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E-raamat: Power System SCADA and Smart Grids

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(Jamia Millia Islamia, New Delhi, India), (GE Energy Management - Digital Energy, Atlanta, Georgia, USA)
  • Formaat: 352 pages
  • Ilmumisaeg: 19-Dec-2017
  • Kirjastus: CRC Press Inc
  • ISBN-13: 9781351831260
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Power System SCADA and Smart GridsSuurem pilt
  • Formaat: 352 pages
  • Ilmumisaeg: 19-Dec-2017
  • Kirjastus: CRC Press Inc
  • ISBN-13: 9781351831260
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Power System SCADA and Smart Grids brings together in one concise volume the fundamentals and possible application functions of power system supervisory control and data acquisition (SCADA). The text begins by providing an overview of SCADA systems, evolution, and use in power systems and the data acquisition process. It then describes the components of SCADA systems, from the legacy remote terminal units (RTUs) to the latest intelligent electronic devices (IEDs), data concentrators, and master stations, as well as:Examines the building and practical implementation of different SCADA systemsOffers a comprehensive discussion of the data communication, protocols, and media usageCovers substation automation (SA), which forms the basis for transmission, distribution, and customer automationAddresses distribution automation and distribution management systems (DA/DMS) and energy management systems (EMS) for transmission control centersDiscusses smart distribution, smart transmission, and smart grid solutions such as smart homes with home energy management systems (HEMs), plugged hybrid electric vehicles, and morePower System SCADA and Smart Grids is designed to assist electrical engineering students, researchers, and practitioners alike in acquiring a solid understanding of SCADA systems and application functions in generation, transmission, and distribution systems, which are evolving day by day, to help them adapt to new challenges effortlessly. The book reveals the inner secrets of SCADA systems, unveils the potential of the smart grid, and inspires more minds to get involved in the development process.

Arvustused

"... a must-have text on this subject. It provides not only students, but those who deal with SCADA, insight into the various technologies and systems that exist along with their differencesboth strengths and weaknesses. ... a very thoughtful resource on such an important, and rapidly changing, topic. This book also provides the next generation of power engineers with a ready reference to understand where we have been and where we can go in the not-too-distant future." David W. Roop, from IEEE Power and Energy Magazine, January/February 2016

"As a power system operator having nearly four decades of experience and as an end user of the supervisory control and data acquisition (SCADA) systems, I have always found the available literature on SCADA as limited and in the form of documents by vendors or in the form of research papers. This book is a first of its kind in the sense that it is vendor neutral and very lucidly brings out various fundamental concepts related to SCADA. The book provides an excellent reference material both for beginners and practicing professionals. I would strongly recommend the book to all power system engineers as an essential reference material. It provides an understanding of the historical and legacy systems as well as an insight into the new technologies. Automation is the key to the future, and the book appropriately delves into this aspect." Sushil Kumar Soonee, Power System Operation Corporation, New Delhi, India

"The authors cover all of the building blocks and detailed functionality of electric power SCADA systems, including a good deal of legacy hardware and older techniques. This is important because most large existing systems contain a mix of new and old equipment, with the latter being very poorly documented and therefore hard for newcomers in the field to understand. I would recommend this book to college students/new graduates as well as professionals coming from other industries who want to understand how electric power SCADA got to where it is, why it is evolving into new technologies, and what types of real-world challenges they will be encountering." Michael Thesing, Patterson & Dewar Engineers, Inc., Norcross, Georgia, USA

"Each topic, like SCADA system and remote terminal unit (RTU), has been introduced with a simple block diagram showing the various components followed by description of each component thereof. This approach will immensely help the student to learn the topic easily and systematically. Photographs of actual (commercially available) products like RTUs and relay intelligent electronic devices (IEDs) make the book very useful to students who are about to enter the engineering profession and to practicing engineers. Advanced topics like alarm suppression techniques and intelligent electronic devices have been dealt with thoroughly. A laboratory implementation of SCADA, named SCADA lab, will be very useful as a learning model to students and as a research model to researchers. A full chapter on SCADA communications does justice to this topic. The following topics are very well addressed in the book: small, medium, and large master stations; software modules of master stations; and human-machine interface (HMI) hardware components and software functionalities. Issues like open and proprietary systems and message security enhance the value of this book. Case studies in SCADA systems give an insight into the practical SCADA systems. The concepts of single master - single RTU, single master - multiple RTU, and multiple master - multiple RTU have been explained with simple block schematics. The authors have a long experience of teaching the subject and working in the area, and the book has been written well. In my view, there was a long-felt need for a book of this type. The book does full justice to the subject of SCADA." HK Verma, Sharda University, Greater Noida, India

"The book is well written and well organized with good details to describe the basic concepts and key features of SCADA systems, including the overall system architecture, key components, functionalities, and the applications, as well as the adjacent sub-systems, such as the communication systems and the filed electronic devices. A few practical application example cases are also included in the book, which will be very useful references for the readers." Jiyuan Fan, Southern States LLC, Hampton, Georgia, USA

"This book provides the fundamentals of SCADA for power system applications. It explains why SCADA systems were developed and how they evolved into the systems in use today, and describes new technologies, e.g., phasor measurement units (PMUs), and their applications. There is also a concise overview of various "smart grid" technologies covering microgrids (AC and DC), PMUs, and DC power systems.

Using this book, students, academics, and working power system engineers will quickly learn how the SCADA system works in substations, transmission, and distribution power systems, and be conversant with the new types of systems used in "smart" grids." John Shea, IEEE Electrical Insulation Magazine, January/February 2018

Preface xvii
The authors xix
Chapter 1 Power system automation
1(20)
1.1 Introduction
1(1)
1.2 Evolution of automation systems
2(2)
1.2.1 History of automation systems
3(1)
1.3 Supervisory control and data acquisition (SCADA) systems
4(3)
1.3.1 Components of SCADA systems
5(1)
1.3.2 SCADA applications
6(1)
1.4 SCADA in power systems
7(3)
1.4.1 SCADA basic functions
7(1)
1.4.2 SCADA application functions
7(1)
1.4.2.1 Generation SCADA application functions
8(1)
1.4.2.2 Transmission SCADA application functions
9(1)
1.4.2.3 Distribution automation application functions
9(1)
1.5 Advantages of SCADA in power systems
10(2)
1.5.1 Deferred capital expenditure
10(1)
1.5.2 Optimized operation and maintenance costs
11(1)
1.5.3 Equipment condition monitoring (ECM)
11(1)
1.5.4 Sequence of events (SOE) recording
11(1)
1.5.5 Power quality improvement
11(1)
1.5.6 Data warehousing for power utilities
12(1)
1.6 Power system field
12(5)
1.6.1 Transmission and distribution systems
12(2)
1.6.2 Customer premises
14(1)
1.6.3 Types of data and signals in power system
14(1)
1.6.3.1 Analog signals
14(1)
1.6.3.2 Data acquisition systems
15(1)
1.6.3.3 Digital signals
16(1)
1.6.3.4 Pulse signals
17(1)
1.7 Flow of data from the field to the SCADA control center
17(1)
1.8 Organization of the book
18(1)
1.9 Summary
19(2)
Bibliography
19(2)
Chapter 2 SCADA fundamentals
21(54)
2.1 Introduction
21(1)
2.2 Open system: Need and advantages
21(1)
2.3 Building blocks of SCADA systems
22(2)
2.4 Remote terminal unit (RTU)
24(11)
2.4.1 Evolution of RTUs
24(1)
2.4.2 Components of RTU
25(1)
2.4.3 Communication subsystem
26(1)
2.4.3.1 Communication protocols
27(1)
2.4.3.2 Message security
27(1)
2.4.3.3 Multi-port communication
27(1)
2.4.4 Logic subsystem
27(1)
2.4.4.1 Time keeping
28(1)
2.4.4.2 Data acquisition and processing
28(1)
2.4.4.3 Digital data acquisition
28(1)
2.4.4.4 Analog data acquisition
29(1)
2.4.4.5 Analog outputs
29(1)
2.4.4.6 Digital (contact) output
29(1)
2.4.4.7 Pulse inputs
30(1)
2.4.4.8 Pulse outputs
30(1)
2.4.5 Termination subsystem
30(1)
2.4.5.1 Digital terminations
31(1)
2.4.5.2 Analog terminations
31(1)
2.4.6 Testing and human-machine interface (HMI) subsystem
31(1)
2.4.7 Power supplies
32(1)
2.4.8 Advanced RTU functionalities
32(1)
2.4.8.1 Multi-port and multi-protocol operation
33(1)
2.4.8.2 Digital interface to other electronic devices
33(1)
2.4.8.3 Closed-loop control, computation, and optimization at the RTU level
34(1)
2.4.8.4 Interface to application functions
34(1)
2.4.8.5 Advanced data processing
34(1)
2.4.8.6 Other functions
35(1)
2.5 Intelligent electronic devices (IEDs)
35(11)
2.5.1 Evolution of IEDs
35(1)
2.5.2 IED functional block diagram
36(2)
2.5.3 Hardware and software architecture of the IED
38(1)
2.5.4 IED communication subsystem
38(2)
2.5.5 IED advanced functionalities
40(1)
2.5.5.1 Protection function including phasor estimation
40(2)
2.5.5.2 Programmable logic and breaker control
42(1)
2.5.5.3 Metering and power quality analysis
42(2)
2.5.5.4 Self-monitoring and external circuit monitoring
44(1)
2.5.5.5 Event reporting and fault diagnosis
44(1)
2.5.6 Tools for settings, commissioning, and testing
45(1)
2.5.7 Programmable LCD display
45(1)
2.5.8 Typical IEDs
45(1)
2.6 Data concentrators and merging units
46(1)
2.6.1 RTUs, IEDs, and data concentrator
46(1)
2.6.2 Merging units and IEDs
46(1)
2.7 SCADA communication systems
46(1)
2.8 Master station
46(8)
2.8.1 Master station software components
47(1)
2.8.1.1 Basic SCADA software
47(1)
2.8.1.2 Advanced SCADA application functions
48(1)
2.8.2 Master station hardware components
48(1)
2.8.3 Server systems in the master station
48(1)
2.8.3.1 SCADA server
49(1)
2.8.3.2 Application server
49(1)
2.8.3.3 ISR or HIM server
49(1)
2.8.3.4 Development server
50(1)
2.8.3.5 Network management server
50(1)
2.8.3.6 Video projection system
50(1)
2.8.3.7 CFE (communication front end) and FEP (front-end processor)
50(1)
2.8.3.8 ICCP server
50(1)
2.8.3.9 Dispatcher training simulator (DTS) server
51(1)
2.8.4 Small, medium, and large master stations
51(1)
2.8.5 Global positioning systems (GPS)
52(1)
2.8.6 Master station performance
53(1)
2.9 Human-machine interface (HMI)
54(8)
2.9.1 HMI components
54(1)
2.9.1.1 Operator console
54(1)
2.9.1.2 Operator dialogue
55(1)
2.9.1.3 Mimic diagram
55(1)
2.9.1.4 Peripheral devices
55(1)
2.9.2 HMI software functionalities
55(1)
2.9.3 Situational awareness
56(1)
2.9.4 Intelligent alarm filtering: Need and technique
57(1)
2.9.5 Alarm suppression techniques
58(1)
2.9.5.1 Area of responsibility (AOR) alarm filtering
58(1)
2.9.5.2 Alarm point priority filtering
59(1)
2.9.5.3 Timed alarm suppression
59(1)
2.9.5.4 Knowledge-based alarm suppression
60(1)
2.9.6 Operator needs and requirements
61(1)
2.10 Building the SCADA systems, legacy, hybrid, and new systems
62(1)
2.11 Classification of SCADA systems
62(3)
2.11.1 Single master--single remote
62(1)
2.11.2 Single master--multiple RTU
63(1)
2.11.3 Multiple master--multiple RTUs
63(1)
2.11.4 Single master, multiple submaster, multiple remote
64(1)
2.12 SCADA implementation: A laboratory model
65(5)
2.12.1 The SCADA laboratory
65(1)
2.12.2 System hardware
66(1)
2.12.3 System software
67(2)
2.12.4 SCADA lab field design
69(1)
2.13 Case studies in SCADA
70(2)
2.13.1 "Kentucky utility fires up its first SCADA system"
71(1)
2.13.2 "Ketchikan Public Utilities finds solutions to outdated, proprietary RTUs"
71(1)
2.13.3 "Overwhelmed by alarms: The blackout puts filtering and suppression technologies in the spotlight"
71(1)
2.13.4 "North Carolina Municipal Power Agency boosts revenue by replacing SCADA"
71(1)
2.14 Summary
72(3)
Bibliography
72(3)
Chapter 3 SCADA communication
75(58)
3.1 Introduction
75(1)
3.2 SCADA communication requirements
76(1)
3.3 Smart grid communication infrastructure
76(3)
3.3.1 Quality of services (QoS)
78(1)
3.3.2 Interoperability
78(1)
3.3.3 Scalability
78(1)
3.3.4 Security
78(1)
3.3.5 Standardization
79(1)
3.4 SCADA communication topologies
79(2)
3.4.1 Point to point and multi-drop
79(1)
3.4.2 Bus topology
80(1)
3.4.3 Ring topology
80(1)
3.4.4 Star topology
81(1)
3.4.5 Mesh topology
81(1)
3.4.6 Data flow: Simplex and duplex
81(1)
3.5 SCADA data communication techniques
81(1)
3.5.1 Master-slave
81(1)
3.5.2 Peer-to-peer
82(1)
3.5.3 Multi-peer (broadcast and multicast)
82(1)
3.6 Data communication
82(7)
3.6.1 Components of a data communication system
83(1)
3.6.2 Transmission of digital signals
83(1)
3.6.2.1 Baseband communication
83(1)
3.6.2.2 Broadband communication
84(1)
3.6.3 Modes of digital data communication
84(1)
3.6.3.1 Synchronous data transmission
84(1)
3.6.3.2 Asynchronous data transmission
85(1)
3.6.4 Error detection techniques
85(1)
3.6.4.1 Parity check
86(1)
3.6.4.2 Checksum error detection
86(1)
3.6.4.3 Cyclic redundancy check (CRC)
86(1)
3.6.5 Media access control (MAC) techniques
87(1)
3.6.5.1 Polling
87(1)
3.6.5.2 Polling by exception
87(1)
3.6.5.3 Token passing
88(1)
3.6.5.4 Time division multiplex media access
88(1)
3.6.5.5 Carrier sense multiple access with collision detection (CSMA/CD)
88(1)
3.7 SCADA communication protocol architecture
89(11)
3.7.1 OSI seven-layer model
90(6)
3.7.2 Enhanced performance architecture (EPA) model
96(2)
3.7.3 TCP/IP model
98(2)
3.8 Evolution of SCADA communication protocols
100(1)
3.9 SCADA and smart grid protocols
101(17)
3.9.1 Modbus
101(1)
3.9.1.1 Modbus message frame
101(1)
3.9.2 IEC 60870-5-101/103/104
102(1)
3.9.2.1 Protocol architecture
103(1)
3.9.2.2 IEC 60870 message structure
104(2)
3.9.3 Distributed network protocol 3 (DNP3)
106(1)
3.9.3.1 DNP3 protocol structure
106(1)
3.9.3.2 DNP3 message structure
106(1)
3.9.4 Inter-control center protocol (ICCP)
107(2)
3.9.5 Ethernet
109(1)
3.9.6 IEC 61850
110(2)
3.9.7 IEEE C37.118: Synchrophasor standard
112(1)
3.9.7.1 Measurement time tag from synchrophasor
113(1)
3.9.7.2 Reporting rates
113(1)
3.9.7.3 Message structure
113(2)
3.9.8 Wireless technologies for home automation
115(1)
3.9.8.1 ZigBee
115(1)
3.9.8.2 ZigBee devices
115(1)
3.9.8.3 Wi-Fi
116(1)
3.9.9 Protocols in the power system: Deployed and evolving
116(2)
3.10 Media for SCADA and smart grid communication
118(1)
3.11 Guided media
118(6)
3.11.1 Twisted pair
118(1)
3.11.2 Coaxial (coax) metallic cable
119(1)
3.11.3 Optical fiber
120(1)
3.11.4 Power line carrier communication (PLCC)
121(1)
3.11.4.1 Power line carrier (PLC)
121(1)
3.11.4.2 Distribution line carrier (DLC)
121(1)
3.11.4.3 Broadband over power lines (BPL)
122(1)
3.11.5 Telephone-based systems
122(1)
3.11.5.1 Telephone lines: Dial-up and leased
122(1)
3.11.5.2 ISDN (integrated services digital network)
123(1)
3.11.5.3 Digital subscriber loop (DSL)
123(1)
3.12 Unguided (wireless) media
124(3)
3.12.1 Satellite communication
124(1)
3.12.2 Radio (VHF, UHF, spread spectrum)
124(1)
3.12.3 Microwaves
125(1)
3.12.4 Cellphone
126(1)
3.12.5 Paging
126(1)
3.13 Communication media: Utility owned versus leased
127(1)
3.14 Security for SCADA and smart grid communication
128(2)
3.15 Challenges for SCADA and smart grid communication
130(1)
3.16 Summary
131(2)
Bibliography
131(2)
Chapter 4 Substation automation (SA)
133(44)
4.1 Substation automation: Why? Why now?
133(1)
4.1.1 Deregulation and competition
133(1)
4.1.2 Development of intelligent electronic devices (IEDs)
133(1)
4.1.3 Enterprise-wide interest in information from IEDs
134(1)
4.1.4 Implementation and acceptance of standards
134(1)
4.1.5 Construction cost savings and reduction in physical complexity
134(1)
4.2 Conventional substations: Islands of automation
134(3)
4.3 New smart devices for substation automation
137(2)
4.3.1 IEDs
137(1)
4.3.2 New instrument transformers with digital interface
138(1)
4.3.3 Intelligent breaker
139(1)
4.3.4 Merging units (MUs)
139(1)
4.4 The new integrated digital substation
139(6)
4.4.1 Levels of automation in a substation
140(1)
4.4.2 Architecture functional data paths
141(2)
4.4.3 Data warehouse
143(2)
4.5 Substation automation: Technical issues
145(3)
4.5.1 System responsibilities
146(1)
4.5.2 System architecture
146(1)
4.5.3 Substation host processor
147(1)
4.5.4 Substation LAN
147(1)
4.5.5 User interface
147(1)
4.5.6 Communications interfaces
147(1)
4.5.7 Protocol considerations
148(1)
4.6 The new digital substation
148(2)
4.6.1 Process level
148(2)
4.6.2 Protection and control level
150(1)
4.6.3 Station bus and station level
150(1)
4.7 Substation automation architectures
150(4)
4.7.1 Legacy substation automation system
151(1)
4.7.2 Digital substation automation design
151(1)
4.7.2.1 Station bus architecture
152(2)
4.7.2.2 Station bus and process bus architecture
154(1)
4.8 New versus existing substations
154(4)
4.8.1 Drivers of transition
155(1)
4.8.2 Migration paths and the steps involved
156(1)
4.8.3 Value of standards in substation automation
157(1)
4.9 Substation automation (SA) application functions
158(6)
4.9.1 Integrated protection functions: Traditional approach and IED-based approach
159(1)
4.9.2 Automation functions
159(1)
4.9.2.1 Intelligent bus failover and automatic load restoration
160(1)
4.9.2.2 Supply line sectionalizing
161(1)
4.9.2.3 Adaptive relaying
161(1)
4.9.2.4 Equipment condition monitoring (ECM)
162(1)
4.9.3 Enterprise-level application functions
162(1)
4.9.3.1 Disturbance analysis
163(1)
4.9.3.2 Intelligent alarm processing
163(1)
4.9.3.3 Power quality monitoring
163(1)
4.9.3.4 Real-time equipment monitoring
163(1)
4.10 Data analysis: Benefits of data warehousing
164(5)
4.10.1 Benefits of data analysis to utilities
165(1)
4.10.2 Problems in data analysis
166(1)
4.10.3 Ways to handle data
167(1)
4.10.4 Knowledge extraction techniques
167(2)
4.11 SA practical implementation: Substation automation laboratory
169(4)
4.11.1 Hardware design of the SA laboratory
170(1)
4.11.2 Software components of the SA laboratory
170(3)
4.11.3 Mitigation from old technology to the new technology
173(1)
4.12 Case studies in substation automation
173(1)
4.13 Summary
174(3)
Bibliography
175(2)
Chapter 5 Energy management systems (EMS) for control centers
177(38)
5.1 Introduction
177(1)
5.2 Operating states of the power system and sources of grid vulnerability
177(2)
5.3 Energy control centers
179(4)
5.3.1 Energy management systems (EMS): Why and what and challenges
180(1)
5.3.2 Energy management systems evolution
181(2)
5.4 EMS framework
183(3)
5.4.1 EMS time frames
185(1)
5.4.2 EMS software applications and data flow
185(1)
5.5 Data acquisition and communication (SCADA systems)
186(2)
5.6 Generation operation and management
188(6)
5.6.1 Load forecasting
188(1)
5.6.2 Unit commitment
189(2)
5.6.3 Hydrothermal coordination
191(1)
5.6.4 Real-time economic dispatch and reserve monitoring
192(1)
5.6.5 Real-time automatic generation control
193(1)
5.7 Transmission operations and management: Real time
194(6)
5.7.1 Network configuration and topology processors
194(1)
5.7.2 State estimation
195(3)
5.7.3 Contingency analysis
198(1)
5.7.4 Security constrained optimal power flow
199(1)
5.7.5 Islanding of power systems
200(1)
5.8 Study-mode simulations
200(1)
5.8.1 Network modeling
200(1)
5.8.2 Power flow analysis
201(1)
5.8.3 Short-circuit analysis
201(1)
5.9 Post-event analysis and energy scheduling and accounting
201(2)
5.9.1 Energy scheduling and accounting
201(1)
5.9.2 Event analysis
202(1)
5.9.3 Energy service providers
202(1)
5.10 Dispatcher training simulator
203(1)
5.11 Smart transmission
204(6)
5.11.1 Phasor measurement unit
204(2)
5.11.2 Phasor quantity and time synchronization
206(1)
5.11.3 PMU-PDC system architecture
207(1)
5.11.4 Applications of PMU
208(1)
5.11.5 WAMS (wide-area monitoring system)
209(1)
5.12 EMS with WAMS
210(2)
5.13 Future trends in EMS and DMS with WAMS
212(1)
5.14 Case studies in EMS and WAMS
213(1)
5.15 Summary
213(2)
Bibliography
213(2)
Chapter 6 Distribution automation and distribution management (DA/DMS) systems
215(36)
6.1 Overview of distribution systems
215(1)
6.2 Introduction to distribution automation
215(5)
6.2.1 Customer automation
217(1)
6.2.2 Feeder automation
218(1)
6.2.3 Substation automation
219(1)
6.3 Subsystems in a distribution control center
220(7)
6.3.1 Distribution management systems (DMSs)
220(1)
6.3.2 Outage management systems (OMS)
220(1)
6.3.2.1 Unplanned outages
220(1)
6.3.2.2 Planned outage
221(1)
6.3.3 CIS (customer information system)
222(1)
6.3.4 GIS (geographical information system)
223(1)
6.3.5 AMS (asset management system)
224(2)
6.3.6 AMI (advanced metering infrastructure)
226(1)
6.4 DMS framework: Integration with subsystems
227(2)
6.4.1 Common information model (CIM)
229(1)
6.5 DMS application functions
229(1)
6.6 Advanced real-time DMS applications
229(9)
6.6.1 Topology processing (TP)
229(1)
6.6.2 Integrated volt-var control (IVVC)
230(1)
6.6.3 Fault detection, isolation, and service restoration (FDIR)
231(4)
6.6.3.1 FDIR control strategies
235(1)
6.6.3.2 Reliability indices
235(1)
6.6.4 Distribution load flow
236(1)
6.6.5 Distribution state estimation (SE) and load estimation
236(2)
6.7 Advanced analytical DMS applications
238(2)
6.7.1 Optimal feeder reconfiguration
238(1)
6.7.2 Optimal capacitor placement
238(1)
6.7.3 Other applications
239(1)
6.8 DMS coordination with other systems
240(1)
6.8.1 Integration with outage management systems (OMS)
240(1)
6.8.2 Integration with AMI
240(1)
6.8.2.1 Consumer energy consumption data
240(1)
6.8.2.2 Reactive energy consumption
241(1)
6.8.2.3 Voltage profile data and energization status data
241(1)
6.9 Customer automation functions
241(1)
6.10 Social media usage for improved reliability and customer satisfaction
242(5)
6.10.1 Replacing truck rolls
243(1)
6.10.2 Tying it all together
244(1)
6.10.3 Routing signals
245(1)
6.10.4 DMS in outage management
246(1)
6.11 Future trends in DA and DMS
247(1)
6.12 Case studies in DA and DMS
247(1)
6.13 Summary
247(4)
Bibliography
248(3)
Chapter 7 Smart grid concepts
251(48)
7.1 Introduction
251(1)
7.2 Smart grid definition and development
252(1)
7.3 Old grid versus new grid
252(1)
7.4 Stakeholders in smart grid development
253(3)
7.5 Smart grid solutions
256(5)
7.5.1 Asset optimization
257(1)
7.5.2 Demand optimization
257(1)
7.5.3 Distribution optimization
258(1)
7.5.4 Smart meter and communications
259(1)
7.5.5 Transmission optimization
260(1)
7.5.6 Workforce and engineering optimization
261(1)
7.5.7 Smart grid road map
261(1)
7.6 Smart distribution
261(29)
7.6.1 Demand-side management and demand response
262(2)
7.6.1.1 Energy efficiency (EE)
264(1)
7.6.1.2 Time of use (TOU)
264(1)
7.6.1.3 Demand response (DR)
264(1)
7.6.1.4 Peak load on the system: Case study
265(1)
7.6.2 Distributed energy resource and energy storage
266(1)
7.6.2.1 Distributed generation (DG)
267(1)
7.6.2.2 Energy storage
267(3)
7.6.3 Advanced metering infrastructure (AMI)
270(1)
7.6.3.1 Components of AMI
271(2)
7.6.3.2 AMI integration with DA, DMS, and OMS
273(2)
7.6.3.3 The market and the business case
275(4)
7.6.4 Smart homes with home energy management systems (HEMs)
279(2)
7.6.5 Plugged hybrid electric vehicles
281(1)
7.6.5.1 PHEV characteristics
282(1)
7.6.5.2 PHEV impact on the grid
283(1)
7.6.6 Microgrids
284(2)
7.6.6.1 Types of microgrids
286(1)
7.6.6.2 Microgrid control
286(2)
7.6.6.3 DC microgrid
288(2)
7.7 Smart transmission
290(1)
7.8 Lessons learned in deployment of smart grid technologies
290(3)
7.8.1 Lessons on technology
290(1)
7.8.2 Lessons on implementation and deployment
291(1)
7.8.3 Lessons on project management: Building a collaborative management team
292(1)
7.8.4 Share lessons learned
293(1)
7.8.5 The lessons continue
293(1)
7.9 Case studies in smart grid
293(2)
7.9.1 PG&E improves information visibility
294(1)
7.9.2 Present and future integration of diagnostic equipment monitoring
294(1)
7.9.3 Accelerated deployment of smart grid technologies in India: Present scenario, challenges, and way forward
294(1)
7.10 Summary
295(4)
Bibliography
295(4)
Glossary 299(6)
Index 305
Mini S. Thomas is a professor in the Department of Electrical Engineering at Jamia Millia Islamia, New Delhi, India (JMI), with 29 years of teaching and research experience in the field of power systems. She was the head of the Department of Electrical Engineering and currently is the director of the Center for Innovation and Entrepreneurship. She graduated from the University of Kerala, India and obtained her M.Tech from the Indian Institute of Technology Madras, both with Gold Medals. She also holds a Ph.D from the Indian Institute of Technology Delhi, New Delhi. Dr. Thomas conceived, designed, and implemented the first-of-their-kind supervisory control and data acquisition (SCADA) and substation automation (SA) laboratories and has done extensive research work in SCADA systems, substation and distribution automation, and smart grids. She has published more than 100 research papers in international journals and conferences of repute, and is the coordinator of the special assistance program (SAP) on power system automation from the University Grants Commission, Government of India.

John D. McDonald, P.E., is director of Technical Strategy and Policy Development for GE Energy Management - Digital Energy, Atlanta, Georgia, USA, with 40 years of experience in the electric utility industry. He joined GE Energys Transmission and Distribution (now Digital Energy) business in 2008 as general manager of marketing, and accepted his current role in 2010. McDonald is a sought-after industry leader, technical expert, educator, and speaker. In his 28 years of working group and subcommittee leadership with the IEEE Power and Energy Society (PES) Substations Committee, he led seven working groups and task forces that published standards and tutorials in the areas of SCADA and master/remote terminal unit (RTU) and RTU/IED communications protocols. He is a fellow of IEEE and past president of the IEEE PES. He teaches smart grid courses for GE and the Georgia Institute of Technology, Atlanta, USA, and substation automation, SCADA, and communications courses for various IEEE PES local chapters. He has published 80 papers and articles, co-authored four books, and holds a BSEE and MSEE from Purdue University, West Lafayette, Indiana, USA, and an MBA from the University of California-Berkeley, USA. He received the 2009 Outstanding Electrical and Computer Engineer Award from Purdue University.
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