Electric system operations : evolving to the modern grid

Electric System Operations Evolving to the Modern Grid, Second Edition
	Foreword
	Preface
	Acknowledgments
	CHAPTER 1 Introduction
		1.1 Introduction to Utilities
		1.2 Electric Utility Explained
			1.2.1 Generation
			1.2.2 Transmission
			1.2.3 Subtransmission
			1.2.4 Distribution
			1.2.5 Customer
		1.3 Electric Utilities: A U.S. Historical Perspective
			1.3.1 First Came PUHCA
			1.3.2 Along Came Deregulation
			1.3.3 Then Came Smart Grid
			1.3.4 A Global Outlook
		1.4 Utilities and Regulation
		1.5 Utility Types and Other Nontraditional Utility-Like Entities
			1.5.1 IOUs
			1.5.2 Publicly Owned Utilities
			1.5.3 Cooperatives
			1.5.4 RTOs and ISOs
			1.5.5 Federal Utilities
			1.5.6 Community Choice Aggregate
			1.5.7 Aggregators
			1.5.8 Independent Power Producers
		Endnotes
	CHAPTER 2
Define System Operations
		2.1 System Operations
		2.2 Key Drivers for Systems Operations
			2.2.1 Impact of Drivers on Distribution
			2.2.2 Impact of Drivers on Transmission
		2.3 What Changes from Transmission to Distribution System Operations?
			2.3.1 New Technologies and Integration Points
			2.3.2 Network Configuration
			2.3.3 Accuracy of the Power System Model
			2.3.4 Component Location
			2.3.5 Three-Phase versus Single-Phase
			2.3.6 Level of Observability
		2.4 Distribution System Operations: An Introduction
		2.5 Key Challenges Facing System Operations
		Endnotes
	CHAPTER 3
Introduction to Power Systems
		3.1 Basic Electric Components
			3.1.1 Capacitors and Reactors
			3.1.2 Transformers
			3.1.3 Switches
			3.1.4 Relays and Protection Equipment
			3.1.5 Kilovolt Classes or Common Voltage Levels
			3.1.6 Busbars
			3.1.7 Substations
			3.1.8 Smart Inverters
			3.1.9 Microgrid
		3.2 Key Power System Physical Concepts Explained
			3.2.1 The Basics: Voltage and Current
			3.2.2 Ohm’s Law
			3.2.3 Kirchhoff’s Laws
			3.2.4 DC versus AC
			3.2.5 Complex Power Representation
			3.2.6 Power Factor
			3.2.7 Three-Phase versus Single Phase
			3.2.8 Six-Phase Transmission System
			3.2.9 Phasors
			3.2.10 Superconductivity in Transmission Lines and Transformers
			3.2.11 Bold® Transmission Line
		3.3 Key Business Concepts Explained
			3.3.1 Utility Interconnected System
			3.3.2 Control Area or Balancing Authority Areas
			3.3.3 Renewable Energy Zones
		Endnotes
	CHAPTER 4
Impact of Deregulation on System Operations
		4.1 Wholesale Markets
			4.1.1 The New Participants and Their Activities
			4.1.2 Summary Description of the Participants and How They Interact
			4.1.3 Architectural Discussion
		4.2 Retail Markets
			4.2.1 ERCOT
			4.2.2 NY REV and the Emergence of the DSO
		4.3 Key Retail Market Constructs
			4.3.1 Transactive Energy
			4.3.2 Customer Choice Aggregate
			4.3.3 Energy Imbalance Market
			4.3.4 Renewable Energy Buyers Alliance
			4.3.5 Summarizing Retail Markets and Their Impacts to System Operations
		4.4 Case Studies
			4.4.1 Case Study 1: Energy  Imbalance Market—PacifiCorp
			4.4.2 Case Study 2: Simple Energy VPP
		4.5 History of Deregulation
		4.6 Summary
		Endnotes
	CHAPTER 5
Impact of Grid Modernization on System Operations
		5.1 Setting the Context
		5.2 Conceptual View of a Modern Grid
		5.3 Defining Key Terms
		5.4 Smart Grid Changes Impacting System Operations
		5.5 Community Changes Impacting System Operations
			5.5.1 DERs
			5.5.2 Electric Transportation
			5.5.3 Microgrids
			5.5.4 Smart Appliances and the Advent of the Smart Home
		5.6 What Does All This Mean for the System Operator?
		5.7 Impact of Smart Grid on New Systems
			5.7.1 MDMS
			5.7.2 OMS
			5.7.3 GIS
			5.7.4 ADMS
			5.7.5 Distributed Energy Resources Management System
		5.8 Cybersecurity
		5.9 Case Studies
			5.9.1 Case Study #1: Smart Grid Technology Increasing Reliability for PPL Customers
			5.9.2 Case Study #2: How Smart Sensors Improved Reliability at FPL
		Endnotes
	CHAPTER 6
Business of System Operations
		6.1 Anatomy of a Regulated Utility
			6.1.1 Generation Business
			6.1.2 Transmission and Distribution
			6.1.3 Customer
			6.1.4 Storage and other NWA between Generation and T&D
		6.2 T&D Operating Model
			6.2.1 Asset Management and System Planning
			6.2.2 Asset Owner
			6.2.3 Work and Resource Management
			6.2.4 Field Execution
		6.3 Other Utility-Like Entities
			6.3.1 RTO/ISO
			6.3.2 CCA
			6.3.3 Aggregators or REPs
		6.4 The Regulatory Regime
			6.4.1 State Level: PUC
			6.4.2 Federal Level: FERC
			6.4.3 Regulation for Municipalities and Cooperatives
		6.5 Architecting the Business of System Operations
			6.5.1 Drivers
			6.5.2 Strategy
			6.5.3 People
			6.5.4 Process
			6.5.5 Technology
		6.6 System Operations Processes
			6.6.1 Monitor and Execute Real-Time Operations
			6.6.2 Manage Planned Events
			6.6.3 Manage Unplanned Events
			6.6.4 Coordinate Emergency Response
			6.6.5 Plan Daily Operations
			6.6.6 Perform System Analysis
			6.6.7 Report Operational Performance
		6.7 Changes to the Business of System Operations
			6.7.1 DER
			6.7.2 NWA
			6.7.3 Electric Transportation
		6.8 Case Studies
			6.8.1 Case Study 1: California’s Move Toward Distributed Generation
			6.8.2 Case Study 2: Navigating the California Duck Curve
		Endnotes
	CHAPTER 7
Control Center: The Hub of System Operations
		7.1 Organization of Work
		7.2 Transmission Control Center
			7.2.1 Transmission Desk
			7.2.2 Generation Desk
			7.2.3 Energy and Transmission Scheduling Desk
			7.2.4 Other Support Desks
		7.3 Distribution Control Center
			7.3.1 Clearance Desk
			7.3.2 Switching Desk
			7.3.3 Other Support Desks
		7.4 Other Key Aspects of a Control Center
		7.5 Introducing a High-Performing System Operator
		7.6 Case Studies
			7.6.1 Case Study 1: Impact of Automation on the Control Center of the Future
			7.6.2 Case Study 2: Control Centers Backing Each Other Up
		Endnotes
	CHAPTER 8
Energy Management Systems
		8.1 How an EMS Supports the System Operator’s Mandate
			8.1.1 Transmission Operator
			8.1.2 Generation Operator
			8.1.3 RTO/ISO
			8.1.4 RTO/Wholesale Market Participant
		8.2 Key Components of an EMS
			8.2.1 EMS Hardware
			8.2.2 EMS Software
			8.2.3 EMS Databases
			8.2.4 EMS UI
		8.3 EMS Application Suites
			8.3.1 SCADA
			8.3.2 Network Apps
			8.3.3 Generation Apps
			8.3.4 Dispatching Training Simulator
			8.3.5 WAMS
			8.3.6 Modeling Apps
		8.4 Case Studies
			8.4.1 Case Study 1: Use of WAMS Implementations to Analyze the Northeast Blackout of 2003
			8.4.2 Case Study 2: Implementation of a Hierarchical EMS
		Endnotes
	CHAPTER 9
Outage Management System
		9.1 Types of Outages
			9.1.1 Transmission Outages
			9.1.2 Distribution Outages
		9.2 Origins of the OMS
			9.2.1 The Paper Age
			9.2.2 The Move to an OMS
		9.3 The Architecture of an OMS
			9.3.1 Outage Engine
			9.3.2 Key Interfaces
			9.3.3 Customer Portal
			9.3.4 Report
			9.3.5 Operator User Interface
		9.4 Impact of Smart Meter on the OMS
			9.4.1 Key Smart Meter Outage Support Characteristics
			9.4.2 Smart Meter Preprocessing
		9.5 Outage Customer Experience
			9.5.1 Estimated Time of Restoration and What It Means
			9.5.2 Forecasting Outages and Damage Prediction
			9.5.3 Damage Assessment
			9.5.4 Control Center as the Information Hub for Outages and Damage
		9.6 The Business of Managing Outages
		9.7 The Future of OMS?
		Endnotes
	CHAPTER 10
Advanced Distribution Management System
		10.1  Introduction to the ADMS
		10.2  The Utility Context: Why Is an ADMS Needed?
			10.2.1 Greater Standards for Customer Satisfaction
			10.2.2 Decision Tools
			10.2.3 Reduced Outage, Whether Planned or Unplanned, Duration
			10.2.4 Ability to Process Real-Time Data Quickly
			10.2.5 Disaster Recovery
			10.2.6 Increased Manageability of the Distribution Infrastructure
			10.2.7 ADMS Is a Tool for Optimizing Employee and System Performance
		10.3 ADMS: An Architectural Description
		10.4 How the ADMS Supports the System Operator’s Mandate
		10.5 How the ADMS Supports the Smart (Modern) Grid
		10.6 Key Component of an ADMS
			10.6.1 ADMS Hardware
			10.6.2 ADMS Databases
			10.6.3 ADMS UI
			10.6.4 ADMS Software
		10.7 ADMS Application Components
			10.7.1 Core Applications
			10.7.2 Advanced Applications
			10.7.3 Distribution Automation Applications
			10.7.4 Integrating Applications
		10.8  ADMS Models and Its Interface with GIS
			10.8.1 Complete and Accurate Data
			10.8.2 Strong Supporting Functions
			10.8.3 Robust Integration
		10.9 What Changes at a Utility When an ADMS Is Implemented?
		10.10 Case Studies
			10.10.1 Case Study 1: Small Utility ADMS Implementation—Bluebonnet Electric Cooperative
			10.10.2 Case Study 2: Large Utility ADMS Implementation—Pennsylvania Power and Light
		10.11 The Future of ADMS
		Endnotes
	CHAPTER 11
Distributed Energy Resource Management System
		11.1 DERs and Establishing the Need for a DERMS System
		11.2 What Is Complicating This Situation?
			11.2.1 Data Deluge or Tsunami
			11.2.2 Multiple Noncoordinated Demand Response Programs
			11.2.3 Management Reporting
			11.2.4 Continued Customer Apathy
		11.3 DERMS Architecture
			11.3.1 Core Components of a DERMS
			11.3.2 What Makes DERMS a Necessary System?
		11.4 Who Would Use This System?
		11.5 Service Models That Need to Be Considered
		11.6 Challenges
		11.7 Case Studies
			11.7.1 Case Study 1: Duke Energy’s Integrated ADMS and DERMS for Grid Modernization
			11.7.2 Sample Use Case: Modeling and Visualization of Energy Storage and EV Scheduling
			11.7.3 Sample Use Case: Solar Forecasting Visualization
			11.7.4 Summary
		11.8 Does DERMS Have a Future?
		Endnotes
	CHAPTER 12
System Operator Training Simulators
		12.1 Drivers Behind the Need for a Training Simulator
		12.2 Establishing the Need for Operator/Dispatcher Training
			12.2.1 New Controls
			12.2.2 Economics and Markets
			12.2.3 Retail Choice: New Competitors
			12.2.4 NWAs
			12.2.5 Distributed Generation
			12.2.6 Renewable (and Distributed) Power Generation
			12.2.7 Distribution Ancillary services
			12.2.8 Customer Expectations Are Changing
			12.2.9 Self-Healing Grid
			12.2.10 Existing Electromechanical Devices Being Replaced by Electronic Devices
			12.2.11 Security and Stability of the Changing System
			12.2.12 Regulatory Changes
			12.2.13 Safety Concerns
			12.2.14 Summary
		12.3 Identifying the Target Audience
		12.4 Introducing the Dispatcher Training Simulator
		12.5 Key Characteristics of a Good System Operator Training  Simulator
		12.6 Architecture of a System Operator Simulator
		12.7 Setting Up a Training Environment
			12.7.1 Hardware/Software Environment
			12.7.2 Training Environment
			12.7.3 Database Models
		12.8 How to Set up a Training Program
		12.9 Key Steps in Setting Up a System Operator Training Program
			12.9.1 People
			12.9.2 Process
			12.9.3 Technology
		12.10 Training Simulators as a Real-Time Simulation Platform
		12.11 Case Studies
			12.11.1 Case Study 1: Use of Dispatching Training Simulator as a Training Tool
			12.11.2 Case Study 2: Use of Dispatcher Training Simulator as a Tool to Support Complex Switching
		12.12 Training Simulators in the Future
		Endnotes
	CHAPTER 13
Conclusions and What Is Coming Next
		13.1  Key Takeaways for the System Operator of the Future
		13.2 Key Takeaways from the Systems Described in This Book
		13.3  Final Conclusions
		Endnotes
	Acronyms and Abbreviations
	About the Author
	Index