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E-raamat: Power System Economic and Market Operations [Taylor & Francis e-raamat]

(The University of Hong Kong, PR of China)
  • Formaat: 256 pages, 26 Tables, black and white; 48 Line drawings, black and white
  • Ilmumisaeg: 16-Jan-2018
  • Kirjastus: CRC Press Inc
  • ISBN-13: 9781351180078
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  • Taylor & Francis e-raamat
  • Hind: 230,81 €*
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  • Tavahind: 329,73 €
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Power System Economic and Market OperationsSuurem pilt
  • Formaat: 256 pages, 26 Tables, black and white; 48 Line drawings, black and white
  • Ilmumisaeg: 16-Jan-2018
  • Kirjastus: CRC Press Inc
  • ISBN-13: 9781351180078
Teised raamatud teemal:
Taylor & Francis e-raamatudRohkem infot Taylor & Francis e-raamatute kohta
Raamatu kodulehekülg: https://www.taylorfrancis.com/books/9781351180078
Power system operation is one of the important issues in the power industry. The book aims to provide readers with the methods and algorithms to save the total cost in electricity generation and transmission. It begins with traditional power systems and builds into the fundamentals of power system operation, economic dispatch (ED), optimal power flow (OPF), and unit commitment (UC). The book covers electricity pricing mechanisms, such as nodal pricing and zonal pricing, based on Security-Constrained ED (SCED) or SCUC. The operation of energy market and ancillary service market are also explored.

"It covers a wide range of interesting topics, which could be very useful for understanding the main phenomena ruling power systems economy (such as Optimal Power Flow analysis and unit Commitments). It addresses topics widely treated in the literature, hence it is important to outline its distinctive features compared to other similar books. The book is well structured and well balanced." Alfredo Vaccaro, University of Sannio, Italy
Preface xv
Acknowledgments xvii
1 Introduction 1(4)
2 Economic operation in power systems 5(8)
2.1 Introduction of power system operation
5(3)
2.2 Development of economic operation
8(4)
2.3 Incentives of economic operation
12(1)
Bibliography
12(1)
3 Power generation costs 13(24)
3.1 Load cycles
13(3)
3.2 Costs for power generations
16(10)
3.2.1 Coal-fired steam power plants
16(6)
3.2.2 Gas-fired power plants
22(2)
3.2.3 Hydro power stations
24(1)
3.2.4 Nuclear power stations
25(1)
3.2.5 Wind power and solar energy
25(1)
3.3 Generation planning
26(9)
3.3.1 Conventional generation planning
26(2)
3.3.2 Screening curve
28(3)
3.3.3 Load duration curve
31(4)
3.3.4 Generation planning and generation scheduling
35(1)
3.4 Summary
35(2)
4 Economic dispatch 37(20)
4.1 Introduction
37(1)
4.2 The problem of economic dispatch
38(11)
4.3 Economic dispatch problem considering losses
49(3)
4.4 Economic dispatch with piecewise linear cost functions
52(3)
4.5 Summary
55(2)
5 Optimal power flow 57(26)
5.1 Introduction
57(2)
5.2 Power flow formulations
59(4)
5.2.1 Bus admittance matrix
59(1)
5.2.2 Power flow equations
60(3)
5.3 Optimal power flow modeling
63(4)
5.3.1 Mathematical model of optimal power flow
63(2)
5.3.2 Solution algorithms for optimal power flow
65(2)
5.4 DC optimal power flow
67(1)
5.5 Security-constrained optimal power flow
68(4)
5.6 Examples
72(5)
5.6.1 Test system
72(1)
5.6.2 Example for AC optimal power flow
73(1)
5.6.3 Example for DC optimal power flow
74(1)
5.6.4 Example for security-constrained optimal power flow
75(2)
5.7 Modified optimal power flow models for power system operations
77(4)
5.7.1 Minimize generation cost
78(1)
5.7.2 Minimize losses/total generation
78(1)
5.7.3 Minimize generation adjustment
78(1)
5.7.4 Minimize load shedding
79(1)
5.7.5 Optimization of reactive power
79(2)
5.8 Optimal power flow and unit commitment
81(1)
Bibliography
81(2)
6 Unit commitment 83(18)
6.1 Introduction
83(1)
6.2 Illustrative example of unit commitment
84(7)
6.3 Mathematical model of unit commitment problem
91(8)
6.3.1 Variables of unit commitment problem
92(1)
6.3.1.1 Control variables
92(1)
6.3.1.2 State variables
92(1)
6.3.2 Objective function
92(1)
6.3.3 Unit constraints
93(3)
6.3.3.1 Generator output limits
93(1)
6.3.3.2 Generation unit ramping constraints
94(1)
6.3.3.3 Generation unit operation time constraints
95(1)
6.3.3.4 Other unit constraints
95(1)
6.3.4 System constraints
96(7)
6.3.4.1 Power balance constraints
96(1)
6.3.4.2 Network constraints
97(1)
6.3.4.3 System reserve constraints
98(1)
6.4 Solution algorithms for unit commitment problem
99(1)
6.5 Summary
100(1)
7 Electricity market overview 101(26)
7.1 Traditional power industry
101(2)
7.2 Deregulation of power industry
103(4)
7.2.1 Unbundling of integrated power systems
103(3)
7.2.2 Restructured power system for market operation
106(1)
7.3 Power deregulation in different countries
107(7)
7.3.1 Great Britain
108(1)
7.3.2 Australia and New Zealand
109(1)
7.3.3 Nordic countries
110(1)
7.3.4 United States
111(2)
7.3.5 Europe
113(1)
7.3.6 China
113(1)
7.4 Electricity retail markets
114(2)
7.5 Overview of electricity market operation
116(9)
7.5.1 Markets
116(2)
7.5.1.1 Energy market
116(1)
7.5.1.2 Ancillary service market
117(1)
7.5.1.3 Electricity financial market
117(1)
7.5.2 Market participants
118(1)
7.5.3 Market operations and its timeline
119(2)
7.5.4 Spot market pricing mechanisms
121(2)
7.5.5 Congestion management
123(1)
7.5.6 Transmission services
124(1)
7.6 Summary
125(1)
Bibliography
125(2)
8 Electricity market pricing models 127(58)
8.1 Introduction
127(1)
8.2 Nodal price-based market model
128(8)
8.2.1 Marginal price introduction
128(1)
8.2.2 Optimal power flow-based market model
129(3)
8.2.2.1 Objective functions
129(2)
8.2.2.2 Constraints
131(1)
8.2.3 Security-constrained optimal power flow-based market model
132(3)
8.2.3.1 Objective functions
133(1)
8.2.3.2 Constraints
133(2)
8.2.4 Bilateral contract formulation in the market model
135(1)
8.3 Locational marginal price
136(13)
8.3.1 Formulation of locational marginal price
137(10)
8.3.2 Derivation of locational marginal price for a security-constrained market model
147(2)
8.4 Examples for locational marginal price calculation and market clearing
149(18)
8.4.1 An example of locational marginal price calculation without loss or congestion
149(1)
8.4.1.1 Example A
149(1)
8.4.2 Examples of locational marginal price calculation with network effects
150(9)
8.4.2.1 Examples: Without loss or congestion
150(5)
8.4.2.2 Examples: With congestions
155(4)
8.4.3 Locational marginal price calculation for a system
159(8)
8.4.3.1 Example D1
161(1)
8.4.3.2 Example D2
161(1)
8.4.3.3 Example D3
162(2)
8.4.3.4 Example D4
164(3)
8.5 Market settlement
167(8)
8.5.1 Bilateral contracts in a spot market
167(1)
8.5.2 Bilateral contract settlement
168(1)
8.5.3 Examples for bilateral contract settlement
169(5)
8.5.3.1 Example I: Double payment of bilateral contract
169(2)
8.5.3.2 Example II: Internal settlement for double payment offsetting
171(2)
8.5.3.3 Example III: External settlement for double payment offsetting
173(1)
8.5.4 Contract that is not resource specific
174(1)
8.6 Uniform zonal price-based market model
175(8)
8.6.1 Uniform market price
176(2)
8.6.2 Zonal uniform market price
178(3)
8.6.2.1 Potential price zones
178(1)
8.6.2.2 Zonal price clearing
179(2)
8.6.3 Zonal price market operation issues
181(2)
8.7 Nodal pricing versus zonal pricing
183(1)
8.8 Summary
184(1)
9 Congestion management and transmission tariff 185(10)
9.1 Introduction
185(1)
9.2 Congestion management
186(1)
9.2.1 Transmission congestion
186(1)
9.2.2 Congestion management and congestion charge
186(1)
9.3 Transmission right
187(2)
9.4 Transmission tariff
189(2)
9.5 Congestion revenue
191(2)
9.6 Summary
193(2)
10 Ancillary service markets 195(18)
10.1 Introduction
195(2)
10.2 Classifications of ancillary services
197(2)
10.3 Frequency regulation services
199(6)
10.3.1 Electricity balancing market
200(2)
10.3.2 Regulation service market
202(1)
10.3.3 Performance-based regulation service market
203(2)
10.4 Reserve service market
205(1)
10.5 Reactive power as an ancillary service
206(6)
10.5.1 Costs for providing reactive power
207(2)
10.5.2 Reactive power market model
209(3)
10.6 Summary
212(1)
Bibliography
212(1)
11 Electricity financial market and its risk management 213(6)
11.1 Risks in the electricity market
213(1)
11.2 Risk management in the electricity market
214(2)
11.3 Electricity derivatives
216(1)
11.4 Summary
217(2)
12 Low carbon power system operation 219(14)
12.1 Introduction
219(1)
12.2 Emission dispatch model
220(3)
12.3 Emission reduction policies for power sectors
223(4)
12.3.1 Introduction of policies applied in power generations
223(1)
12.3.2 Clean Air Act of the United States
223(2)
12.3.3 European Emission Trading Scheme
225(1)
12.3.4 Renewable energy certificate scheme
226(1)
12.3.5 Feed-in tariff
226(1)
12.4 Impacts of CO2 prices on power system dispatch
227(1)
12.5 Impacts of emission trading on generation scheduling and electricity prices
228(1)
12.6 Discussions on low carbon market mechanisms
229(3)
12.7 Summary
232(1)
Index 233
Dr. Jin Zhong received her B.Sc. degree from Tsinghua University, Beijing, China, and her Ph.D. degree from Chalmers University of Technology, Gothenburg, Sweden. At present, she is with the Department of Electrical and Electronic Engineering at the University of Hong Kong. Her areas of interest are power system operation, electricity market, ancillary services, power system optimization, smart grid, and renewable energy integration.
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