reference frame without the need of using Park transformation; and (2) in addition, the inherent properties of the MMC model are considered in the proposed control technique. Considering these properties leads to constructing a control technique that is robust against MMC parameters changes and also is a very good tracking method for the components of MMC input currents. These features lead to improving the operation of MMC significantly, which can act as a rectifier in the HVDC structure. The simulation studies are conducted through MATLAB/SIMULINK software, and the results obtained verify the effectiveness of the proposed modulation function-based control technique. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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1265 KiB  
Article
Droop Control Design of Multi-VSC Systems for Offshore Networks to Integrate Wind Energy
by Muhammad Raza, Kevin Schönleber and Oriol Gomis-Bellmunt
Energies 2016, 9(10), 826; https://doi.org/10.3390/en9100826 - 14 Oct 2016
Cited by 12 | Viewed by 7698
Abstract
This research envisages the droop control design of multi voltage source converter systems for offshore networks to integrate wind power plant with the grids. An offshore AC network is formulated by connecting several nearby wind power plants together with AC cables. The net [...] Read more.
This research envisages the droop control design of multi voltage source converter systems for offshore networks to integrate wind power plant with the grids. An offshore AC network is formulated by connecting several nearby wind power plants together with AC cables. The net energy in the network is transferred to onshore using voltage source high voltage direct current (VSC-HVDC) transmissionsystems. In the proposed configuration, an offshore network is energized by more than one VSC-HVDC system, hereby providing redundancy to continue operation in case of failure in one of the HVDC transmission lines. The power distribution between VSC-HVDC systems is done using a droop control scheme. Frequency droop is implemented to share active power, and voltage droop is implemented to share reactive power. Furthermore, a method of calculating droop gains according to the contribution factor of each converter is presented. The system has been analyzed to evaluate the voltage profile of the network affected by the droop control. Nonlinear dynamic simulation has been performed for the verification of the control principle. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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1318 KiB  
Article
Optimal Available Transfer Capability Assessment Strategy for Wind Integrated Transmission Systems Considering Uncertainty of Wind Power Probability Distribution
by Jun Xie, Lu Wang, Qiaoyan Bian, Xiaohua Zhang, Dan Zeng and Ke Wang
Energies 2016, 9(9), 704; https://doi.org/10.3390/en9090704 - 01 Sep 2016
Cited by 3 | Viewed by 4018
Abstract
Wind power prediction research shows that it is difficult to accurately and effectively estimate the probability distribution (PD) of wind power. When only partial information of the wind power probability distribution function is available, an optimal available transfer capability (ATC) assessment [...] Read more.
Wind power prediction research shows that it is difficult to accurately and effectively estimate the probability distribution (PD) of wind power. When only partial information of the wind power probability distribution function is available, an optimal available transfer capability (ATC) assessment strategy considering the uncertainty on the wind power probability distribution is proposed in this paper. As wind power probability distribution is not accurately given, the proposed strategy can efficiently maximize ATC with the security operation constraints satisfied under any wind power PD function case in the uncertainty set. A distributional robust chance constrained (DRCC) model is developed to describe an optimal ATC assessment problem. To achieve tractability of the DRCC model, the dual optimization, S-lemma and Schur complement are adopted to eliminate the uncertain wind power vector in the DRCC model. According to the characteristics of the problem, the linear matrix inequality (LMI)-based particle swarm optimization (PSO) algorithm is used to solve the DRCC model which contains first and second-order moment information of the wind power. The modified IEEE 30-bus system simulation results show the feasibility and effectiveness of the proposed ATC assessment strategy. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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1781 KiB  
Article
General Forced Oscillations in a Real Power Grid Integrated with Large Scale Wind Power
by Ping Ju, Yongfei Liu, Feng Wu, Fei Dai and Yiping Yu
Energies 2016, 9(7), 525; https://doi.org/10.3390/en9070525 - 08 Jul 2016
Cited by 5 | Viewed by 5280
Abstract
According to the monitoring of the wide area measurement system, inter-area oscillations happen more and more frequently in a real power grid of China, which are close to the forced oscillation. Applying the conventional forced oscillation theory, the mechanism of these oscillations cannot [...] Read more.
According to the monitoring of the wide area measurement system, inter-area oscillations happen more and more frequently in a real power grid of China, which are close to the forced oscillation. Applying the conventional forced oscillation theory, the mechanism of these oscillations cannot be explained well, because the oscillations vary with random amplitude and a narrow frequency band. To explain the mechanism of such oscillations, the general forced oscillation (GFO) mechanism is taken into consideration. The GFO is the power system oscillation excited by the random excitations, such as power fluctuations from renewable power generation. Firstly, properties of the oscillations observed in the real power grid are analyzed. Using the GFO mechanism, the observed oscillations seem to be the GFO caused by some random excitation. Then the variation of the wind power measured in this power gird is found to be the random excitation which may cause the GFO phenomenon. Finally, simulations are carried out and the power spectral density of the simulated oscillation is compared to that of the observed oscillation, and they are similar with each other. The observed oscillation is thus explained well using the GFO mechanism and the GFO phenomenon has now been observed for the first time in real power grids. Full article
(This article belongs to the Special Issue Advances in Power System Operations and Planning)
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