TOWARDS RESILIENT SMART GRIDS: ROBUST CONTROL...
Transcript of TOWARDS RESILIENT SMART GRIDS: ROBUST CONTROL...
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TOWARDS RESILIENT SMART GRIDS: ROBUST CONTROL FRAMEWORK DESIGNTO ENHANCE TRANSIENT STABILITY
By
MUHARREM AYAR
A DISSERTATION PRESENTED TO THE GRADUATE SCHOOLOF THE UNIVERSITY OF FLORIDA IN PARTIAL FULFILLMENT
OF THE REQUIREMENTS FOR THE DEGREE OFDOCTOR OF PHILOSOPHY
UNIVERSITY OF FLORIDA
2017
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c© 2017 Muharrem Ayar
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To my lovely wife Ozlem, my beloved son Omer Selim and my parents
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ACKNOWLEDGMENTS
I would like to express my deepest respect and most sincere gratitude to my
advisor, Dr. Haniph A. Latchman, for his encouragement, guidance, and support. He
did not spare any effort to improve my research and teaching skills. His constructive
criticism and invaluable suggestions throughout my graduate study have helped my
research and enabled me to develop a better understanding of the subject. I am
extremely privileged to have been a student under his supervision. I hope that I could
become as good an advisor to my students as Dr. Latchman in the future.
I extend my gratitude to my co-advisor, Dr. Janise McNair, for her guidance and
support. She also assisted me greatly to improve my research and complete my
doctoral dissertation. She is a dedicated advisor, and I have benefited tremendously
from having been a student in her research group.
I also express my appreciation to Dr. Arturo Bretas for his extraordinary guidance
and support to improve my doctoral research. Also, I want to thank Dr. Norman Fitz-Coy
for accepting to serve on my dissertation committee and his recommendations.
A very special appreciation to my friend Dr. Serhat Obuz for his collaboration and
fruitful discussions we held throughout my research, and for his contributions to the
success of our joint research work.
Finally, and most importantly, I would like to thank my family. My parents have been
undeniably my pillar of strength and a constant source of motivation. Their prayers
for me were what sustained me hereto. I cannot thank my lovely wife enough; without
her understanding, patience, and support, I would not have been able to continue and
succeed. My beloved son, your innocence was my fuel and your smile was my remedy.
Special thanks also to my sisters, for their prayers for me.
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TABLE OF CONTENTS
page
ACKNOWLEDGMENTS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4
LIST OF TABLES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7
LIST OF FIGURES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8
ABSTRACT . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10
CHAPTER
1 INTRODUCTION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13
1.1 Challenges in Smart Grids . . . . . . . . . . . . . . . . . . . . . . . . . . . 171.1.1 Cyber-Physical Security . . . . . . . . . . . . . . . . . . . . . . . . 171.1.2 Stability and Resiliency . . . . . . . . . . . . . . . . . . . . . . . . . 191.1.3 Communication . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 21
1.2 Research Motivation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 231.3 Research Contributions . . . . . . . . . . . . . . . . . . . . . . . . . . . . 241.4 Dissertation Organization . . . . . . . . . . . . . . . . . . . . . . . . . . . 25
2 SMART GRID STABILITY AND CONTROL . . . . . . . . . . . . . . . . . . . . 26
2.1 Smart Grid Stability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 262.1.1 Rotor Angle Stability . . . . . . . . . . . . . . . . . . . . . . . . . . 27
2.1.1.1 Transient Stability . . . . . . . . . . . . . . . . . . . . . . 282.1.1.2 Small-Signal Stability . . . . . . . . . . . . . . . . . . . . 30
2.1.2 Frequency Stability . . . . . . . . . . . . . . . . . . . . . . . . . . . 302.1.3 Voltage Stability . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 31
2.2 Controls for Smart Grid Transient Stability . . . . . . . . . . . . . . . . . . 322.2.1 Decentralized Control . . . . . . . . . . . . . . . . . . . . . . . . . . 332.2.2 Centralized Control . . . . . . . . . . . . . . . . . . . . . . . . . . . 332.2.3 Distributed Control . . . . . . . . . . . . . . . . . . . . . . . . . . . 34
2.3 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 36
3 A ROBUST DECENTRALIZED CONTROL FRAMEWORK WITH CONSTANTTIME DELAY COMPENSATION . . . . . . . . . . . . . . . . . . . . . . . . . . 38
3.1 Dynamic Model of Synchronous Machines . . . . . . . . . . . . . . . . . 403.2 Robust Nonlinear Controller Design . . . . . . . . . . . . . . . . . . . . . . 413.3 Lyapunov Stability Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . 443.4 Simulation and Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . 473.5 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 52
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4 CYBER-ENABLED DECENTRALIZED CONTROL FRAMEWORK WITH UN-KNOWN TIME-VARYING INPUT DELAY COMPENSATION . . . . . . . . . . . 53
4.1 Dynamic Model and Properties of Synchronous Machines . . . . . . . . . 564.2 Control Objective and Development . . . . . . . . . . . . . . . . . . . . . 584.3 Stability Analysis . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 604.4 State Estimator . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 644.5 Simulation and Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 694.6 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 73
5 A DISTRIBUTED NONLINEAR CONTROL STRATEGY FOR ENHANCINGSMART GRID TRANSIENT STABILITY . . . . . . . . . . . . . . . . . . . . . . 74
5.1 Distributed Control Framework . . . . . . . . . . . . . . . . . . . . . . . . 755.1.1 Dynamic Model of Synchronous Machines . . . . . . . . . . . . . . 775.1.2 Control Development . . . . . . . . . . . . . . . . . . . . . . . . . . 785.1.3 Lyapunov Stability Analysis . . . . . . . . . . . . . . . . . . . . . . 82
5.2 Simulation and Results . . . . . . . . . . . . . . . . . . . . . . . . . . . . 865.3 Case Study under Practical Limitations . . . . . . . . . . . . . . . . . . . . 885.4 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 92
6 AN ADAPTIVE MAC PROTOCOL DESIGN FOR SMART GRID HOME AREANETWORKS . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 94
6.1 Literature Review . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 966.2 Research Motivation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 986.3 HomePlug/IEEE 1901 CSMA/CA MAC Protocol . . . . . . . . . . . . . . . 99
6.3.1 Backoff Procedure . . . . . . . . . . . . . . . . . . . . . . . . . . . 996.3.2 Priority Resolution . . . . . . . . . . . . . . . . . . . . . . . . . . . 100
6.4 Adaptive Contention Window based CSMA/CA MAC . . . . . . . . . . . . 1016.5 Performance Evaluation with Prioritized Traffic . . . . . . . . . . . . . . . . 1076.6 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 111
7 CONCLUSIONS AND FUTURE WORK . . . . . . . . . . . . . . . . . . . . . . 113
7.1 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1137.2 Future Work . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 115
7.2.1 A Cross-Layer Strategy for Cyber-Physical Security of Smart Grids 1157.2.2 Saturated Robust Controller . . . . . . . . . . . . . . . . . . . . . . 117
REFERENCES . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 120
BIOGRAPHICAL SKETCH . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 128
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LIST OF TABLES
Table page
3-1 Decentralized controller gain settings for known constant time delay case. . . . 48
4-1 Adjusted controller gain values for unknown time-varying constant time delaycase. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 69
5-1 Distributed controller gain settings. . . . . . . . . . . . . . . . . . . . . . . . . 86
5-2 Default simulation parameters. . . . . . . . . . . . . . . . . . . . . . . . . . . . 87
6-1 Contention resolution parameters of the standard HomePlug MAC protocol. . . 99
6-2 HomePlug 1.0 MAC parameters. . . . . . . . . . . . . . . . . . . . . . . . . . . 107
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LIST OF FIGURES
Figure page
1-1 Evolution of power girds: Past, Today and Future. . . . . . . . . . . . . . . . . . 14
1-2 A satellite image of the Northeastern cities in US during 2003 blackout. . . . . 16
1-3 An overview of smart grid. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 17
1-4 An overview of smart grid communication networks. . . . . . . . . . . . . . . . 21
2-1 Classification of power system stability . . . . . . . . . . . . . . . . . . . . . . . 27
2-2 The dynamic model of synchronous machines. . . . . . . . . . . . . . . . . . . 29
3-1 An overview of decentralized control framework for transient stability. . . . . . 39
3-2 Rotor angle and speed deviation of synchronous machines during and afterthree phase fault. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 49
3-3 Stabilization time versus varying DESS capacity and time delay. . . . . . . . . 49
3-4 Stabilization time versus clearing time. . . . . . . . . . . . . . . . . . . . . . . 50
3-5 Stabilization time versus additive time-varying disturbance. . . . . . . . . . . . 51
4-1 PMUs and synchrophasor data flows in the North American power grid. . . . . 54
4-2 Data flow of the proposed cyber-physical control strategy. . . . . . . . . . . . . 55
4-3 Rotor speed and angle deviation of synchronous machines during and afterthree phase fault. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 70
4-4 Representation of varying actual time delay and its constant estimate. . . . . . 70
4-5 Comparative simulation results under practical limitations. . . . . . . . . . . . . 72
5-1 An overview of designed distributed control framework for smart grids. . . . . . 75
5-2 Rotor angle deviation and rotor speed oscillation over time during and afterthree-phase fault inception. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 88
5-3 Stabilization performance of the distributed controller under practical limitations. 89
6-1 The MAC throughput comparison of wireless (IEEE 802.11) and wired(HomePlug) networking technologies . . . . . . . . . . . . . . . . . . . . . . . 96
6-2 Operational flow chart of HomePlug/IEEE 1901 CSMA/CA MAC protocol. . . . 100
6-3 Backoff resolution of HomePlug/IEEE 1901 CSMA/CA MAC protocol. . . . . . 101
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6-4 Markov chain model for adaptive contention window based CSMA/CA MACprotocol. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 101
6-5 Numeric and analytic solution for po . . . . . . . . . . . . . . . . . . . . . . . . 104
6-6 Estimating number of contending nodes over a changing network traffic. . . . 106
6-7 Simulation results to evaluate MAC efficiency of the proposed MAC protocolwhen the number of nodes is given and estimated . . . . . . . . . . . . . . . . . 106
6-8 Case study to compare the MAC efficiency of the designed controller with thestandardized HomePlug MAC. . . . . . . . . . . . . . . . . . . . . . . . . . . . 109
6-9 Case study to compare the channel access delay performance of the de-signed controller with the standardized HomePlug MAC. . . . . . . . . . . . . . 110
7-1 Cross-layer cyber-physical security framework for smart grid. . . . . . . . . . . 116
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Abstract of Dissertation Presented to the Graduate Schoolof the University of Florida in Partial Fulfillment of theRequirements for the Degree of Doctor of Philosophy
TOWARDS RESILIENT SMART GRIDS: ROBUST CONTROL FRAMEWORK DESIGNTO ENHANCE TRANSIENT STABILITY
By
Muharrem Ayar
August 2017
Chair: Haniph A. LatcmanCochair: Janise McNairMajor: Electrical and Computer Engineering
Smart grids use digital communications, signal processing, sensing, and control
systems technologies to enhance the efficiency, reliability, and security of electrical
power systems and contribute to the sustainability of energy with the large penetration
of renewable energy sources. Increasing integration of the cutting-edge digital technolo-
gies has become the source of new challenges such as cybersecurity and uncertainties,
while at the same time being the cornerstone of new opportunities such as real-time
control and monitoring systems to enhance the power system stability.
Maintaining the stability of power systems has become an even more challenging
problem with the increasing complexity by enabling two-way power flow through active
loads and energy storage systems. Fortunately, making real-time data exchange
between sensors and control units possible through communication networks allows
designing advanced control systems. However, communication delay which is inherent
in communication systems limits the capacity of the control systems and introduce
uncertainty to the system. On the other hand, cyber-attacks to the various segments of
smart grids threat the stability and security of power systems by leading to malfunction
of underlying protection and control systems.
In today’s world, isolating systems by deploying private networks cannot entirely
protect them from cyber-attacks and penetration. The Stuxnet case, for example, led to
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the malfunctioning of control systems in Iranian’s nuclear power station, despite being
physically isolated from the global network. Therefore, addressing various form of cyber-
attacks requires defense-in-depth strategies whereby enabling multiple layers of security
in the underlying communication and control systems.
This dissertation presents distributed and decentralized robust control frameworks
that aim at enhancing the transient stability and resiliency of smart grids in the face
of cyber-physical disturbances by employing phasor measurement units (PMU) and
distributed energy storage systems (DESS). Robust controllers introduce a novel time
delay compensation technique to mitigate the effect of communication and control input
time delay. In addition, uncertainties arising from varying plant parameters and errors in
sensor measurements are considered in the robust controller design. Furthermore, the
communication delay is addressed in network layer by developing an adaptive medium
access control (MAC) protocol to reduce the channel access delay and improve the data
throughput with respect to increasing numbers of connected intelligent devices.
The success of robust controllers is proven by conducting several comparative
case studies based on IEEE 39 bus 10 machines test power system. The enhanced
resiliency to the large time delay and uncertainties highlights the success of robust
controllers in comparison to the state-of-the-art controllers. To illustrate, while the para-
metric feedback linearization (PFL) controller can tolerate up to 160ms communication
delay, the designed distributed controller can stabilize a perturbed power system even in
the existence of 1s communication delay. Similarly, comparisons between decentralized
controller and the well-known multi-band power system stabilizer (MB-PSS) controller
shows that decentralized controller can reduce the stabilization time by 80% when the
delay is known and by 60% if the delay is unknown with respect to the MB-PSS. It is
evident that the robust controller owes this success to the designed novel time delay
compensation technique. Moreover, the simulation results with respect to uncertainty in
sensor measurements show that the robust controller is resilient up to 10% deviation.
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Whereas, the measurement uncertainty affect the stabilization performance of the PFL
controller significantly.
In addition, the designed MAC protocol is tested in a home area network (HAN)
which hosts large numbers of nodes with various applications. Simulation results
demonstrate that an 80% MAC efficiency is maintained for up to 100 nodes while the
efficiency of standardized HomePlug MAC protocol, for example, reduces down to 10%.
Similarly, an 80% reduction in channel access delay is achieved by the adaptive MAC
protocol with respect to the HomePlug MAC protocol. It is asserted that tailoring the
adaptive MAC protocol for other communication networks such as neighborhood area
network (NAN) and wide area networks (WAN) can reduce the channel access delay
and improve data throughput.
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CHAPTER 1INTRODUCTION
Electricity is one of the ground-breaking discoveries of the 19th century that has
made a great impact on the socioeconomic development of nations. Reliable delivery
of electricity plays a crucial role in nation’s economy, security, and even in the health
and safety. However, the current electric infrastructures are aging and they are being
pushed to do more than they were originally designed to do. Fundamental changes in
both demand and supply side cause electrical power system to face increasing stress.
On the demand side, increasing world energy consumption has been forcing
capacity of electrical power systems to work on their physical limits. The International
Energy Agency has recently released 2016 World Energy Outlook Report, that projects
30% rise in world energy consumption by 2040 [1]. Similarly, the International Energy
Outlook 2016 (IEO2016) of the U.S. Energy Information Administration estimates that
the energy consumption will grow by 48% between 2012 and 2040 [2]. In order to
meet the current energy demand and preparing the power system for future, advanced
technologies such as demand response (DR) and smart metering have been used to
manage energy consumption and generation.
On the supply side, concerns about energy security and sustainability, environ-
mental effects of fossil fuel emission, and sustained long-term energy prices have led
a shift from bulk energy generation to distributed generation by increasingly integrating
renewable energy sources (RES) which are abundant in the form of solar, hydro, wind,
geothermal, and biomass. According to the IEO2016, harvesting energy from renew-
ables is growing at a rapid pace all over the world. Since renewables are eco-friendly
and economic, many countries including the United States have been promoting green
energy generation by adopting new energy policies and incentives [3]. In the United
States, energy generation from renewables in the form of wind, solar, and geothermal
has been doubled since 2008 and 20% growth has been targeted by 2020 [4]. China
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Figure 1-1. Evolution of power girds: Past, Today and Future [7].
targeted to achieve 20% renewable by 2020 [3] and more ambitiously set the target of
86% renewable by 2050 [5]. Similarly, European Commission asserted 20% renewable
target of Europe by 2020 [6].
The conventional power system architecture was based on bulk energy generation
remotely located from consumers, hierarchical control systems with minimal feedback,
and passive loads. The capacity, flexibility, reliability, and security of the traditional sys-
tem is far more behind the need for meeting the emerging trends, such as increasing
integration of relatively low inertia generation source, large penetration of distributed
generation, and the need for better resiliency. It is expected from the today’s electrical
grids that dynamically optimize operation and sources, integrate diverse generation
sources, integrate demand response, quickly detect and mitigate disturbances and
provide robust protection against cyber-physical threats. Incorporating all these fea-
tures transforms the conventional electric grids to the future’s modern smart grids as
illustrated in Figure 1-1.
The targeted benefits from the smart grids includes:
• Increasing integration of renewable energy systems,
• Improving the efficiency of energy transmission,
• Engaging end-users in power systems management,
• Optimizing operation and management costs,
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• Quicker restoration or self-healing power systems after a disturbance,
• Enhancing the security.
The modernization of the traditional power systems requires the use of cutting-edge
technologies such as advanced metering infrastructures (AMI), wireless and fiber optic
networks, and energy storage systems and advanced control that communicate and
collaborate to enable safe and reliable two-way electricity and data flow. Enabling
advanced technologies can greatly decrease the frequency and duration of power
outages, reduces the impact of natural disasters, and accelerates the restoration
service [2,8].
Grid modernization must encompass the technologies that offer cybersecurity pro-
tections and innovative control system architectures. Smart grids are one of the critical
infrastructures of the nations and must be protected well to avoid major blackouts which
may cause socioeconomic disasters by damaging and even worse seizing the operation
of banks, telecommunication, traffic, etc. A smarter grid should, therefore, enhance the
resiliency of power systems in order to prepare them to address emergencies such as
natural disasters and terrorist attacks.
In addition to the resiliency of electrical grids, power system stability is vital for
the reliable and sustainable operation of electrical grids that is maintained by enabling
centralized, decentralized or distributed control architectures. Traditional control systems
with minimal local feedback suffer from lack of situational awareness and the need for
human intervention. The Northwestern blackouts in 2003 [9] and the Italy blackout in
2003 [10], for example, were the result of a cascading failure that occurred very fast
due to the lack of advanced automation and global feedback for control. These two
unhindered major blackouts affected over 50 million people and over 400 generators and
caused a considerable amount of economic loss [11]. In the Figure 1-2, a satellite image
of the US Northeastern cities in 2003 illustrates the blackout.
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Figure 1-2. A satellite image of the Northeastern cities in US during 2003 blackout.
The two-way interactive communication capacity of the smart grids equipment
allows advanced digital control architectures with a real-time global feedback to en-
hance the stability and resiliency of electrical power grids. Current power systems has
been relatively interacted with information and communication technologies and keep
increasing interaction and to support automation, protection and control application as
depicted in Figure 1-3. In today’s smart grid, wide-area control systems (WACS) are
employed throughout generation and transmission systems. However, their centralized
architecture emerges several challenges such as increasing communication traffic and
data volume with large penetration of advanced sensors, and cybersecurity risk due to
their dependence on a central controller. Thus, the current trend for future smart grid
control systems shifts to distributed architectures rather than centralized ones.
The cybersecurity of smart grids is paramount for national security and need to be
investigated and treated carefully. The National Institute of Standards and Technology
(NIST) advocates that cybersecurity of electrical power grids requires a defense-in-
depth strategies by enabling multiple security throughout communication, protection
and control systems. In this dissertation, several control frameworks that take in
consideration of cyber-physical disturbances to enhance the transient stability are
presented. Moreover, a communication protocol is presented that aims at improving the
data throughput and the channel access delay for smart grid application within home
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Figure 1-3. An overview of smart grid [8].
area networks. An adaptive medium access control (MAC) protocol has been designed
to leverage the efficiency of highly populated networks.
The major contributions of this dissertation includes:
• Decentralized and distributed control frameworks design,
• Developing model-free based robust nonlinear controllers,
• Implementing novel time delay compensation techniques to overcome effects ofknown and unknown time-varying delay,
• Using distributed energy storage systems (DESS) for transient stability enhance-ment,
• Designing an adaptive MAC protocol for smart grid home-area network.
1.1 Challenges in Smart Grids
1.1.1 Cyber-Physical Security
Electrical energy is the major driver of social and economic dynamic of nations and
thus securing the energy is critical. It is evident as the US has designated electrical
power system as one of the top 16 critical infrastructures [12]. Concerns about the
security of electrical grids have raised recently because of increasingly connecting
grid equipment to communication networks that provides multiple entry points for
the intrusion of adversary. Cyber-physical security, thus, has become one of the top
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priorities of nations and many initiatives and research activities have been supported by
governments. The US government, for example, allocated $14 billion budget for funding
cybersecurity research and initiatives in FY 2016 [13].
Smart grids are one of the critical cyber-physical architectures comprised of a
broad range of technologies implemented throughout the generation, transmission,
and distribution systems that are owned and regulated by numerous owners. The large
diversity in incorporated technological equipment and varying regional regulations
across the countries requires consensus to address cyber-physical security. In the
US, for example, several organizations including the Department of Energy (DoE), The
National Electric Sector Cybersecurity Organization (NESCO), the National Institute of
Standards (NIST), and the Nort American Electric Reliability Corporation (NERC) take
on a mission with regard to the electrical power sector cybersecurity and resiliency.
The NIST advocates that cybersecurity of intelligent electrical grids need defense-
in-depth strategies that utilize multiple layer security throughout the communication,
protection and restoring systems [14]. Adaptive and dynamic nature of cyber-attacks
threatens the various layer of power systems. The Stuxnet, for example, is a virus first
identified in 2010 that caused a substantial damage in Iran’s nuclear program [15]. This
particular malware does not have a domain-specific design and an architecture which
could be tailored as a platform for attacking modern supervisory control and data ac-
quisition (SCADA) and PLC systems that are highly utilized in power system protection
and control. It is evident that boosting only the cybersecurity of communication system
or isolating SCADA systems from global networks may not be enough to protect smart
grids as it was experienced by the Stuxnet that was introduced to the systems via a USB
drive. Because of these reasons, cybersecurity needs to be considered throughout the
entire grid operations and functions including communication, protection and control
systems.
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Electrical power grids are highly interconnected and a local failure or a cyber-
attack, which can lead a cascaded fault that may result in major blackouts. As an
example, Ukrainian blackout in 2015 caused by a cyber-attack to a substation and
culminated with a major power outage that affected over 225,000 people in Ukraine [16].
Quadrennial Energy Review report of US Department of Energy reveals the significance
of smart grid cybersecurity by stating that “electricity system faces imminent danger
from cyber-attacks” [17]. To draw attention towards cybersecurity of smart grid, many
warnings [18–20] and some guidelines have been published, such as NISTIR 7628 [14]
and NIST SP 1108 [21].
Since there is no single security measure that could counter all types of threats in
smart grids, there is a need for cross-layer security solutions among communication,
protection and control systems as suggested by the NIST. Communications systems
need to be leveraged to detect and protect grid equipment from intrusions, malicious
data injection, and intentionally occupation to increase latency. If communication
layer fails, protection systems such as state estimation (SE) must be able to detect
and correct malicious parameters to prevent systems from malfunctioning because of
disturbances. On the other hand, control systems must be resilient to either failure of
communication and protection system or inability to provide a totally reliable feedback
to maintain the stability of systems or recovering the system that subjected to a major
disturbance.
1.1.2 Stability and Resiliency
Smart grid must address not only deliberate cyber-attacks but also inadvertent
compromises of utilized cyber-physical infrastructures due to user errors, equipment
failures and natural disasters to maintain the stability of systems. The power systems
stability has always been a major concern for sustaining their reliable and secure oper-
ation. However, increasing integration of low inertia generations from renewables, large
penetration of distributed energy generations at the distribution level, and introducing
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active loads in electrical grid to enable bi-directional power flow have fueled the power
system instability problems.
In conventional electrical power systems, stability has been treated by conducting
local control actions with a minimal feedback signals from associated equipment.
The emerging instability problem with the increasing complexity in power system
environment and growing interdependency between cyber and physical components
reveal the need for advanced robust control system architectures. Fortunately, the
ability of information technology to enable real-time two-way communication between
widely dispersed sensors such as PMU and control systems provides an opportunity to
design real-time monitoring and control systems such as wide-area monitoring systems
(WAMS) and wide-area control systems (WACS).
The WACS proposes a centralized control architecture that aggregates system
information at a central point via remotely installed sensors, calculate control signals
and actuates remote devices in the case of disturbances. The increased visibility of grid
through distributed sensors helps control systems to command the entire grid effectively.
However, concerns about scalability and security of centralized control architectures
have been arising because of the increasing communication burden and security risk
of being dependent on a single control center. Emerging uncertainties that may stem
from the communication delay and the loss or the failure of sensors contribute to the
instability of power systems.
On the other hand, the coexistence of a variety of low inertia energy generators with
bulk energy generators adversely affect the physical dynamics of the electrical power
system [22]. Distributed generation units such as inverter-connected wind turbines and
PV, which do not have rotational inertia, have been effectively displacing the rotating
conventional generators. This transformation results in changes in electromechanical
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dynamics of synchronous machines and affects the power system stability [23]. More-
over, the fast frequency dynamics with low rotational inertia make frequency control and
power system stability even more challenging.
Taking into account all these challenges, new robust control architectures are
explicitly required to enhance the stability and resiliency power systems in the face of
cyber-physical disturbances. It is concluded that controller that is required must be able
to withstand to uncertainties that arise from cyber treats and compromises of the cyber
and physical infrastructures, and changing nonlinear dynamics coupled with reducing
overall rotational inertia.
1.1.3 Communication
Figure 1-4. An overview of smart grid communication networks [24].
Communication technologies are the key enablers of the smart grid applications
such as demand response, real-time monitoring, automation, and control, etc. Smart
grid communication networks (SGCN) are typically comprised of several segments,
each of which operates within a specific region of electrical power systems to ensure
information and control message exchange among entities. The communication
characteristics of these segments differ from each other in terms of operation region,
supported application, delay, and bandwidth requirements. In general, the SGNC are
decomposed into three representative networks that are home area networks (HAN),
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neighborhood area networks (NAN) and wide area networks (WAN), as illustrated in
Figure 1-4.
Home Area Networks (HAN)
A HAN is utilized in residential dwellings to support a range of applications such as
smart meters, smart appliances, charging and control of Plug-in Hybrid Electric Vehicles
(PHEVs), and IP multimedia. Typically, HANs need to cover areas of up to 200m2.
Heterogeneity is the biggest challenge in HAN because of different needs of supported
applications such as various data rate and delay requirements. HANs tailor wireless,
wired or hybrid networking technologies such as PLC, Zigbee and Wi-Fi to support
smart applications within the premises.
Neighborhood Area Networks (NAN)
The NAN enables information exchange between a cluster of smart meters at
customer premises and utility company’s WANs. The population of each NAN varies
from a few hundred to a few thousand of smart meters depending on the power grid
topology and the deployed communications technology and protocol. The required
data rate varies depending on deployed applications. While a simple demand meter
reading application only needs a few bps, supporting sophisticated applications such
as advanced distribution automation, fault detection and restoration may require
higher data rates, e.g., a few tens of kbps per meter. It is worth to note that the NAN
is responsible for transporting a huge volume of different types of data and distributing
control signals between utility companies and a large number of devices installed at
customer premises [25]. The NAN can be formed by using power line communication
(PLC), Wi-Fi and cellular technologies.
Wide Area Network (WAN)
WAN is responsible for long-haul communications such as delivering aggregated
data of multiple NANs to utility company’s private networks and ensuring data exchange
among different data concentrators of power generation plants, distributed energy
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resource stations, transmission and distribution grids, control centers, etc [25]. The
WAN may cover a very large area, i.e., thousands of square kilometers and could
aggregate a large number of supported devices and thus require hundreds of megabits
per second (Mbps) of data transmission. WANs are usually enabled by using cellular
networking technology such as WiMaX, 3G, and LTE and fiber optical solutions for
the given long distances among entities. Installation cost of fiber optical networks
and operational cost of cellular network emerge as a problem from utility & business
perspective.
The seamless collaboration of all these segments reveals the need for interop-
erability of various communications technologies to coexist and to meet the require-
ments of each applications in terms of data rates, communications latency, deploy-
ment/maintenance costs. The Electric Power Research Institute (EPRI) and the National
Institute of Standards and Technology (NIST) emphasize that communication between
each component in the smart grid is extremely important to secure the energy genera-
tion and consumption in an efficient way [26].
Currently standardized wireless (e.g., cellular, satellite, microwave, WiMAX, WiFi,
and Zigbee) and wired (e.g, copper cable, fiber optic cable, and power line carrier)
network technologies have been designed specifically for internet communication but
tailored for SGCN. It must be noted that, the internet and smart grid communication
networks pose fundamental differences in terms of bandwidth, latency, and security
requirements. While, the data rate and the fairness, for example, are the key metrics
for internet communication, latency requirements are more stringent in smart grids. For
instance, load shedding for under frequency has a delay allowance of only 10 ms [25].
1.2 Research Motivation
This dissertation looks for answers for following questions arises in smart grid
control and communications:
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1. How to enhance the resiliency of smart grids by addressing transient stability
problem?
2. How to address the negative influence of large penetration of distributed genera-
tions?
3. How to mitigate the effect of uncertainties such as delay, erroneous sensor
measurement, and varying plant parameters in control systems?
4. How to improve the channel access delay and throughput performance of the
smart grid communication networks at the medium access control layer?
1.3 Research Contributions
The contributions of the research can be summarized as follows:
1. A decentralized control framework has been developed to enhance the transient
stability margin of synchronous generators (SG) when a large disturbance such
as loss of large loads or generators occurs. The designed control framework
employs PMU to obtain local measurements and DESS to provide external power
for damping the frequency oscillation quickly when SG are perturbed. A model-
free based nonlinear robust controller with a novel constant and known input
delay compensation technique has been developed and the proposed framework
has been validated on IEEE 39 bus 10 machine test power system via Matlab-
Simulink.
2. The delay compensation technique applied to decentralized control framework
has been leveraged to take care of unknown time-varying delay. Also, the control
framework has been boosted by enabling state estimation function to filter out the
PMU measurement before entering the controller.
3. A distributed control framework has been designed to enhance the transient
stability of smart grids by enabling situational awareness. In addition to the local
measurements, remote data from adjacent buses are considered to calculate
control signal. In contrast to the centralized control architectures such as WACS,
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the distributed control framework reduces the communication burden while
partially maintaining situational awareness. Also, the distributed controller is
advantageous over WACS in terms of cybersecurity. For example, a cyber-attack
to the centralized controller may result in failure of the entire system, however, a
cyber-attack to a distributed controller can only effect a particular area in the power
grid and this area can be isolated to prevent the system from cascaded failures.
4. An adaptive medium access control protocol for smart grid home area networks
have been developed to enhance the throughput and delay performance for the
highly congested network. The increasing traffic throughout network might be
because of either high connectivity or cyber attacks such as denial-of-service.
The proposed MAC protocol maintains the throughput and delay characteristics
of the network even for highly congested networks. Analytical and numerical
studies demonstrate the success of the proposed MAC protocol with respect to the
state-of-art models.
1.4 Dissertation Organization
The rest of the dissertation is organized as follows. Chapter 2 presents a detailed
review on power systems stability and control systems. In Chapter 3, a decentralized
control framework has been introduced to address the transient stability issue of smart
grids. In Chapter 4, the proposed decentralized controller has been extended by
considering cyber-physical limitations and developing a new nonlinear robust controller
to compensate for unknown time-varying time delay. In Chapter 5, a distributed control
framework has been developed to enhance the stability and resiliency of synchronous
generators. In Chapter 6, an adaptive channel access protocol is presented that has
been developed to enhance the throughput and delay performance of HAN. The
conclusion and final remarks are given in Chapter 6.
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CHAPTER 2SMART GRID STABILITY AND CONTROL
In the conventional power systems, generally organized as generation, transmis-
sion, distribution and end-users (customers), the electrical power is generated through
bulk energy sources that are located far away from end-users and first transformed to
high voltage (HV) by step-up transformers before transmitting through long distances. At
the distribution side, the high voltage is reduced to medium voltage (MV) or low voltage
(LV) to provide electrical power to the residential customers and industry.
The smart grid has drastically changed the classical power systems by enabling
two-way power and communication data flow with the increasing integration of dis-
tributed generations (DG) and advanced digital technologies. The large penetration of
DG distribution system is shifting distribution systems from being a passive network,
containing only loads, to an active network. However, the intermittent and inertia-less
nature of distributed energy sources such as wind power, photo voltaic (PV) impacts the
stability of the power systems. Furthermore, equipping the power system components
with intelligent electronic devices to connect them to data network raises cybersecurity
issues besides their advantageous in terms of enhancing operation and management
power systems.
This chapter investigates the existing stability problems in smart grids and dis-
cusses control systems that have been developed for addressing the instability of power
systems. Furthermore, contributions of the state-of-the-art controllers to the resiliency
and the cyber-physical security of the smart grid are studied and the existing problems
that are remained open are presented.
2.1 Smart Grid Stability
Stability of power systems has been considered as critical for secure and reliable
operation of system since 1920s [27] and has been defined by IEEE/CIGRE Joint Task
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Figure 2-1. Classification of power system stability .
Force in [28] as the ability of electrical power systems to regain a state of operation point
after being subjected to a physical disturbance.
Instability of smart grids is a complex problem as it can emerge in various forms
depending on numerous factors. Throughout the history, maintaining the transient
stability has been the dominant issue on most systems including electrical power grids.
With the continuous evolution of power systems through increasing interconnections,
integration of renewable energy sources, and deployment of digital technologies, various
forms of power systems stability have emerged such as frequency stability, voltage
stability, and rotor angle stability. It should be noted that instability of the power systems
must be carefully identified before treating. In [28], the power systems stability has
been defined and categorized as in Figure 2-1 by considering the physical nature of the
resulting mode of instability, the size of the disturbances, and the devices, process and
time spans to assess stability.
2.1.1 Rotor Angle Stability
Rotor angle stability is the ability of the interconnected synchronous machines
(generators) to remain in synchronism being subjected to a large or a small disturbance.
Multiple synchronous machines run parallel and deliver active power to the loads
depends on the rotor angle of the machines. Power system faults such as losing a large
load lead to a sudden changes on the generator electrical power output. However, the
mechanical power input to generators cannot response instantaneously. In steady-state
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condition, there is an equilibrium between the input mechanical power and the electrical
output power of all synchronous machines in interconnected power systems and speed
of the machines remain same.
During a fault, synchronous machines lose the equilibrium which results in the
acceleration or deceleration of the machines. If a synchronous machine temporarily
moves faster relative to the other machines, the rotor angle of the machine will advance
with respect to slow machine. The resulting angular difference lead to increase load
delivered by faster machine and decrease load delivered by slow machine in order to
reduce the speed difference and hence the angular separation. Also, after a certain
point, an increase in angular separation will be followed by decreasing the power
transfer by fast machine which further increases the angular separation. If the kinetic
energy corresponding to the angular separation cannot be absorbed, then instability
occurs and synchronization of a machine or a group of machines will be lost.
The power system stability depends on the existence of synchronizing torque and
damping torque for each synchronous machine. Lack of synchronizing torque causes
non-oscillatory instability and lack of damping torque lead to oscillatory instability. Rotor
angle stability is divided into two subcategories: transient stability and small-signal
stability which are the concern of power system when subjected to a large disturbance
and small disturbance respectively.
2.1.1.1 Transient Stability
Transient stability is the ability of synchronous machines to return to stable condition
and maintaining synchronism after being subjected larges disturbances come out of
switching ON and OFF of the circuit breakers to isolate and clear the faults in perturbed
area in interconnected power systems. Since power systems often experience these
type of faults, the transient stability needs to be studied carefully. The transient stability
depends on the initial states and the severeness of the disturbances. Instability may
take place in the form of angular separation due to insufficient synchronizing torque, that
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Figure 2-2. The dynamic model of synchronous machines.
is also called as first swing instability. In large systems, transient stability may occur as a
result of superposition of a slow inertia swing mode and local plant swing mode leading
a large excursion of rotor angle beyond the first swing [29]. The transient stability is a
short term phenomena, that is, the target time frame for transient stability studies is
usually 3 to 5 seconds following a disturbance. However, the time frame may extend to
10-20 seconds for very large systems with dominant inter-area swings [28].
In order to study the transient stability of a synchronous generators using swing
equation, a synchronous machine, as illustrated in Figure 2-2, can be examined. A
synchronous machine supplied with input mechanical power PM produces a mechan-
ical torque equal to TS that rotates the machine at a speed of ω rad/sec and outputs
electromagnetic torque TE and electrical power PE on the receiving end. In steady state
condition, if the synchronous machine is supplied from one end and a constant load
connected to the other end, a relative angular displacement, , known as load angle δ,
occurs between rotor axis and stator magnetic field in proportional to the loading of the
machine.
A sudden change in loading (add or remove), leads to deceleration or acceleration
of the rotor accordingly with respect to the stator magnetic field and causes swinging of
the rotor speed relative to the stator magnetic field. The relative motion of the load angle
and stator magnetic field is known as swing equation for transient stability of power
system [29–31].
There are numbers of factors that may influence the transient stability of power
systems including generator inertia, generator loading, generator power output during
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fault, and fault clearing time [29]. The inertia have become even critical with increasing
penetration of inertialess renewable energy generations. The decreasing overall inertia
makes transient stability a challenging issue for interconnected smart grid power
systems.
2.1.1.2 Small-Signal Stability
Small-disturbance or small-signal stability is associated with the ability of power
system to resist small disturbances such that the linearization of the system dynamic
model is allowable for stability analysis [29]. Small-signal stability problems can be
resolved into local and global instability problems. Local problems are associated with
only a small part of the power system and depends on the rotor angle oscillation of a
single machine with respect to the rest of the power systems. Damping these oscilla-
tions rely on the strength of the transmission system. excitation control system and plant
output [29]. On the other hand, global problems arises from inter area oscillations where
oscillation of a group of machine in one area of swinging against a group of machines
in another area. The characteristics of the global instability problems are very compli-
cated and load characteristics are the major effects on the inter area stability mode.
The time span for small-signal stability is on the order of 10 to 20 seconds following a
disturbances [28].
2.1.2 Frequency Stability
Frequency stability stands for maintaining the steady frequency of power systems
after being subjected to large disturbances perturbing the load and generation bal-
ance. The frequency instability causes tripping of generating units and/or loads. In
general, large disturbances end up with excursion of frequency, power flows, voltage,
hence advanced control and protection schemes that are required but not included in
conventional transient stability and voltage stability studies.
Frequency stability requires to maintain an equilibrium between loads and genera-
tors with a minimum unintentional loss of loads. In interconnected power systems, this
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instability condition emerges during islanding power networks and arises the questions
of whether or not each island will reach the equilibrium with minimum unintentional loss
of load. The frequency stability problems generally stems from the poor response of
the incorporated equipment and lack of coordination between control and protection
systems [28].
During frequency excursion, the response time of the activated process and devices
range from a fraction of seconds for the response of load shedding, generator control,
and protections, to a several minutes for the response time of the devices such as load
voltage controller and prime mover energy supply systems.
2.1.3 Voltage Stability
Voltage stability aims at maintaining steady voltages at all buses after power system
being subjected to a disturbance from a given initial operating points. Voltage instability
occurs when the equilibrium between load and supply is lost, because the load tends
to restore more power than the capacity of generation [29]. The voltage instability may
end up with losing load or tripping transmission lines and so cascaded outages. Also,
some generators may lose synchronism because of outages or operating conditions that
violate field current limit [28,32].
The voltage stability is analyzed under two subcategories as shown in Figure 2-1
that are small disturbance stability and large disturbance stability. Small-disturbance
voltage stability aims at maintaining steady voltages after power systems being sub-
jected to small disturbances such as load variations. Whereas, large-disturbance
voltage stability targets sustaining all bus voltages within an allowable level following a
large disturbance such as loss of generation, systems faults, presence of contingen-
cies [28, 32]. Also, it is worth to note that the time span for voltage stability problem
ranges from a few seconds that corresponds to short-term, to tens of minutes that
corresponds to long-term voltage stability. The short-term voltage stability comprise of
fast acting load components such as electronically controlled loads, induction motors,
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and HVDC converters. Whereas, the long-term voltage stability includes slow acting
components such as generator current limiters and tap-changing transformers [28].
2.2 Controls for Smart Grid Transient Stability
Reliability is the major concern of the power system design and operation. Main-
taining reliability depends on security of the power system. To be secure, the power
system must be stable and also must be secure against intentional or unintentional
cyber physical disturbances at all level. In conventional power systems, various control
and protection systems have been employed to enhance the reliability, security and
stability of the electrical power grid. However, the power grids have experienced a big
changes with the integration of digital technologies, distributed energy generation and
various smart applications such as demand response, real-time monitoring and control.
The rapid transformation of the power systems into smart grid emerges new security
and stability problems beside numerous advantageous.
The growing complexity of the power systems has left the conventional control
systems insufficient in terms of security and stability. Transient stability, for instance, has
been taken care of local excitation controllers in traditional power system. However, the
increasing penetration of low inertia or inertia-less power generations arises and fuels
the transient stability problem once again. In order to maintain the transient stability
with respect to reducing rotational inertia in power system, robust control architectures
are required. Due to the fact that smart grid has a cyber-physical nature, the proposed
controllers need to be studied with a particular focus on cyber-physical effects and
limitations.
In the literature, control architectures for stability of power systems are categorized
into three groups: i) decentralized (local) controllers, ii) centralized controllers, and iii)
distributed controllers. In this section, different control schemes that fall in these groups
are reviewed.
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2.2.1 Decentralized Control
Decentralized controllers are distributed all over the power systems that operates
locally and perform its own objective rather than global objectives. Most of the excitation
controllers in conventional power systems fall into this category. In decentralized
control, each local controller situated near synchronous generators observes the rotor
speed and rotor angle of its generator and calculate the control signal. Little or no
communication need in decentralized control systems reduces the cost but lack of
information exchange decreases the overall system performance.
Conventional power system stabilizers (PSS) are an excellent example of the local
linear controllers [33–35]. However, PSS are designed to respond to small disturbances,
caused by small load variations, thus their contribution for transient stability is marginal.
Over the last few years, advanced excitation control schemes have been developed to
enhance the robustness of power systems by using nonlinear techniques or linearization
techniques such as direct feedback linearization (DFL). The DFL method has been
proposed in [36–39] to linearize the nonlinear dynamic model of multi-machine power
systems in order to make it possible to use linear control techniques. Even though
these DFL techniques provide a stabilization in large extent, they all require the exact
knowledge of the power system plant parameters which is usually unavailable in
practice [40]. Also, unexpected faults in system and external disturbances could
degrade the stabilizing capability of a controller that is designed for a specific model.
2.2.2 Centralized Control
Centralized controllers are considered advantageous over decentralized controllers
in terms of situational awareness since centralized controllers enable information
exchange globally. The integration of information communication systems makes
possible monitoring the power system components in real-time through sensors and
communication networks and control the entire systems with a broad knowledge. Wide-
area control systems (WACS) are currently implemented centralized control approaches.
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WACS are implemented implemented in addition to the local primary controllers. It
is envisioned that WACS can effectively address the inter-area oscillation problem
since information exchange is enabled [41]. WACS are developing in parallel to the
advancement in communication, sensor and digital signal processing technologies.
Phasor measurement units (PMU), for instance, are one of the advanced sensor
technologies deployed to the power systems in order to measure and transmit the
real-time phasor data with a high precision and in real-time accordingly.
Besides all advantages of WACS structures, the increasing number of PMU
deployment for enhancing observability leads an exponential rise in data volume and
arises communication problems such as time delay. Aggregating information at a
central point to calculate the control action and transmitting control signal back to local
actuators significantly increase the communication overhead. Moreover, the reliability
of centralized controller is low, because communication systems are vulnerable to
cyber-attacks and rely on a single point which increases the risk that any possible attack
may lead the system to instability. In addition, communication latency is another issue
that centralized controller hold due to the long communication distances. Transient
stability, for example, is a short term phenomena and need to be circumvent quickly. If
the latency goes beyond the acceptable rate, it becomes one of the key disturbance by
itself for centralized controller.
2.2.3 Distributed Control
The distributed controller have been a rising trend for multi-agent systems because
of their efficiency in terms of processing and capability of enabling coordination between
agents. The rising communication and security problems in centralized controllers
and lack of information exchange in classical decentralized controller make distributed
control strategies promising for power system stability. In distributed power system
control strategies, first the entire system is divided into small regions and the interaction
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between these regions are maintained through distributed controllers. Since sensors
only transmit data to the associated controller, communication burden is relieved.
Utilizing distributed control approaches do not only ease the communication
burden and decrease latency but also enhance the power system security in contrast
to centralized scheme. For example, if a distributed control agent experience a cyber-
attack, other distributed controllers can sustain their operation by isolating the attacked
controller from the system. Furthermore, distributed controller are usually secondary
controller, hence even if their operation perturbed, the primary local controller will
continue to treat the system.
Distributed controls for networked multi-agent systems have attracted many re-
searchers because of their advantages in reducing communication load while enhancing
the system performance. In [42, 43], authors present distributed consensus controllers
for networked multi-agent systems. A distributed model predictive control (MPC) is
presented in [44] and Venkat et al., uses distributed MPC strategy for power system
automatic generation controller in [45,46].
Furthermore, a distributed control strategy was designed to address transient
stability problem by using parametric feedback linearization (PFL) technique to actuate
external storage sources (ESS) in [47, 48]. Authors aim at damping the oscillation after
power system being subjected a large disturbance by absorbing or injecting power
from generator buses via fast acting EES such as flywheels or batteries. However,
the proposed model is inconsistent with the distributed approach since it explicitly
considers the knowledge of all generator angles and voltages in calculation of power
flow. In addition , the proposed PFL based control requires exact model knowledge of
the dynamic system which is unrealistic for highly nonlinear smart grid power systems.
Furthermore, a distributed frequency control algorithm that is capable of restoring
system frequency after a disturbance is presented in [49]. This method uses a PI-like
controller to actuate the mechanical power input of generators to damp oscillations of
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power systems. Technological limitations of the generator turbine and valve actuation
speeds and time constants may limit the performance and effectiveness of this kind
of approach for system stabilization. One limitation of this method is that it considers
linearized power flow equations, which may introduce errors when generator angles
largely deviate from the equilibrium point during severe disturbances.
Time delay is still an issue even for distributed controllers since even a small
time delay may significantly affect the control performance. Time delay systems have
been thus a major interest in many studies [50]. In recent decades, efforts focused on
designing controllers which are subjected to time delay for linear dynamics [51, 52] and
nonlinear dynamics [53–59]. Compensating the time delay problem has been addressed
for linear systems in [60–64] and for nonlinear systems in [65–68] with exact model
knowledge. In [66–68], predictor based controllers are designed to compensate for
an arbitrary long input time delay by transforming the input delay as a transport partial
differential equation. However, the predictor-based controllers require the exact model
knowledge of the dynamics and do not consider uncertainties in field parameters and
external disturbances. Uncertainties in field parameters and external disturbances are
inevitable in many nonlinear systems such as smart grids. In order to abstain from the
exact model knowledge requirement of the dynamics, several nonlinear controllers
are designed [59, 69–71]. Hence, there is a need for designing controllers that can
compensate for the time delay and external disturbances for uncertain nonlinear
dynamics. The designed controllers [59, 69, 70] consider single-agent systems and
do not consider the communication delay. Therefore, there is a need for distributed
controllers that are robust to communication and control input delay and also external
disturbances for uncertain nonlinear dynamics such as smart grids.
2.3 Summary
In this chapter, the emerging and existing power systems stability problems with
their causes and effects are discussed for current smart grid power systems. Also, the
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state-of-art control systems that are already implemented or proposed for addressing
power system instability are presented. Since the major interest of this thesis is to
develop control systems to enhance the the transient stability of smart grid, the literature
review is extended for controllers that have been developed for the same purposes.
In conclusion, we assert that the transient stability problem is becoming even
more critical with the rapid penetration of inertia-less renewable energy sources.
Also, the integration of information and communication systems has transformed the
power system into cyber-physical system, hence cyber security emerges another
challenging problem. Therefore, we advocate that in order to enhance the resiliency
of the smart grid, advanced control strategies that are robust to cyber disturbances
such as communication delay, contingent sensor measurement and-cyber attacks, and
physical disturbances such as losing loads or generators are required.
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CHAPTER 3A ROBUST DECENTRALIZED CONTROL FRAMEWORK WITH CONSTANT TIME
DELAY COMPENSATION
Reliability is the key to the success of power system that invokes robust control
systems for enhancing the stability margin. The large penetration of distributed genera-
tions with their inertia-less generation units leads to a transient stability problem, which
refers to the ability of synchronous generators to return back to their nominal operation
frequency after being subjected a large disturbance. Transient instability has always
been a major problem in multi-machine interconnected power systems with respect to
varying network configuration, loading, and power flow condition and become even more
dynamic with the integration of intermittent renewable energy sources.
Current excitation control systems implemented for transient stability of power
systems are insufficient to maintain stability during inter-area oscillations. Therefore, in
this chapter, a new nonlinear controller for the synchronous machine excitation system
is presented that uses a novel control input time delay compensation technique and
distributed energy storage sources (DESS) to enhance the transient stability of smart
grids. The designed control framework, shown in Figure 3-1, uses local measurements
(rotor angle and rotor speed) obtained by phasor measurement units connected at
the generator buses and actuates fast acting DESS such as flywheels or batteries to
inject or absorb damping power to the system. The objective is to return the perturbed
synchronous machines back to synchronism as quick as possible.
DESS are currently being deployed in power systems to perform zero-energy
ancillary services, such as load following and regulation, especially due to the increasing
penetration of intermittent solar and wind power sources [72]. The presented control
framework adds a function to DESS by using them for transient stability. PMU sensors
are employed because of their capability in providing real-time data to controller and
other power system functions to enhance visibility of entire system.
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Figure 3-1. An overview of decentralized control framework for transient stability.
As the designed decentralized control framework can be used to address transient
instability problem by itself, it can also be used as a backup controller to Wide-area
control systems (WACS). Due to the centralized nature of WACS, they may suffer from
large communication delay, cyber disturbances and loss of remote sensors. Hence, a
backup controller like primary excitation controllers is needed to enhance the resiliency
of the smart grids.
Time delay is inherent for all systems and significantly affects the performance
of the incorporated applications. The time delay in the proposed control framework
arises from the communication between sensor and controller, processing in controller
and response time of the DESS. To mitigate the effect of time delay and uncertainties
arise from varying plant parameters and cyber disturbances, the proposed nonlinear
robust controller is leveraged by developing a novel delay compensation technique and
considering the time-varying additive disturbances in the dynamic model.
The Lyapunov stability analysis proves that all error tracking signals are globally
uniformly ultimately bounded (GUUB) and the decentralized nonlinear controller can
guarantee the system stability over the whole operating region regardless of fault loca-
tions or parameter uncertainties of the transmission network. Furthermore, the designed
decentralized control framework was implemented on IEEE 39 bus 10 machine test
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power system through Matlab/Simulink and validated with respect to varying fault loca-
tions, DESS capacity, control input time delay and parametric uncertainties. Simulation
results demonstrate the success of the proposed control framework in damping the
post-fault frequency oscillation very quickly.
3.1 Dynamic Model of Synchronous Machines
Multi-machine power systems consist of n synchronous generators, which are
interconnected through a transmission network. The transient stability of synchronous
generators are studied by using swing equations defined in [29–31,73] as:
δ̇i = ωi,
ω̇i =1
Mi(−Diωi + Pm,i − Pe,i) , (3–1)
where ωi ∈ R is the rotor speed deviation from the synchronous rotating reference
of generator i in radian per second (rad/s), which is the difference between electrical
actual rotor speed ωacti ∈ R (rad/s) and synchronous rotor speed ωo ∈ R (rad/s),
ωi = ωacti − ω0 and ω̇i ∈ R is the acceleration of the generator i. The δi ∈ R denotes
the rotor angle deviation from the synchronous rotating reference of the generator i in
radian, equivalent to the transient internal voltage angle of the machine [29]. Di is per
unit damping constant and Mi denotes the normalized inertia constant, given in s2/rad.
The difference between mechanical power input (Pm,i) and electrical power output (Pe,i),
both are in p.u, is defined as the accelerating power (Pa,i), that is, (Pa,i = Pm,i−Pe,i). Pm,i
can be assumed as constant for transient stability analysis and Pe,i can be calculated by
using the following power flow equation.
Pe,i =κ∑k=1
|Ei| |Ek|(Gik cos (δi−δk)+Bik sin (δi−δk)) , (3–2)
where κ ∈ R is the set of buses connected to bus i, Gik ∈ R denotes the equivalent
conductance between the buses i and k, while Bik ∈ R is the equivalent susceptance
40
-
between the buses i and k. Ei, Ek ∈ C are the voltages of buses i and k, respectively,
while δi ∈ R and δk ∈ R are their respective angles.
3.2 Robust Nonlinear Controller Design
By considering the external damping power absorbed or injected through DESS, the
swing equation (3–1) modifies as follows:
ω̇i =1
Mi(−Diωi + Pa,i + di (t) + ui(t− τi)) , (3–3)
where, ui (t− τi) ∈ R represents the external generalized delayed input control signal
which corresponds to the DESS power output. τi ∈ R is a known constant non-negative
time delay and t0 ∈ R is the initial time. Also, di : [t0,∞) → R denotes uncertain
time-varying exogenous disturbance stems from uncertainties in power system. The
controller is developed based on the following assumptions:
Assumption 1. The rotor angle (δi) and rotor speed (ωi) are measurable.
Assumption 2. Mi is bounded by known, positive, constants such that mi ≤ Mi ≤ m̄i,
where m̄i,mi ∈ R. Di and Pe,i are also bounded by a known constants.
Assumption 3. The unknown nonlinear exogenous disturbance and its first time
derivative exist and are bounded by known positive constants [74].
Assumption 4. δid ∈ R, is designed such that the δid refers to the pre-fault value of δi.
Assumption 5. The input delay is a known non-negative constant. Also, it is assumed
that the system in (3–1) does not escape to infinity during the time interval [t0, t0 + τi]
[59].
The objective of the control design is to ensure that the actual rotor angle of
each generator (δi) tracks its desired rotor angle (δid) despite a known constant input
41
-
delay, additive disturbances and uncertainties in the dynamics. To quantify the control
objective, a measurable auxiliary tracking error, denoted by e0i ∈ R is defined as
e0i =
∫ t0
(δi (θ)− δd,i (θ)) dθ. (3–4)
where the first time derivative of e0i quantifies the control objective. To facilitate the
subsequent analysis, auxiliary tracking errors, denoted by e1i ∈ R, defined as
e1i = ė0i + αie0i (3–5)
where αi ∈ R is an adjustable, positive, constant control gain.
In order to compensate the input delay, an auxiliary error signal denoted by eui ∈ R
is developed to to inject a delay-free input signal and cancel the delayed input signal in
the closed-loop error system as follows:
eui =
∫ tt−τi
ui (θ) dθ. (3–6)
Furthermore, an auxiliary tracking errors, denoted by ri ∈ R, defined as
ri = ė1i + βie1i + ηieui, (3–7)
where βi, ηi ∈ R are adjustable, positive, constant control gains. Based on the sub-
sequent stability analysis, the following continuous robust controller is is designed
as
ui = −kiri, (3–8)
where ki ∈ R are positive, adjustable, constant control gains. Taking the time derivative
of (3–7) and using (3–3)-(3–5), (3–6), and (3–8), the closed-loop dynamics for ri can be
obtained as
ṙi =
(αi + βi −
DiMi
)ωi +
1
MiPa,i +
diMi−(ηi −
1
Mi
)ui(t− τi)
+αiβi (e1i − αie0i)− ηikiri. (3–9)
42
-
To facilitate the stability analysis, the expressions in (3–9) can be segregated as terms
that can be upper bounded by a state-dependent function and by a constant, such that
ṙi = Ñi +Ni − e1i +(ηi −
1
Mi
)kiri(t− τi)− ηikiri (3–10)
where the auxiliary terms Ñi, Ni ∈ R can be defined as
Ñi ,
(αi + βi −
DiMi
)ωi + αiβi (e1i − αe0i) (3–11)
Ni ,1
MiPa,i +
diMi
. (3–12)
Remark 3.1. By using Assumption 2, an upper bound can be obtained for (3–11) as∣∣∣Ñi∣∣∣ ≤ψ1i ‖zi‖ , (3–13)where ψ1i ∈ R is a known positive constant and zi ∈ R4 is the vector of error signals
defined as
zi , [e0i, e1i, ri, eui]T . (3–14)
Remark 3.2. Ni is upper bounded by a known constant, by Assumptions 2,
supt∈ R
|Ni| ≤ ψ2i, (3–15)
where ψ2i ∈ R is a known positive constant .
To facilitate the subsequent stability analysis, auxiliary bounding positive constants
σi,Ωi ∈ R are defined as
σi,min
{(αi− 12
),(βi− η
2i
2ε1i−1
2
),(ω2i3τi−ε1i
), ηiki
8
}(3–16)
Ωi ,min
{σi2,ω2ik
2i
3,
1
3τi
}(3–17)
43
-
where �1i, ω2i ∈ R are known, positive constants. It should be noted that �1i, ω2i ∈ R are
not implemented in the control law but will be used for stability analysis. Also, σi and Ωi
will be used as bounding constants (for convergence decay rate and definition of the
domain of attraction) in Section 3.3. As a conclusion, the result is global in the sense
that D = SD = R5.
3.3 Lyapunov Stability Analysis
Theorem 3.1. Given the dynamics in (3–1), the controller given in (3–8) ensures
globally uniformly ultimately bounded tracking in the sense that
‖ei (t)‖ ≤ �0i exp (−�1it) + �2i, (3–18)
where �0i , (1 + αi)√
2Vi (t0)− 2λ2iΦ2i
Ωimiηiki, �1i , − Ωiλ2i (t− t0) and �2i , (1 + αi)
√2λ2iΦ2i
Ωimiηiki.
The control gains are selected sufficiently large relative to the initial conditions of the
system such that the following conditions are satisfied.
αi >1
2, (3–19)
βi >η2i
2ε1i+
1
2, (3–20)
ηi <1
mi+ ψ3i, (3–21)
ki ≥2ψ1iηiσi
, (3–22)
ω2i >3τiε1i, (3–23)
τi ≤ηi8− (2φ
2i
�1i+ψ23iηi
) (3–24)
Proof. Let V : D → R be a continuously differentiable Lyapunov function candidate
defined as
Vi,1
2eT0ie0i +
1
2eT1ie1i +
1
2rTi ri +
φi2eTiueiu +Q1i +Q2i, (3–25)
44
-
where Q1i, Q2i ∈ R are defined as
Q1i ,
(ψ23ik
2i
ηiki+φ2i kiε1i
) t∫t−τi
ri (θ)2 dθ, (3–26)
Q2i ,ω2i
t∫t−τi
t∫s
u2i (θ) dθds, (3–27)
and let yi ∈ R5 be defined as
yi ,
[zi,√Q1i,√Q2i
]T. (3–28)
The following inequalities can be obtained for (3–25) as
λ1i ‖yi‖2 ≤ Vi ≤ λ2i ‖yi‖2 , (3–29)
where λ1i , min{12 ,φi2} andλ2i , max{φi2 , 1}. The time derivative of (3–26), (3–27) and
using (3–5)-(3–6), (3–10), the time derivative of (3–25) can be obtained as
V̇i = eT0i (e1i − αe0i) + eT1i (ri − βie1i − ηieiu) + φieTuiki (ri − ri(t− τi))
+ rTi
(Ñi +Ni − e1i +
(ηi −
1
Mi
)kiri(t− τi)− ηikiri
)
+
(ψ23ik
2i
ηiki+φ2i kiε1i
)(r2i − r2i (t− τi)
)+ ω2i
τik2i r2i − t∫t−τi
u2i (θ) dθ
(3–30)After completing the squares for ri with rTi Ñi, rTi Ni, applying Young Inequality for cross
terms in (3–30), the following upper bound can be obtained for (3–30) as
V̇i ≤ −(αi −
1
2
)e20i −
(βi −
η2i2ε1i− 1
2
)e21i + ε1ie
2ui +
ψ1iηiki‖zi‖2 +
1
ηikiψ22i
−(ηiki8−(φ2i kiε1i
+ψ23ik
2i
ηiki+φ2i kiε1i
+ ω2iτik2i
))r2i − ω2i
t∫t−τi
u2i (θ) dθ (3–31)
45
-
The Cauchy-Schwartz inequality is used to develop the following upper bound for e2ui.
e2ui ≤ τi
t∫t−τi
u2i (θ) dθ. (3–32)
The following upper bound can be obtained for Q2i as
Q2i ≤ ω2iτi sups�[t−τi,t]
t∫s
u2i (s) ds
≤ ω2iτi t∫t−τi
u2i (θ) dθ. (3–33)
Using (3–8), (3–26), (3–32), (3–33) and the gain condition (3–24), the following upper
bound can be obtained for (3–30) as
V̇i ≤ −(αi −
1
2
)e20i −
(βi −
η2i2ε1i− 1
2
)e21i −
ηiki8r2i −
(ω2i3τi− ε1i
)e2ui
+ψ1iηiki‖zi‖2 −
ω2ik2i
3Q1i −
Q2i3τi
+1
ηikiψ22i (3–34)
Using the definitions of zi in (3–14) and σi in (3–16), and the gain conditions (3–19),
(3–20), (3–23) an upper bound can be obtained for (3–34) as
V̇i ≤ −(σi2− ψ1iηiki
)‖zi‖ 2 −
σi2‖zi‖ 2 −
ω2ik2i
3Q1i −
Q2i3τi
+1
ηikiψ22i (3–35)
Using the definition of Ωi in (3–17), the gain condition in (3–22), the definition of yi and
(3–29), an upper bound can be obtained for (3–35) as
V̇i ≤ −Ωiλ2i
Vi +1
ηikiψ22i (3–36)
The solution of the differential equation in (3–36) can be obtained as
Vi (t) ≤ Λi (3–37)
46
-
where Λi , Vi (t0) e− Ωiλ2i
(t−t0) +ψ22iλ2iδiηiki
(1− e−
Ωiλ2i
(t−t0))
. Using (3–25) and (3–37), the
following inequalities can be obtained for e0i, e1i, ri and eui as
|e0i| ≤√
2Λi, |e1i| ≤√
2Λi,
|ri| ≤√
2Λi, |eui| ≤√
2
φΛi.
By using the time derivative of (3–4) and (3–5), |δi − δid| can be upper bounded as
|δi − δd,i| ≤ (1 + αi)√
2Λi,
By using (3–1), (3–4) and (3–5), |ωi − ωd,i| can be upper bounded as
|ωi − ωd,i| ≤(
1 + βi +ηiφi
)√2Λi.
It is concluded that by using the Theorem 4.18 in [75], y is semi-globally uniformly
ultimately bounded where uniformity in initial time can be concluded from the indepen-
dence of δi and the ultimate bound from to. Since e0i, e1i, ri and eui ∈ L∞, then from
(3–8), ui ∈ L∞. Analysis of the closed-loop system shows that the remaining signals are
bounded.
3.4 Simulation and Results
The developed control framework has been implemented and validated on the IEEE
39 bus 10 machines test power system via Matlab-Simulink. The model parameters
of test power system were obtained from [31, 76] and given in Appendix A. The power
output capacity of each connected DESS (PDESS ) is rated to the mechanical power
output of the associated generator, that is, ( PDESS = ρPm ). Also, desired rotor angles
values (δd,i ) are set to their own pre-fault values for the sake of easiness as suggested
in [48]. In addition, The controller gains, given in Table 3-1, are found with respect to the
gain conditions given in (3–19) - (3–24).
47
-
Table 3-1. Decentralized controller gain settings for known constant time delay case.αi βi ηi ki
Generator 1 0.01 0.08 60 3.85
Generator 2 0.01 0.08 60 0.23
Generator 3 0.01 0.08 60 0.27
Generator 4 0.01 0.08 60 0.22
Generator 5 0.01 0.08 60 0.20
Generator 6 0.01 0.08 60 0.26
Generator 7 0.01 0.08 60 0.20
Generator 8 0.01 0.08 60 0.18
Generator 9 0.01 0.08 60 0.26
Generator 10 0.01 0.08 60 0.32
The objective of the control framework is to recover the perturbed synchronous
generators after a major disturbance. Therefore, a solid three-phase fault is applied
at bus 17 in line 16-17 at to=0.5 s in order to test the stabilization performance of the
controller. Afterwards, the fault is cleared by opening circuit breakers within clearing
time that is set to 100 ms unless otherwise specified. The controller takes action
and actuates the DESS to inject or absorb power according to the control signal
after 100 ms. The performance of the proposed control framework is quantified in
terms of stabilization time that is calculated as the time between fault inception and
convergence of all generators speed to the synchronous frequency of 60 Hz within a
tolerance of 0.1%, that is, [59.94-60.06] Hz. This stabilization criterion is inspired by the
Frequency Trigger Levels of 0.05 Hz deviation by North American Electric Reliability
Corporation [77]. Finally, the simulation time was set to 20 ms and beyond that time limit
refers to losing stability and failure of controller.
The frequency oscillation and rotor angle deviation of all generator during and after
fault, shown in Figure 3-2 over time, demonstrate the stabilization performance of the
proposed controller when the control input delay and maximum capacity of DESS are
48
-
0 1 2 3 4 5 6 7 8 9 10
Time (seconds)
0
10
20
30
40
50
60
70
80
90A
ng
le -δ (
Deg
ree)
δ
1
δ2
δ3
δ4
δ5
δ6
δ7
δ8
δ9
0 1 2 3 4 5 6 7 8 9 10
Time (seconds)
59.6
59.7
59.8
59.9
*59.94
60
*60.06
60.1
60.2
60.3
60.4
60.5
Spee
d (
ω )
Hz
ω1
ω2
ω3
ω4
ω5
ω6
ω7
ω8
ω9
ω10
Figure 3-2. Rotor angle and speed deviation of synchronous machines during and afterthree phase fault.
set to τi=10 ms and ρi=0.2 respectively. Furthermore, the response of the controller with
respect to varying control input delay, DESS power output capacity and the magnitude
of additive disturbance were evaluated.
It should be noted that all PSS controllers were disabled in this simulation to make
the condition more aggressive. First, the performance of the designed control framework
was demonstrated in Figure 3-3 with respect to varying DESS capacity and control
input time delay. The simulation results show that the proposed control framework
can stabilize the frequency oscillation within [6-8] s based on the time delay (τi) when
5 10 15 20 25 30 35
DESS power output capacity - ρ
0
1
2
3
4
5
6
7
8
9
10
Sta
bil
izati
on
tim
e [
s]
τi =10ms
τi =50ms
τi =100ms
τi =130ms
Figure 3-3. Stabilization time versus varying DESS capacity and time delay.
49
-
0.05 0.1 0.15 0.2 0.25
Fault clearing time [s]
0
2
4
6
8
10
12
14
16
18
20
Sta
biliz
ati
on
tim
e [
s]
Decentralized (τi =10ms)
Decentralized (τi =50ms)
Decentralized (τi =100ms)
Decentralized (τi =130ms)
MBPSS
Figure 3-4. Stabilization time versus clearing ti