constrained economic dispatchfor hvdc using particle swarm...
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UNIVERSITY OF NAIROBI
FACULTY OF ENGINEEING
DEPARTMENT OF ELECTRICAL AND INFORMATION ENGINEERING
SECURITY CONSTRAINED ECONOMIC DISPATCH FOR HVDC USING
PARTICLE SWARM OPTIMIZATION
PROJECT INDEX: 058
SUBMITTED BY CYPRIAN OCHIENG’, F17/1430/2011
SUPERVISOR: PROF. N.O. ABUNGU
EXAMINER:
PROJECT REPORT SUBMITTED IN PARTIAL FULFILLMENT
OF THE REQUIREMENT FOR THE AWARD OFTHE DEGREEOF
BACHELOR OF SCIENCE IN ELECTRICAL AND ELECTRONICENGINEERING
OF THE UNIVERSITY OF NAIROBI 2016
SUBMITTED ON:
PAGE 1
DECLARATION OF ORIGINALITY
NAME OF STUDENT: Cyprian Ochieng’
REGISTRATION NUMBER: F17/1430/2011
COLLEGE: Architecture and Engineering
FACULTY/ SCHOOL/ INSTITUTE: Engineering
DEPARTMENT: Electrical and Information Engineering
COURSE NAME: Bachelor of Science in Electrical &
Electronic Engineering
TITLE OF WORK: Security Constrained Economic Dispatch for
HVDC Using Particle Swarm Optimization
(PSO)
I understand what plagiarism is and I am aware of the university policy in this regard.
I declare that this final year project report is my original work and has not been submitted
elsewhere for examination, award of a degree or publication. Where other people’s work
or my own work has been used, this has properly been acknowledged and
referenced in accordance with the University of Nairobi’s requirements.
I have not sought or used the services of any professional agencies to produce this work.
I have not allowed, and shall not allow anyone to copy my work with the intention of
passing it off as his/her own work.
I understand that any false claim in respect of this work shall result in disciplinary action,
in accordance with University anti-plagiarism policy.
Signature: …………………………………………………………………..
Date: ………………………………………………………………………..
PAGE 2
CERTIFICATION
This report has been submitted to the Department of Electrical and Information
Engineering University of Nairobi with my approval as supervisor:
Prof. Nicodemus Abungu Odero
Date: .....................................................................................................................
PAGE 3
DEDICATION
I dedicate this project to the Almighty God and to my family, lecturers and fellow
students for their support and encouragement.
PAGE 4
ACKNOWLEDGEMENTS
I would like to thank God for this life and for His Presence and Guidance throughout my
life and studies.
I would also like to thank my supervisor, Prof. Nicodemus Abungu for his insight,
motivation, support and guidance.
I extend my appreciation to Mr. Musau for his valuable insights into my project, criticism
and encouragement.
I appreciate all my lectures and all staff at the Department of Electrical and Electronic
Engineering, and the entire community of the University of Nairobi for their contribution
towards my degree.
I am thankful to my classmates and friends for their support and availability throughout
my studies and most importantly during the period over which I was working on the
project.
In conclusion I would like to sincerely thank my family for their presence and undying
support throughout my studies.
PAGE 5
PAGE 6
Contents
DECLARATION OF ORIGINALITY ........................................................................................................ 1
CERTIFICATION ........................................................................................................................................ 2
DEDICATION ............................................................................................................................................... 3
LIST OF TABLES ........................................................................................................................................ 9
LIST OF ABBREVIATIONS ..................................................................................................................... 10
1.1. Definition of terms .......................................................................................................................... 12
1.2. A brief introduction to HVDC system .......................................................................................... 14
1.2.1. Components of an HVDC transmission system ....................................................................... 15
1.2.2. HVDC systems control............................................................................................................... 16
1.2.3. HVDC configurations ................................................................................................................ 17
1.2.4. Reasons for HVDC ..................................................................................................................... 18
1.2.5. Comparison between DC and AC systems ............................................................................... 18
1.3. Problem statement ......................................................................................................................... 20
1.4. Objectives ....................................................................................................................................... 20
1.5. Research Questions ........................................................................................................................ 21
CHAPTER 2 ................................................................................................................................................ 22
2.1. Economic dispatch problem neglecting transmission losses ....................................................... 23
2.1.1. Fuel cost characteristics ............................................................................................................ 24
2.1.2. Problem formulation .............................................................................................................. 25
2.2. Economic dispatch problem considering network losses ...................................................... 27
2.2.1. Transmission line loss equation .............................................................................................29
2.2.2. Losses in HVDC systems ........................................................................................................30
2.2.3. HVDC inequality constraints ................................................................................................. 31
2.3. Review of solution methods .................................................................................................... 32
2.3.1. Particle swarm optimization ................................................................................................... 33
2.3.2. Genetic algorithm ................................................................................................................... 34
2.3.3. Evolutionary Programming .................................................................................................... 34
2.3.4. Linear Programming .............................................................................................................. 35
2.3.5. Lambda iteration .....................................................................................................................36
CHAPTER 3 ................................................................................................................................................ 37
SOLUTION OF SECURITY CONSTRAINED ECONOMIC DISPATCH USING PSO .................... 37
PAGE 7
3.1. PSO Algorithm ............................................................................................................................... 37
3.2. Parameter representation ............................................................................................................. 42
3.3. PSO Algorithm for SCED.........................................................................................................42
CHAPTER 4 ........................................................................................ Error! Bookmark not defined.45
RESULTS AND ANALYSIS………………………………………………………………………………………………………………45
4.1. Case Study: IEEE 30-bus System………………………………………………………………………………….45
4.2. Results………………………………………………………………………………………………………………………….46
4.3. Analysis and Discussion………………………………………………………………………………………………….49
CHAPTER 5 ................................................................................................................................................ 51
CONCLUSION AND RECOMMENDATION………………………………………………………………………………..51
5.1 Conclusion……………………………………………………………………………………………………………………….51
5.2 Recommendations…………………………………………………………………………………………………………..51
REFERENCES…………………………………………………………………………………………………………………………………..52
APPENDIX…………………………………………………………………………………………………………………………………….53
PAGE 8
LIST OF FIGURES
Fig 1.1: Total cost/distance…………………………………………………….............................……..18
Fig 1.2: Typical transmission line structures for approximately 1000MW…………………....…….19
Fig 2.1: N-thermal units connected to a bus to serve a load.........................................................….....23
Fig2.2: A typical fuel cost characteristics…………..………………………………………………….24
Fig 2.3: N thermal units serving LoadP through a transmission network with losses.…....................26
Fig 3.1: PSO Algorithm..................................…………………………………………….….………....36
Fig 4.1: One line diagram of IEEE 30-bus system [1]............................…............................................43
Fig 4.2: Variation of Real Power Losses with Power Demand for SCED and CED…………....…...47
Fig 4.3: Variation of Optimal Cost with Power Demand for SCED and CED…………...........….…48
PAGE 9
LIST OF TABLES
Table 4.1: Optimal generation for SCED and CED using PSO for a total demand of 283.4MW........44
Table 4.2: Optimal generation for SCED and CED using PSO for a total demand of 374.3MW........45
Table 4.3: Optimal generation for SCED and CED using PSO for a total demand of 540MW...........45
Table 4.4: Comparison of Economic Dispatch using PSO and GA for a total demand of 283.4MW..46
PAGE 10
LIST OF ABBREVIATIONS
CED Classical Economic Dispatch
ED Economic Dispatch
GA Genetic Algorithm
HVAC High Voltage Alternating Current
HVDC High Voltage Direct Current
IEEE Institute of Electrical and Electronic Engineering
LP Linear Programming
MATLAB Matrix Laboratory
MW Megawatts
OPF Optimal Power Flow
PSO Particle Swarm Optimization
QP Quadratic Programming
SCED Security Constrained Economic Dispatch
HPSO Hybrid Particle Swarm Optimization
PAGE 11
ABSTRACT
With increasing number of appliances, at house hold, office and institution level, as well
as facilities such as transport, communication among others, and machinery that require
electrical power, there is need for a reliable and efficient power supply that is at a
reasonable cost. With this in mind there is need for generation facilities, while harnessing
the abundant renewable energy sources provided by nature, to generate the energy that
requires fossil fuel at reduced cost to ensure affordability of the power on the side of the
consumer. This is to be done while ensuring that the whole system of generation and
supply if operating within their defined safe limits.
Considering this growing demand of power, there is need for interconnection of power
grids between nations within a region as well as integration of offshore generated energy
into the inland grid. With these long distances over which transmission is to be done to
achieve this, as well as to harmonize power systems operating at different frequencies,
HVDC technology is necessary.
Security Constrained Economic Dispatch is as an optimization procedure that attempts to
obtain an optimal balance of two conflicting objectives; cost efficiency that aims at
serving the demand with minimum cost, and security that requires electricity to be
delivered to customers without interruption even when a component of the system fails.
SCED problem has been solved with conventional methods as well as intelligent search
methods. In this project, Particle Swarm Optimization method is used to solve the
problem. The PSO algorithm has been implemented on the IEEE 30-bus network with a
load demand of 283.4MW. Six generating units are used to supply the power to meet this
demand.
PAGE 12
CHAPTER 1
INTRODUCTION
1.1.Definition of terms
1.1.1. Economic Dispatch
Describes how the real power output of each controlled generating unit in an area is
selected to meet a given load and to minimize the total operating cost in the area. It is the
allocation of generation levels to generating units comprising a power system to
economically serve the load in entirety while remaining within the operational limits of
the generation facilities.
1.1.2. System Security
These are measures put in place to keep the system operating when components fail. A
measure of this security is the ability of the power system to withstand the effects of
contingencies such as generator, transformer or line outage, the effects of which are
monitored with specified security limits. An operationally secure system is one with low
possibility of system collapse or equipment damage.
The following are the three major functions carried out in the energy control center under
system security;
i. System monitoring; gives up-to-date information on the state of the power system
on real time basis with regard to the load and generation change.
ii. Contingency analysis; foresees possible system outages before they actually
occur. They alert the operators to any potential overloads or serious voltage
violation.
iii. Corrective action analysis; allows the operator to alter the operation of the power
system in such a direction as to avert the occurrence of a serious problem due to a
given outage.
1.1.3. Security Constrains
These are limits put in a power system to prevent outage of equipment due to
overstretching of the performance capabilities of the facilities and therefore ensure
continued supply of power to consumers with minimum interruptions.
PAGE 13
May be applied as;
A temporary constraint to deal with an outage situation when some assets are not
available.
A permanent constraint when the normal integrated power system capability and
expected generation offers and demand may not result in secure operation.
1.1.4. Security Constrained Economic Dispatch
This is the operation of generating facilities to produce energy at the lowest cost to
reliably serve consumers, recognizing any operational limits of generation and
transmission facilities. The varying nature of demand of energy and the variations in
costs of different types of generating units, together with the known and unknown
conditions on the transmission network determine which generating units to be used to
serve the load most reliably.[13]
1.1.5. HVDC system
This involves the transmission of power at high voltages with the aim of improving
system efficiency and reducing the overall energy cost.
PAGE 14
1.2.A brief introduction to HVDC system
Power transmission was formerly done in early 1880s using Direct Current (DC). With
the introduction of transformers, development of induction motors, availability of
synchronous generators and facilities that could convert alternating current to direct
current whenever required, alternating current gradually replaced direct current as a
method of power transmission. However in 1928 the availability of devices like mercury
vapor rectifiers that have the ability to rectify and invert current created possibilities for
high voltage direct current transmission.
With fast development of converters (rectifiers and inverters) that can work at higher
voltages and large currents, dc transmission became a major factor in the planning of
power transmission.
In the early stages all HVDC schemes used mercury arc valves, invariably single phase in
construction in contrast to the low voltage polyphase units used for industrial application.
Around 1960, control electrodes were added to silicon diodes, giving silicon-controlled-
rectifiers (SCRs). Among the early schemes were;[14]
The Gotland Scheme in Sweden, commissioned in 1954, capable of transmitting
20MW of power at -100KV and consisting of a single 96km cable with sea
return.
The Cross Channel link between England and France put in operation in 1961,
two single conductor submarine cables 64km at ±100KV with two bridges each
rated at 80MW.
Sakuma Frequency Changer in 1965 to connect the 50Hz and 60Hz systems of
Japan, capable of transmitting 300MW in either direction at 250KV.
With the growing application of HVDC transmission, need arises to formulate Economic
Dispatch for it. This entails the allocation of generation levels to generating units in a
power system employing HVDC lines to economically serve the load in entirety while
remaining within the operational limits of the generating and transmitting facilities.
The fundamental processes in an HVDC system is the conversion of electrical current
from AC to DC (rectification) at the transmitting end, and from DC to AC at the
receiving end. There are three ways of achieving conversion;[12]
I. Use of Natural Commutated Converters; are most used in HVDC systems today.
A thyristor capable of handling 4000A currents and blocking up to 10KV is used.
Series connection of these thyristors to form a thyristor valve enables them to
block hundreds of KV. The thyristor is operated at net frequency (50Hz or 60Hz)
PAGE 15
and change of DC voltage level is achieved by means of adjusting the control
angle of the thyristor.
II. Use of Capacitor Commutated Converters (CCC); this is an improvement of the
thyristor-based-commutation. Commutation capacitors are inserted in series
between the converter transformers and the thyristor valves. These capacitors
improve the commutation failure performance of the converters when connected
to weak networks.
III. Use of forced commutated converters; the valves of these converters are made
with semiconductors with the ability to turn-on and also turn-off. They are known
as Voltage Source Converters (VSCs). Semiconductors normally used to are
Gate-Turn-Off Thyristors (GTOs) and Insulated Gate Bipolar Transistors
(IGBTs). The VSC commutates with high frequency and its operation is achieved
by Pulse Width Modulation (PWM). With PWM it is possible to create any phase
angle and/or amplitude by changing the PWM pattern, which can be done almost
instantaneously. Thus PWM offers possibility to control both active and reactive
power independently, making the PWM VSC a close to ideal component in the
transmission network.
1.2.1. Components of an HVDC transmission system
The three main elements in an HVDC system are;
i. Converter Station
Converter stations at each ends are replicas of each other and thus consists of all
equipment needed to convert from AC to DC and vice versa. The main
components here are;
Thyristor valves – most common way of arranging thyristor valves is in a
twelve-pulse group with three quadruple valves. All communication
between the control equipment at earth potential and each thyristor at high
potential is done with fiber optics.
VSC valves – consists of two level or multilevel converter, phase-reactors
and AC filters. VSC valves, control equipment and cooling equipment are
in enclosures which make transport and installation easy.
Transformers – adapt the AC voltage level to DC voltage level and
contribute to commutation reactance.
AC filters and Capacitor banks – filters are installed in order to limit the
amount of harmonics to the level required by the network. In the
conversion process the converter consumes reactive power which is
compensated for in part by the filter banks and the rest by capacitor banks.
DC filters – reduce the disturbances in telecommunication systems created
by harmonics due to HVDC converters.
PAGE 16
ii. Transmission medium
Most frequently overhead line, normally bipolar (that is, two conductors with
different polarity) when over land. HVDC cables are used for submarine
transmission.
iii. Electrodes
Are conductors that provide connection to the earth for neutral. They have large
surface to minimize current densities and surface voltage gradients.
1.2.2. HVDC systems control
Control is done for efficiency and stability of the system, and also for maximum
flexibility of power control without compromising on safety of equipment.
The parameters mostly controlled are;
Direct current from rectifier to inverter cos cosdr di
d
cr L ci
V VI
R R R
rectifier end voltage
inverter end voltage
rectifier resistance
inverter resistance
transmission line resistance
dr
di
cr
ci
L
V
V
R
R
R
Power at the rectifier terminal dr dr dP V I
Power at the inverter terminal 2
di di d dr L dP V I P R I
The means of control is by control of the internal voltages that can be used to control the
voltage at any point along the transmission line and the current flow or power.
This is done by controlling the firing and extinction angles of the rectifiers and inverters
(fast action) or by changing taps on the transformers on the AC side (slow response).
Power reversal is done by reversing the polarity of the DC voltages at both ends, current
flow remains unchanged (since valves can only conduct in on direction)
A control action may be chosen with aim of prevention of large fluctuations in DC
voltage/current due to variations in the AC side voltage, maintenance of direct current
PAGE 17
voltage near the rated value or to keep power factor at the receiving and transmitting ends
as high as possible.
Tap changer control is used to keep the converter firing angle ( & ) within the desired
range. They are sized to allow for minimum and maximum steady state voltage variation.
For current limits, the maximum short circuit current is limited to 1.2 to 1.3 times the
normal full load current to avoid thermal damage of equipment. Minimum current limit is
set to avoid ripple in the current that may cause it to be discontinuous or intermittent.
Minimum firing angle limit is set to prevent reversal of power flow as a result of the
inverter station switching to rectification mode in case of a DC fault.
For power control, the current order required to transmit a scheduled power is given by;
, is thescheduled power, thecontrolled voltageoord o d
d
PI P V
V
1.2.3. HVDC configurations
There are three HVDC configurations; monopolar, bipolar and homopolar systems.
Monopolar HVDC systems have either ground return or metallic return.
A monopolar HVDC system with ground return consists of one or more six-pulse
converter units in series or parallel at each end. It can be a cost-effective solution
for an HVDC cable transmission and/or the first stage of a bipolar scheme. At
each end of the line it requires an electrode line and a ground or sea electrode
built for continuous operation.
A monopolar HVDC system with metallic return usually consists of one high
voltage and one medium voltage conductor. A monopolar configuration is used
either in the first stage of a bipolar scheme, avoiding ground currents, or when
construction of ground electrode lines and ground electrodes result in an
uneconomical solution due to a short distance or high value of earth resistivity.
Bipolar HVDC systems consist of two poles, each of which includes one or more
twelve-pulse converter units in series or parallel. There are two conductors, one
with positive and the other with negative polarity. For power flow in the other
PAGE 18
direction, the two conductors reverse their polarities. A bipolar system is a
combination of two monopolar schemes with ground return.
Back-to-Back HVDC links are special cases of monopolar HVDC
interconnections where there is no DC transmission line and both converters are
located at the same site. For economic reasons each converter is usually twelve-
pulse converter unit, and the valves for both converters may be located in one
valve hall. The control system, cooling equipment and auxiliary system may be
integrated into configurations common to the two converters.
Generally for a Back-to-Back HVDC link, the DC voltage rating is low and the
thyristor valve current rating is higher in comparison with HVDC
interconnections via overhead lines or cables.
1.2.4. Reasons for HVDC
Some short comings of AC transmission as well as the need to incorporate the upcoming
renewable energy from sources such as solar and wind compel a change and application
of DC technology. Some gaps in high voltage AC transmission are;[7]
Inductive and capacitive elements of overhead lines and cables put limits to the
transmission capacity and the transmission distance for AC transmission links.
Depending on the required transmission capacity, the system frequency and the
loss evaluation, the achievable transmission distance for an AC cable is in the
range of 40 to 100km, mainly limited by charging current.
Direct connection between two AC systems with different frequencies is not
possible.
Direct connection between two AC systems with the same frequency or a new
connection within a meshed grid may be impossible because of system instability,
too high short-circuit levels or undesirable power flow scenarios
1.2.5. Comparison between DC and AC systems
Comparison can be done under technical merits, economic considerations and
environmental issues.
Technical Merits of HVDC
The advantages of a DC link over an AC link are;
A DC link allows for power transmission between AC networks with different
frequencies or networks which cannot be synchronized for some reasons.
PAGE 19
Transmission capacity or the maximum length of a DC line or cable is not limited
by inductive and capacitive parameters. The conductor cross-section is also fully
utilized because there is no skin effect.
A digital control system provides accurate and fast control of the active power
flow.
Fast modulation of DC transmission power can be used to damp power
oscillations in an AC grid and thus improve the system stability.
Economic considerations
For a given transmission task, feasibility studies are conducted before the final decision
on implementation of an HVAC or HVDC system can be made. The figure below shows
a typical comparison curve between AC and DC transmission considering AC vs DC
station terminal costs, AC vs DC line costs, and AC vs DC capitalized value of losses.[7]
Fig 1.1 Total cost/distance[7]
The DC curve is not as steep as the AC curve because of considerably lower line costs
per kilometer. For long AC lines the cost of intermediate reactive power compensation
has to be taken into account. The break even distance is in the range of 500 to 800km
depending on factors like country-specific cost elements, interest rates for projects
financing, loss evaluation, and cost of right of way, among others.
Environmental issues
An HVDC transmission system is basically environment friendly because improved
energy transmission possibilities contribute to a more efficient utilization of existing
PAGE 20
power plants. The land coverage and the associated right of way cost for an HVDC
overhead transmission line is not as high as that of an AC line. This reduces the visual
impact and saves land compensation for new projects. It is also possible to increase the
power transmission capacity for existing right of way. [7]
Fig 1.2 Typical transmission line structures for approximately 1000MW[7]
There are however some environmental issues which must be considered for the
converter stations. These include audible noise, visual impact, electromagnetic
compatibility and use of ground or sea return path in monopolar operation, among others.
In general it can be said that an HVDC system is highly compatible with any
environment and can be integrated into it without the need to compromise on any
environmentally important issues of today.
1.3.Problem statement
The aim of this paper is to introduce security constraints to the economic dispatch
through the analysis of factors affecting the generation of energy at the generating units
and the transmission of that energy to the demand centers using High Voltage Direct
Current.
To solve this problem, adequate knowledge of economic dispatch, system security and
HVDC as well as its security aspects and transmission is a fundamental requirement.
1.4.Objectives
To obtain an optimal solution to the Security Constrained Economic Dispatch, the
following objectives are to be achieved;
To formulate the ED problem taking into consideration the constrains in
generation of power and its transmission using HVDC
PAGE 21
To study the methods of solution of the Security Constrained Economic Dispatch
problem, and
To come up with an optimal solution for the problem
1.5.Research Questions
The process and outcome of the project will attempt to address the following questions;
What are the constraint to be considered while undertaking a Security Constrained
Economic Dispatch for HVDC?
What is the most effective technique to apply in solving this particular SCED
problem?
PAGE 22
CHAPTER 2
LITERATURE REVIEW
Economic Dispatch (ED) entails optimal allocation of the outputs of a large number of
participating generators.
Security Constrained Economic Dispatch seeks to optimize the process, taking into
account all the relevant factors pertaining to selection of the generating units to dispatch
so as to deliver a reliable supply of power at the lowest cost possible.
The choice as to whether a generating unit should participate in sharing the load at a
given interval of time is a problem of unit commitment. The unit commitment problem
having been solved, optimal allocation of the available generation units to meet the
forecasted load demand for the time interval in question is done.
ED process has two stages, also referred to as time periods;
PAGE 23
a. Unit commitment stage – the operators decide which units to be committed to be
online for each hour, usually for the next 24hrs period, based on load forecast
taking into account the unit’s maximum and minimum output levels, the
minimum time a generator in the unit must run once started, the generating costs
and the costs of environmental compliance and how quickly the output of the unit
can be changed. Also of importance to consider under this stage are the forecasted
conditions that can affect transmission grid, that is, the “security constrained”
aspect of commitment analysis, as well as the generation and transmission
facilities outages, line capabilities (limits and directions) and weather. If security
analysis indicate that optimal ED cannot be done reliably, relatively expensive
generators may have to be opted for.
b. Unit dispatch stage – operators decide in real time the level at which each
available resource (as determined from stage (a)) should be operated, given the
actual load and grid conditions, such that reliability is maintained and overall
production costs are minimized.
Optimization techniques are used to determine not only the optimal outputs of the
participating generators, but also the optimal settings of various control devices such as
the tap settings of Load Tap Changers (LTCs), outputs of VAR compensating devices,
desired settings of phase shifters, among others.
The desired objectives for optimization problems include minimization of the cost of
generation, minimization of the total power loss in the system, minimization of voltage
deviations, and maximization of the reliability of the power supplied to customers. While
formulating the optimization strategy, one or more of these objectives can be taken into
consideration. Determination of the real power output of the generators so that the total
cost of generation in the system is minimized is known as Economic Dispatch.
The majority of generating systems are of three types; nuclear, hydro and thermal (using
fossil fuels such as coal, oil and gas), but due to developments in the technology of
renewable energy, and with rising environmental concerns together with rising demand
for power, these sources are currently complemented by other sources such as wind, solar
and tidal energy. Nuclear plants tend to be operated at constant output power levels.
Operating cost of hydro units do not change much with the output. The operating cost of
thermal plants however change significantly with the output power level, and therefore
are considered in this paper for discussing the ED problem.
2.1.Economic dispatch problem neglecting transmission losses
First the ED problem is considered with the transmission losses neglected (like in the
case of Back-to-Back HVDC systems where systems operating at different frequencies
are joined together and at one location and the transmission distance is essentially zero or
where a group of generators are connected to a particular bus-bar like in the case of
PAGE 24
individual generating units in a power plant, or when they are physically located very
close to each other, and thus the transmission losses can be ignored due to the short
distance involved).[10]
Consider the Fig2.1 below showing N-thermal units connected to a bus to serve a load
LoadP .
Fig 2.1 N-thermal units connected to a bus to serve a load LoadP [9]
Input to each unit is expressed in terms of cost rate, say $/h. The total cost rate is the sum
of cost rates of each of the individual units. The essential operating constraint is that the
sum of the power outputs must be equal to the load (neglecting power losses).
2.1.1. Fuel cost characteristics
ED problem is the determination of generation levels with the aim of minimizing the total
cost of generation for a defined level of load. For thermal generating units, the cost of
fuel per unit power output varies significantly with the power output of the unit. In
solving the ED problem, the fuel cost characteristics of the generators are considered
while finding their optimal real power outputs. A typical fuel cost characteristics is as
shown in Fig2.2 below.
PAGE 25
Fig2.2 A typical fuel cost characteristics[9]
The labor cost, supply and maintenance are generally fixed. MinP is the output level below
which it is uneconomical or technically infeasible to operate the units. MaxP on the other
hand is the maximum output power limit. In formulating the dispatch problem, fuel costs
are usually represented as a quadratic function of output power as shown by the equation
below.
2( )F P aP bP c (2.1)
2.1.2. Problem formulation
Total fuel cost for operating N generators is given by;
1 1 2 2( ) ( ) ... ( )T N NF F P F P F P (2.2)
1
( )N
i i
i
F P
(2.3)
With transmission losses neglected, total generation should meet the total load.
Therefore, the equality constraint is;
1
N
i Load
i
P P
(2.4)
Based on minimum and maximum power limits of the generators, the following
inequality constraint is imposed;
( ) ( )i Min i i MaxP P P ; 1,2,...i N (2.5)
This is a constrained optimization problem that can be solved by Lagrange multiplier
method.
The Lagrange method is formulated as;
TL F (2.6)
Where 1
N
Load
i
P Pi
accounts for the equality constraint (2.4), is the Lagrange
Multiplier. The necessary condition for TF to be minimum is that the derivative of
Lagrange function with respect to each independent variable is zero. Thus the necessary
conditions for the optimization problem are;
PAGE 26
Load
1 1
{ ( ) (P )N N
i i i
i ii i
LF P P
P P
(2.7)
0i
i
F
P
; 1,2,...i N (2.8) and
0i
L
P
(2.9)
Rearranging (2.8),
i
i
F
P
; 1,2,...i N (2.10)
Equation (2.10) states that to minimize the fuel cost, the necessary condition is to have all
the incremental fuel costs equal. Equation (2.10), along with the equality constraint (2.4)
and the inequality constraint (2.5) are the Coordination Equations for Economic Dispatch
with network losses neglected.
Using equation (2.1), fuel cost characteristics of all the generators are expressed as;
2
i i i i i iF a P b P c ; 1,2,...i N (2.11)
Using (2.10), the necessary conditions for the optimal solutions are given by;
2ii i i
i
Fa P b
P
; 1,2,...i N (2.12)
Or
2
ii
i
bP
a
; 1,2,...i N (2.13)
Substituting iP from (2.13) into (2.4), we have;
1 2
Ni
Load
i i
bP
a
(2.14)
Or
PAGE 27
1
1
( )2
[ ]1
( )2
Ni
Load
i i
N
i i
bP
a
a
(2.15)
With this, can be calculated from (2.12) and iP be determined for 1,2,...i N from
(2.11).
2.2.Economic dispatch problem considering network losses
This involves economically distributing the load among different plants of a power
system. In this case transmission losses are considered as shown in the schematic below
depicting such a system.
Fig 2.3 N thermal units serving LoadP through a transmission network with losses
For a unit with low incremental cost, operating cost may be higher if the transmission line
losses are very high (for example where there is a large distance between the unit and the
load), thus it becomes necessary to take into consideration the transmission line losses
when determining Economic Dispatch of units in a power system.
The total fuel cost rate is still as expressed by equation (2.2)
1 1 2 2( ) ( ) ... ( )T N NF F P F P F P
The power balance (equality) equation now includes the transmission losses.
PAGE 28
0
0N
Loss Load i
i
P P P
(2.16)
LossP is the total transmission loss in the system.
The problem is to find iP s that minimize TF subject to the constraint (2.16).
Using the method of Lagrange multipliers,
TL F , with given as expressed by equation (2.16).
The necessary conditions to minimize TF are as follows;
0i
L
P
; 1,2,...i N
Or
1 1
{ ( ) ( )} 0N N
i i Loss Load i
i ii
F P P P PP
(2.17)
Or
( 1) 0i Loss
i i i
F PL
P P P
; 1,2,...i N (2.18)
This (equation 2.18) is the condition for optimal dispatch.
Rearranging (2.18),
1
i
i
Loss
i
F
P
P
P
(2.19)
The equation above is often expressed as
ifi
i
FP
P
(2.20)
With fiP being the Penalty Factor of the plant, and is given by;
PAGE 29
1
1fi
Loss
i
PP
P
(2.21)
Here, Loss
i
P
P
is the incremental loss for bus i .
From Equation (2.20), the minimum cost operation is achieved when the incremental cost
(IC) for each unit multiplied by its penalty factor is same for all generating units in the
system. Relating to the case of units in the same plant, or generators connected to the
same bus, (2.20) implies;
1 21 2
1 2
... Nf f fN
N
FF FP P P
P P P
When units are connected to the same bus, incremental change with transmission loss
with change in generation is the same for all the units, thus;
1 2...f f fNP P P , and therefore;
1 2
1 2
... N
N
FF F
P P P
(2.22)
Which is the same as in the case of units connected to a bus.
Equation (2.19) and (2.16) are collectively known as coordination equations for
Economic Dispatch considering transmission losses.
2.2.1. Transmission line loss equation
Transmission line loss equation, known as Kron’s loss formula is expressed as;
T T
Loss O OOP P BP B P B (2.23)
Where P is the vector of all generator bus net outputs; B is a square matrix; OB is a
vector of same length as P ; OOB is a constant.
The B-terms are called Loss-Coefficients or B-Coefficients, and the N by N symmetrical
matrix B is simply known as the B-matrix.
Equation (2.23) can be written as;
PAGE 30
1 1 1
N N N
Loss i ij j iO i OO
i j i
P PB P B P B
(2.24)
Referring to the coordination equation, the equality constraint now becomes;
1 1 1 1
[ ]N N N N
Load i ij j iO i OO i
i j i i
P PB P B P B P
(2.25)
The derivative of Lagrange function now becomes;
1
[1 2 ]N
ij j iO
ji i
L FB P B
P P
(2.26)
The coordination equations are now coupled.
Solution of Economic Dispatch problem in this case is a little complex compared to the
case with network losses neglected.
2.2.2. Losses in HVDC systems
Typically, overall losses in HVDC transmission are 30% to 50% less than HVAC
transmission. Although HVDC incurs losses during the conversion process from AC to
DC, the line losses in HVDC cable are smaller than HVAC cables, and when used over
long distances, lower cable losses compensate for higher conversion losses of HVDC
transmission.
The power losses produced, per converter station, in VSC HVDC technology are more
than the power losses produced per converter station in LCC HVDC technologies. The
power losses in VSC per converter station are 4% to 6% of the total power being
delivered while that per converter stations in LCC HVDC are 2% to 3%. However VSCs
are preferred due to their low levels of harmonics generated hence reduced need to install
filters in offshore substations.
For a VSC HVDC system, losses can be studied under the following stages;
VSC Converter losses; divided into conduction losses and switching losses
Transmission losses, including DC cable losses, coupling transformer losses,
smoothing reactor losses and losses in AC filters.
PAGE 31
2.2.3. HVDC inequality constraints
In HVDC the inequality constraints are usually the operation or physical limits. For
instance, a transmission line capacity is constrained by its thermal limit, the bus voltages
are within their insulation limits and generating units have lower and upper output limits.
Such constraints restrict the ED of the generators to range between the maximum and
minimum values, and include;
The power generator capacity constraint
GiMin Gi GiMaxP P P
The tap ratio of the converter
Min MaxT T T
Ignition angle of the converter
Min Max
Extinction angle of the converter
Min Max
DC current
dcMin dc dcMaxI I I
DC voltage
dcMin dc dcMaxV V V
The aim of this project is to minimize the total operating cost of the power system while
meeting the total load plus the transmission losses while operating within the generator
limits and transmission line limits. The transmission losses were taken to be 40% of the
losses obtained by calculation using B coefficients for an HVAC line of equivalent
length.
Mathematically, the aim is to minimize;
2
1 1
( )N N
i i i i i i i
i i
F P a P b P c
,
Subject to the following constraints;
PAGE 32
The energy balance equation
0
N
i Loss Load
i
P P P
The generator limits
GiMin Gi GiMaxP P P
The tap ratio of the converter
Min MaxT T T
Ignition angle of the converter
Min Max
Extinction angle of the converter
Min Max
DC current
dcMin dc dcMaxI I I
DC voltage
dcMin dc dcMaxV V V
2.3.Review of solution methods
Two basic approaches are used in the solution;
1. The case of network loss formula, and
2. The case of optimization tools incorporating power flow equations and
constraints.
PAGE 33
2.3.1. Particle swarm optimization
Particle Swarm Optimization was proposed by James Kennedy and Russell C. Eberhart in
1995.[15] It is a technique used to explore the search space of a given problem to find the
settings or parameters required to maximize a particular objective. It originates from two
concepts; the idea of swarm intelligence based on the observation of swarming habits of
certain kinds of animals, and the field of evolutionary computation.
Optimization is the mechanism by which the maximum or minimum value of a function
or process is obtained. A search space is defined, with elements called candidate
solutions of the search space. The number of parameters involved in the optimization
problem is the dimensions of the search space. An objective function maps the search
space to the function space. For a known function, calculus may be used to easily provide
the minima or maxima as desired. In real life however, the objective function is not
directly known. Instead, the objective function is a “black box” to which we apply
parameters and receive an output value. The result of this evaluation of a candidate
solution becomes the solution’s fitness. The final goal of an optimization task is to find
the parameters in the search space to maximize or minimize the fitness.[17]
The elements of a candidate solution may be subject to certain constraints, in which case
the task becomes a constrained optimization task.
Each particle is searching for an optimum and is moving, hence has a velocity. Each
particle remembers the position at which it had its best so far (its personal best). To
improve the effectiveness, particles in the swarm co-operate by exchanging information
about what they have discovered in the places they had been to. Thus a particle has
neighbors associated with it, it knows the fitness of those in its neighborhood, and uses
the position of the one with best fitness to adjust its own velocity.
In each time step a particle has to move to a new position by adjusting its velocity. The
adjustment is the sum of its current velocity, a weighted random portion in the direction
of its personal best, and a weighted random portion in the direction of the neighborhood
best.
Particles’ velocity on each dimension are clamped to a maximum velocity MaxV . If the sum
of accelerations would cause the velocity on that dimension to exceed MaxV , a parameter
specified by the user. Then the velocity in that direction is limited to MaxV .
Particle Swarm Optimization is a preferred method of solving ED problems for among
others the following reasons;
With a population of candidate solutions, a PSO algorithm can maintain useful
information about the characteristics of the environment.
PAGE 34
PSO, as characterized by its fast convergence behavior, has an inbuilt ability to
adapt to a changing environment.
Some early works on PSO have shown that PSO is effective for locating and
tracking options in both static and dynamic environment.
As compared to other optimization techniques, PSO is a simple concept that is
easy to implement, cheaper, impervious to failure regardless of user input or
unexpected conditions and takes less time to converge.
2.3.2. Genetic algorithm
First proposed by Frazer and later by Bremermann and Raed, Genetic Algorithm was
popularized by the work of Holland. GA models genetic evolution. Features of
individuals are expressed using genotypes. The main driving operators of a GA is
selection which models survival of the fittest and recombination through application of a
crossover operator that models reproduction.[17]
A population of individuals (phenotypes) to an optimization problem is evolved towards
better solutions. Each candidate solutions’ features are mutated. The process starts from a
population of individuals and is an iterative process resulting in successive generations.
For each generation the fitness of each individual is evaluated, the fitness being the value
of the objective function in the optimization problem being solved. The more fit
individuals are stochastically selected from the current population and each individual’s
genome modified to form the next generation. This generation solutions are then used in
the next iteration of the algorithm. The algorithm terminates when a satisfactory fitness
level has been reached for the population.
Although Genetic Algorithm always converges, it does not give assurance that a global
optimum will be obtained. It also lacks a constant optimization response time.
2.3.3. Evolutionary Programming
Evolutionary Programming (EP) was first used by Lawrence J. Fogel in the US in 1960 to
use simulated evaluation as a learning process to generate artificial intelligence. While
EP shares the objectives of imitating natural evolutionary processes, with Genetic
Algorithm and Genetic Programming, it differs substantially in that EP emphasizes the
development of behavioral models and not genetic models. EP considers phenotypic
evolution, it iteratively applies two evolutionary operators; variation through application
of mutation operators and selection.[17]
The evolutionary process, first developed to evolve finite state machines, consists of
finding a set of optimal behaviors from a space of observable behaviors. The fitness
PAGE 35
function measures the “behavioral error” of an individual with respect to the environment
of that individual.
EP utilizes four main components of Evolutionary Algorithm (EA).
Initialization; a population of individuals is initialized to uniformly cover the
domain of the optimization problem.
Mutation; the mutation operator introduces variation in the population to produce
new candidate solutions. Each parent produces one or more offspring through
application of the mutation operator.
Evaluation; a fitness function is used to quantify the “behavior error” of
individuals. While the fitness function provides an absolute fitness measures to
indicate how well the individual solves the problem being optimized, survival in
EP is usually based on a relative fitness measure. A score is computed to quantify
how well an individual compares with a randomly selected group of competing
individuals. Individuals that survive to the next generation are selected based on
this relative fitness.
Selection; the selection operator selects the individuals that survive to the next
generation.
The setback with EP is its slow convergence in solving some of the multimodal
optimization problems.
2.3.4. Linear Programming
Linear programming is the most commonly applied form of constrained optimization.
The main elements of any constrained optimization problem are;
Variables (decision variables); values are unknown at start, usually represent
things that can be adjusted or controlled. The goal is to find values of the
variables that provide the best value of the objective function.
Objective function; is a mathematical expression that combines the variables to
express the goal. The requirement is to either maximize or minimize the objective
function.
Constraints; are mathematical expressions that combine the variables to express
limits on the possible solutions.
In linear programming all the mathematical expressions for the objective function and the
constraints are linear, thus it has an inaccurate evaluation of system losses and a limited
ability to find accurate solutions due to its linear approximation of non-linear control
parameters as compared to an exact non-linear model of a power system.[17]
PAGE 36
2.3.5. Lambda iteration
When the minimization is constrained with an equality constraint it can be solved using
the method of Lagrange Multiplier. The key idea is to represent a constrained
minimization problem as an unconstrained problem.[11]
Lambda iteration method requires a unique mapping of from a value of lambda
(incremental cost) to each generator’s output. For any choice of lambda the generators
collectively produce an output. The methods starts with values of lambda below and
above the optimal value (corresponding to too little and too much output), and then
iteratively brackets the optimum value. Inclusion of losses impact the necessary
conditions for an optimal economic dispatch. The analytic calculation of the penalty
factor is involving, the problem is that a small change in the generation impacts the flow
and hence the losses throughout the entire system. However using a power flow, the
function can be approximated by making a small change to the output of individual
generators and seeing how the losses change.
PAGE 37
CHAPTER 3
SOLUTION OF SECURITY CONSTRAINED ECONOMIC DISPATCH USING
PSO
3.1.PSO Algorithm
The PSO algorithm works by simultaneously maintaining several candidate solutions in
the search space. Initially, the algorithm chooses candidate solutions randomly within the
search space composed of all possible solutions. The algorithm uses the objective
function to evaluate its candidate solutions and operates upon the resultant fitness values.
PAGE 38
Fig 3.1. PSO Algorithm
PAGE 39
Each particle maintains its position, composed of the candidate solution and its evaluated
fitness, and its velocity. Additionally, it remembers the best fitness value it has achieved
thus far during the operation of the algorithm, referred to as the individual best fitness,
and the candidate solution that achieved this fitness, referred to as the individual best
position or individual best candidate solution. Finally, the PSO algorithm maintains the
best fitness value achieved among all particles in the swarm, called the global best
fitness, and the candidate solution that achieved this fitness, called the global best
position or global best candidate solution.
The PSO algorithm consists of just three steps, which are repeated until some stopping
condition is met:
1. Evaluate the fitness of each particle
2. Update individual and global best fitness and positions
3. Update velocity and position of each particle
The first two steps are fairly trivial. Fitness evaluation is conducted by supplying the
candidate solution to the objective function. Individual and global best fitness and
positions are updated by comparing the newly evaluated fitness against the previous
individual and global best fitness, and replacing the best fitness and positions as
necessary.
The velocity and position update step is responsible for the optimization ability of the
PSO algorithm. The velocity of each particle in the swarm is updated using the following
equation:
1
1 1 2 2
2
]
0 1and
1 , 1 1 1 1
,
0 1
,
,
j j j pbest j gbest j
max max
V t w t V t c r X t X t c r X t X
x
r r
t
x
The index of the particle is represented by j. Thus, ( )jv t is the velocity of particle i at
time t and ( )jx t is the position of particle j at time t. The parameters w , 1c and 2c
( 10 1.2,0 2,w c and 20 2c ) are user-supplied coefficients. The values 1r and
2r ( 1 20 1and 0 1r r ) are random values regenerated for each velocity update. The
value ,j pbestX is the individual best candidate solution for particle i at time t, and gbestX is
the swarm’s global best candidate solution at time t.
Each of the three terms of the velocity update equation have different roles in the PSO
algorithm. The first term 1jw t V t is the inertia component, responsible for keeping
PAGE 40
the particle moving in the same direction it was originally heading. The value of the
inertial coefficient w is typically between 0.8 and 1.2, which can either dampen the
particle’s inertia or accelerate the particle in its original direction. Generally, lower values
of the inertial coefficient speed up the convergence of the swarm to optima, and higher
values of the inertial coefficient encourage exploration of the entire search space.
The second term 1 1 , 1 1 j pbest jc r X t X t , called the cognitive component, acts
as the particle’s memory, causing it to tend to return to the regions of the search space in
which it has experienced high individual fitness. The cognitive coefficient 1c is usually
close to 2, and affects the size of the step the particle takes toward its individual best
candidate solution gbestX .
The third term 2 2 1 1gbest jc r X t X t , called the social component, causes the
particle to move to the best region the swarm has found so far. The social coefficient 2c is
typically close to 2, and represents the size of the step the particle takes toward the global
best candidate solution gbestX the swarm has found up until that point.
The random values 1r in the cognitive component and 2r in the social component cause
these components to have a stochastic influence on the velocity update. This stochastic
nature causes each particle to move in a semi-random manner heavily influenced in the
directions of the individual best solution of the particle and global best solution of the
swarm.
In order to keep the particles from moving too far beyond the search space, we use a
technique called velocity clamping to limit the maximum velocity of each particle. For a
search space bounded by the range , ,max maxx x velocity clamping limits the velocity to
the range , ,max maxv v where *max maxv k x .
The value k represents a user-supplied velocity clamping factor, 0.1 1.0.k In
many optimization tasks, such as the ones discussed in the paper, the search space is not
centered on 0 and thus the range , ,max maxx x is not an adequate definition of the search
space. In such a case where the search space is bounded by , ,min maxx x we define
*( ) / 2max max minv k x x .
Once the velocity for each particle is calculated, each particle’s position is updated by
applying the new velocity to the particle’s previous position:
1 j j jX t X t V t
PAGE 41
This process is repeated until some stopping condition is met. Some common stopping
conditions include: a preset number of iterations of the PSO algorithm, a number of
iterations since the last update of the global best candidate solution, or a predefined target
fitness value.
For this project, the constrained optimization problem is converted as an unconstrained
optimization using penalty function method.
In fitness penalization of a solution, the fitness function is the sum of the objective
function value and the sum of constraint violation.[5]
i.e. minimize
1 1
( ) 1000*n n
i i i l
i i
F P P D P
Power loss is obtained by DC power flow with the following assumptions made;
1. All voltage magnitudes are equal to 1.0 p.u.
2. The resistances of the branches are ignored; i.e., the susceptance of the branch is
1ij
ij
Bx
3. The angle difference on the two ends of the branch is very small, such that
sin
cos 1
ij i j
ij
4. All ground branches are ignored; i.e.,
0 0 0i jB B
And therefore the DC power flow model is
1 1
2 2
1 1n n
P
PB
P
The DC power flow is a purely linear equation, so only one iteration calculation is needed
to obtain the power flow solution. It is used in calculation of real power flow on
transmission lines and transformers. The power flowing on each line using DC power
flow is;
PAGE 42
( )i j
ij ij i j
ij
P Bx
3.2.Parameter representation
The aim is to minimize the operating cost. The optimization is done by PSO technique.
The population of particles P, representing the generators where iP is the ith unit in the
power system, is initialized together with other variables. Each particle is generated
randomly within the allowable range specified by the generation limits of the particular ith
particle.
min maxi i iP P P
The size of the population, representing the number of generators is initialized along with
the initial and final inertia weight, random velocity of the particle, acceleration constant,
maximum generation, the number of iterations and Lagrange’s multiplier.
The fitness of each individual in the population is calculated using the fitness function,
which includes the cost function and the penalty function for violation of the equality and
inequality constraints.
1 1
( ) Equalityconstraints InequalityconstraintsT n
T i i
i i
C C P
Each unit’s position and velocity is updated along with the multipliers i for equality and
i for inequality constraints whose value can be 1 or 0 depending on whether the
particular constraint has been violated or has not been violated respectively.
If the number of iterations reaches the maximum, the individual that generates the latest
value is the optimal generation power of each unit with the minimum total generation
cost.
3.3.PSO Algorithm for SCED
PSO is a population based stochastic optimization technique. Each particle in the
population represents a candidate solution to the problem. All particles start at randomly
initialized positions and fly throughout the search space to find the best possible solution,
PAGE 43
while communicating with each other and sharing the best local solutions each of them
has achieved. Based on the local and global information obtained, each particle updates
its position towards a desired global optimum.[4]
The elements of the PSO algorithm are as described below:
Particle, jX t – each particle is a candidate solution vector containing n
optimization variables. jX t is the thj particle at time t described as;
1 2 , , , ,j j j j nX t x t x t x t
The particle vector describes the particle’s position within the search space.
Population, Pop t – is a set of m particles at time t ,
Particle velocity, jV t – is the velocity of the thj particle at the time t in the n-
dimensional search space represented as;
1 2 , , , ,T
j j j j nV t v t v t v t
The velocity of the particle indicates the relative change of the particle within the
solution space with respect to its current position vector. For each time increment
a particle’s velocity demonstrates the time rate of change to the particle’s solution
vector.
Individual best ,j pbestX t – is the best position achieved by the thj particle so far
at time t . Each particle memorizes its best position throughout the entire searching
process.
Global best, gbestX t – is the best solution that has been achieved so far among
all the particles. The information of global best is known to all the particles
through communication among the particles.
The PSO algorithm is implemented in the order below
Initialization – at the start t = 0, all particles are initialized with a randomly
assigned position and velocity value. The thi dimensional position ,j ix of the thj
particle is initialized with a uniform random value between lower and upper
bounds. The thi dimensional velocity of the particle is initialized with a uniform
random value between – imaxv and imaxv , with ( ) ( )– i u i l
imax
im
x xv
N where ( )i ux and
( )i lx are the upper and lower bounds of the of the particles position respectively in
the thi dimension and imN is the minimum number of steps that change a particles
PAGE 44
position from its lower bound to its upper bound of the thi dimension, a value
chosen by the user.
Velocity updating – during each iteration cycle the particle velocity is updated
according to the following formula.
1 1 2 2 1 , 1 1 1 1 ]j j pbest gbestV t w t V t c r Xj t Xj t c r X t Xj t
Where w t is the inertia weighting factor, 1c and 2c are two positive constants,
and 1r and 2r are uniform random numbers in [0, 1].
Position updates – with the velocity updated, each particle changes its position
according to the formula;
1 j j jX t X t V t
Process termination – the process stops when a specified stopping criterion is met,
for instance when the number of iterations reach a pre-specified maximum.
PAGE 45
CHAPTER 4
RESULTS AND ANALYSIS
The proposed Particle Swarm Optimization algorithm was tested on IEEE – 30 bus
systems and results compared with those obtained from Classical Economic Dispatch
neglecting security constraints, as well as with results obtained from Genetic Algorithm.
The Network topology, load data, line limits and generator cost data for the systems are
taken from [1].
4.1.Case Study: IEEE 30-Bus System
Fig 4.1: One line diagram of IEEE 30-bus system [1]
PAGE 46
4.2.Results
The optimal total generation, generation for the individual six generating units, the
optimal generation costs for each unit, the total generation cost and the system power
losses by PSO are given in tables 4.1 and 4.2 for SCED as well as CED for system
demand of 540MW and 840MW. Table 4.3 shows the comparison between the results
from the proposed PSO method with those from GA for a total demand of 840MW.
Table 4.1: Optimal generation for SCED and CED using PSO for a total demand of
283.4MW
Generation No. SCED CED
PG1 166.003 168.289
PG2 43.8662 50.1362
PG5 20.7474 26.4431
PG8 26.9202 23.1219
PG11 17.5307 10.8661
PG13 16.8103 13.2421
Total generation (MW) 291.878 292.098
Total cost ($/hr) 801.712 803.898
Total loss (MW) 8.47783 8.6982
PAGE 47
Table 4.2: Optimal generation for SCED and CED using PSO for a total demand of
374.3MW
Generation No. SCED CED
PG1 175.305 193.811
PG2 61.6824 52.011
PG5 30.8379 34.0868
PG8 44.3274 45.164
PG11 40.6352 26.8235
PG13 31.2773 33.2283
Total generation (MW) 384.065 385.125
Total cost ($/hr) 1172.5 1163.01
Total loss (MW) 9.76504 10.8245
Table 4.3: Optimal generation for SCED and CED using PSO for a total demand of
540MW
Generation No. SCED CED
PG1 109.883 149.128
PG2 80.7397 83.7191
PG5 68.1473 50
PG8 130.108 90.8636
PG11 81.3105 101.135
PG13 82.3566 80
Total generation (MW) 552.545 554.846
Total cost ($/hr) 2268.03 2180.01
Total loss (MW) 12.545 14.8457
PAGE 48
Table 4.4: Comparison of Economic Dispatch using PSO and GA for a total demand
of 283.4MW.
Generation No. PSO GA
PG1 166.003 175.7899
PG2 43.8662 48.2548
PG5 20.7474 22.0974
PG8 26.9202 22.3942
PG11 17.5307 12.3715
PG13 16.8103 11.3669
Total generation (MW) 291.878 292.795
Total cost ($/hr) 801.712 802.3516
Total loss (MW) 8.47783 9.395
PAGE 49
4.3.Analysis and Discussions
Fig 4.2: Variation of Real Power Losses with Power Demand for SCED and CED
0
2
4
6
8
10
12
14
16
0 100 200 300 400 500 600
Rea
l P
ow
er L
oss
es (
MW
)
Demand (MW)
SCED CED
PAGE 50
Fig 4.3: Variation of Optimal Cost with Power Demand for SCED and CED
Fig 4.2 is a graph showing the variation of Real Power Losses with Demand for both
SCED and CED. The Real Power Losses increase with increasing Total Demand. In
comparison, the Real Power Losses are lower for the SCED case than or the CED. A
possible explanation for this could be due to the fact that SCED aims at operating within
the power flow limits and as a consequence reduces the power loss in the buses.
Fig 4.3 shows variation of Optimal Cost with power demand for SCED and CED. The
cost of generation is observed to increase with increasing demand, a fact that can be
attributed to higher fuel requirement for higher power generation. It can also be observed
that the cost of generation under SCED is higher than that under CED. The margin
between the two is more pronounced at higher demand. This can be explained from the
fact that higher costs occur when the transmission line constraints are violated. At low
power demand, the power flow is more likely within the bus limits, or if it goes above the
limits it is by a small magnitude. Increasing demand increases the strain on the system
resources in an attempt to meet this demand, and with that, increases the costs.
0
500
1000
1500
2000
2500
0 100 200 300 400 500 600
Op
tim
al C
ost
($/
hr)
Demand (MW)
SCED CED
PAGE 51
CHAPTER 5
CONCLUSION AND RECOMMENDATIONS
5.1.Conclusion
The project utilizes the PSO algorithm to solve the security constrained economic
dispatch problem for HVDC. The procedure was tested on the IEEE 30-bus network with
six generators. The results of the various parameters from the SCED for HVDC using
PSO were compared with results of similar published works obtained using Genetic
Algorithm to verify the effectiveness of the proposed PSO algorithm. In this project, the
security aspects considered were the generator active power limits and the real power
flow limits of the buses.
From the comparisons done, the PSO algorithm exhibited the advantages of lower
optimal cost, lower total losses and higher probability of convergence to the global
optimum. The method is therefore appropriate for network flow analysis.
5.2.Recommendations
More research and study is necessary on HVDC systems with regards to security
constraints, and to economic dispatch as a whole.
Power flow in PSO code was found to be rather slow in execution. The computational
time could be reduced by lowering the number of iterations, which on the negative side
could increase the chances of settling at a local minimum thus inhibiting achieving of the
optimal solution, the global minimum.
Use of a Hybrid Particle Swarm Optimization algorithm could enhance the chances of
obtaining best results with a lower computational time. Such a method can be considered
in future projects.
PAGE 52
REFERENCES
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PAGE 54
APPENDIX
Appendix Table1: Generator data for IEEE 30-bus system [1]
Generators No.1 No.2 No.5 No.8 No.11 No.13
Pgimax(pu) 2.00 0.80 0.50 0.35 0.30 0.40
Pgimin(pu) 0.50 0.20 0.15 0.10 0.10 0.12
Qgimax(pu) 2.50 1.00 0.80 0.60 0.50 0.60
Qgimin(pu) -0.20 -0.20 -0.15 -0.15 -0.10 -0.15
Cost Function
ai 0.00375 0.0175 0.0625 0.0083 0.0250 0.0250
bi 2.00000 1.7500 1.0000 3.2500 3.0000 3.0000
ci 0.00000 0.0000 0.0000 0.0000 0.0000 0.0000
Appendix Table 2: Load data for IEEE 30-bus system [1]
Bus no. PD(p.u) QD(p.u) Bus no. PD(p.u) QD(p.u)
1 0.000 0.000 16 0.035 0.016
2 0.217 0.127 17 0.090 0.058
3 0.024 0.012 18 0.032 0.009
4 0.076 0.016 19 0.095 0.034
5 0.942 0.190 20 0.022 0.007
6 0.000 0.000 21 0.175 0.112
7 0.228 0.109 22 0.000 0.000
8 0.300 0.300 23 0.032 0.016
9 0.000 0.000 24 0.087 0.067
10 0.058 0.020 25 0.000 0.000
11 0.000 0.000 26 0.035 0.023
12 0.112 0.075 27 0.000 0.000
13 0.000 0.000 28 0.000 0.000
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14 0.062 0.016 29 0.024 0.009
15 0.082 0.025 30 0.106 0.019
Appendix Table 3: Line flow limits data for IEEE 30-bus system [1]