Operations-Training-SolutionsThe focus of O-T-S is the
development and delivery of training programs for electric power
system operations personnel.
Southwest 2011 OutageThe Dynamics of Disturbances class has been
updated to include a detailed description of the 9/8/2011 Southwest
outage.
NERC Practice Tests
Synchronizing and Synchronizing Equipment1. Synchronizing and
Synchronizing Equipment1.1 Theory of SynchronizingWhen closing a
circuit breaker between two energized parts of the power system, it
is crucial to match voltages on both sides of the circuit breaker
before closing. If this matching or "synchronizing" process is not
done correctly, a power system disturbance will result and
equipment (including generators) can be damaged. In order to
synchronize properly, three different aspects of the voltage across
the circuit breaker must be closely monitored. The three aspects of
the voltage are called the synchronizing variables and are:1. The
voltage magnitudes2. The frequency of the voltages3. The phase
angle difference between the voltages1.1.1 Voltage Magnitude
Synchronizing VariableIf the voltage magnitudes are not closely
matched, a sudden rise in Mvar flow will appear across the circuit
breaker as it is closed. For example, if a 345 kV circuit breaker
were closed with a 20 kV difference in voltage across the open
circuit breaker, a large Mvar flow would suddenly occur upon
closing. The allowable voltage magnitude differences across the
open circuit breaker are system specific. However, for general
guidance, a difference of a few percent is unlikely to cause any
serious problem.1.1.2 Frequency Synchronizing VariableIf the
frequencies on either side of an open circuit breaker are not
matched prior to closing, a sudden change in MW flow will appear
across the circuit breaker as it is closed. The sudden MW flow
change is in response to the initial frequency difference as the
system seeks to establish a common frequency once the circuit
breaker is closed. The allowable frequency difference is again
system specific. However, a general guideline would be to have the
frequencies within 0.1 Hz of each other prior to closing.1.1.3
Phase Angle Synchronizing VariableThe third synchronizing variable
- and likely the most important of the three - is the voltage phase
angle difference. If the phase difference between the voltages on
either side of the open circuit breaker is not reduced to a small
value, a large MW flow increase will suddenly occur once the
circuit breaker is closed. The voltage phase angle difference is
the difference between the zero crossings of the voltages on either
side of the open circuit breaker. Ideally, the voltage phase angle
should be as close to zero degrees as possible before closing the
circuit breaker.1.2 Synchronizing ExamplesThe importance of
synchronizing cannot be overstated. All system operators should
understand the theory and practice of synchronizing. If two power
systems are synchronized via an open circuit breaker, and the
synchronizing process is not done correctly, generators can be
severely damaged. Two scenarios for synchronizing follow to further
describe the synchronizing process.1.2.1 Scenario #1: Synchronizing
Two IslandsThe first scenario assumes that two islands are about to
be connected together using the open circuit breaker as illustrated
in Figure 1. The two islands, since they are independent electrical
systems, will have different frequencies so all three of the
synchronizing variables must be monitored to ensure they are within
acceptable limits prior to closing the open circuit breaker.The
system operators for the two islands will likely have to adjust
generator MW output levels (or adjust island load magnitudes) in
one or both islands to achieve the desired adjustment in
frequencies and phase angles. Voltage control equipment (reactors,
capacitors, etc.) may also be used as necessary to change voltage
magnitudes to within acceptable levels.
Figure 1Synchronizing Two Islands1.2.2 Scenario #2: Establishing
the Second TieOnce the first transmission line is closed
interconnecting the two islands, the frequency will be the same in
the two areas. Therefore, one of the three synchronizing variables
(the frequency) is no longer a factor. However, as illustrated in
Figure 2, the other two synchronizing variables must still be
monitored. Generation and/or voltage control equipment may be to be
utilized to ensure the phase angle and voltage magnitude
differences are within acceptable limits prior to closing the
second circuit breaker. This process should be easier than closing
the first transmission line (Scenario #1) as frequency is no longer
a factor. Figure 2Establishing the Second Transmission Tie1.3
Synchronizing Equipment1.3.1 SynchroscopeA synchroscope is a simple
piece of equipment that is used to monitor the three synchronizing
variables. A basic synchroscope (illustrated in Figure 3) inputs
voltage waveforms from the two sides of the open circuit breaker.
If the voltage waveforms are at the same frequency, the
synchroscope does not rotate. If the voltage waveforms are at a
different frequency, the synchroscope rotates in proportion to the
frequency difference. The synchroscope needle always points to the
voltage phase angle difference.A synchroscope is a manual device in
that an operator must be watching the "scope" to ensure they close
the circuit breaker at the correct time. The synchroscope is
normally mounted above eye level on a "synch panel". The synch
panel also contains two voltmeters so that the voltage magnitudes
can be simultaneously compared.The synchroscope in Figure 3
reflects a slight voltage magnitude mismatch, and a stationary
synchroscope with a phase angle of approximately 35. The fact that
the synchroscope needle is not rotating indicates frequency is the
same on either side of the circuit breaker.
Figure 3Synchroscope in a Synch Panel1.3.2 Synchro-Check RelaysA
synchro-check or synch-check relay electrically determines if the
difference in voltage magnitude, frequency and phase angle falls
within allowable limits. The allowable limits will vary with the
location on the power system. Typically, the further away from
generation and load, the more phase angle difference can be
tolerated. Synch-check relays typically do not provide indication
of the voltage magnitude, frequency or phase angle. A synch-check
relay decides internally whether its conditions for closing are
satisfied. The synch-check relay will either allow or prevent
closing depending on its settings. A typical synch-check relay may
allow closing if the voltage angle across the breaker is less than
30.1.3.3 Application of Synchronizing EquipmentAt power plants,
synchroscopes are routinely installed to permit manual closing of a
circuit breaker. In addition, synch-check relays can be used to
"supervise" the closing of the circuit breaker and prevent
distracted or inexperienced operator from initiating a bad
close.Modern power plants typically utilize automatic
synchronizers. Automatic synchronizers send pulses to the generator
exciter and governor to change the voltage and frequency of the
unit. The synchronizer will automatically close the breaker when it
is within an allowable window.Substations on the transmission
system have traditionally had synchroscopes installed. However, few
substations are now manned due to the availability of powerful
SCADA systems. Because of this development, newer substations may
or may not have a synch panel, depending on the transmission
company procedures. Since most circuit breaker operations are done
remotely, transmission companies often rely on synch-check relays
to supervise closing of breakers.Figure 4 illustrates a possible
synchronizing system for substation breakers. Note the use of a
synch scope and a synch-check relay. Electrical contacts can be
opened or closed to rearrange the synchronizing system as
desired.
Figure 4Synchronizing System for a Substation Breaker
Operations-Training-SolutionsThe focus of O-T-S is the
development and delivery of training programs for electric power
system operations personnel.
Southwest 2011 OutageThe Dynamics of Disturbances class has been
updated to include a detailed description of the 9/8/2011 Southwest
outage.
NERC Practice Tests
Surge Impedance Loading (SIL)The surge impedance loading or SIL
of a transmission line is the MW loading of a transmission line at
which a natural reactive power balance occurs. The following brief
article will explain the concept of SIL.Transmission lines produce
reactive power (Mvar) due to their natural capacitance. The amount
of Mvar produced is dependent on the transmission line's capacitive
reactance (XC) and the voltage (kV) at which the line is energized.
In equation form the Mvar produced is:
Transmission lines also utilize reactive power to support their
magnetic fields. The magnetic field strength is dependent on the
magnitude of the current flow in the line and the line's natural
inductive reactance (XL). It follows then that the amount of Mvar
used by a transmission line is a function of the current flow and
inductive reactance. In equation form the Mvar used by a
transmission line is:
A transmission line's surge impedance loading or SIL is simply
the MW loading (at a unity power factor) at which the line's Mvar
usage is equal to the line's Mvar production. In equation form we
can state that the SIL occurs when:
If we take the square root of both sides of the above equation
and then substitute in the formulas for XL (=2pfL) and XC (=1/2pfC)
we arrive at:
The term in the above equation is by definition the "surge
impedance. The theoretical significance of the surge impedance is
that if a purely resistive load that is equal to the surge
impedance were connected to the end of a transmission line with no
resistance, a voltage surge introduced to the sending end of the
line would be absorbed completely at the receiving end. The voltage
at the receiving end would have the same magnitude as the sending
end voltage and would have a phase angle that is lagging with
respect to the sending end by an amount equal to the time required
to travel across the line from sending to receiving end. The
concept of a surge impedance is more readily applied to
telecommunication systems than to power systems. However, we can
extend the concept to the power transferred across a transmission
line. The surge impedance loading or SIL (in MW) is equal to the
voltage squared (in kV) divided by the surge impedance (in ohms).
In equation form:
.Note in this formula that the SIL is dependent only on the kV
the line is energized at and the line's surge impedance. The line
length is not a factor in the SIL or surge impedance calculations.
Therefore the SIL is not a measure of a transmission line's power
transfer capability as it does not take into account the line's
length nor does it consider the strength of the local power system.
The value of the SIL to a system operator is realizing that when a
line is loaded above its SIL it acts like a shunt reactor -
absorbing Mvar from the system - and when a line is loaded below
its SIL it acts like a shunt capacitor - supplying Mvar to the
system.Figure 1 is a graphic illustration of the concept of SIL.
This particular line has a SIL of 450 MW. Therefore is the line is
loaded to 450 MW (with no Mvar) flow, the Mvar produced by the line
will exactly balance the Mvar used by the line.
Figure 1Surge Impedance Loading of a Transmission Loading.
Power Plant InfromationFriday, 10 January 2014Circuit Breaker
Logic Circuit in Power plantCircuit Breaker Logic Circuit in Power
Plant
Circuit breakers are geographically distributed in the power
plant to control the power supply to busses or loads in power
plant. So the circuit breakers need to be controlled from different
locations in addition to the circuit breaker board. The circuit
breaker should also operate for different protection according to
their application. These requirements are full filled using control
logic (Relay logic or PLC) for the circuit breaker which will
initiate close or open signals to the circuit breaker. Circuit
breaker is latching device i.e. if it is in a closed position it
will be in that position until unless the open signal is applied to
it. So the breaker consists of one closed coil and trip coil. A
required current flow is needed through the close coil to close the
circuit breaker and cause the breaker to latch the breaker. Once
the breaker is closed the closing coil is de-energized by stopping
the current flow. To trip (open) the circuit breaker, a flow of
current is required through the trip coil. The plunger operated by
the trip coil releases the latch and rapidly opens the breaker.
Once the breaker is open, the trip coil is de-energized.
The logic circuit controls the flow of current to the closed
coil and trip coil according to the logic conditions. Thus the
logic has two paths 1) closed circuit path and 2) trip (open)
circuit path.
Closed Circuit path
This path controls the flow of current to the closed coil
according to the logic switches placed in the path. The figure
shows the closed circuit path for energizing the 52 C close coil.
The path consists of the following parts
Fuse part
A separate fuse is provided in closed path to ensure that if the
fuse in closed circuit blows the breaker still has the tripping
supply to open the breaker.
Breaker closing logic part
This contains the actual logic from the remote or local close of
the circuit breaker. When the Push button from local or remote
logic close is activated then it allows the current to flow through
closing auxiliary relay (52 X). The auxiliary relay energizes main
close coil 52 C. The reason for placing auxiliary relay is that for
energizing the 52 C coil, it requires large current which the
control circuit cannot tolerate.
Circuit Breaker closing mechanism
By energizing the 52C coil it activates the breaker closing
mechanism. Once the breaker closes the Lb contact which is
mechanically with the circuit breaker closing mechanism opens the
contacts and supply to 52 X auxiliary relay to de-energize the 52C
coil. This is to ensure that the absence of 52C close coil supply
during tripping of circuit breaker.
Tripping circuit path
The tripping circuit path is separately fused with isolation
from the closing circuit to ensure the reliability of tripping
circuit. The tripping circuit has also three parts as same as
closed circuit.
When the breaker is closed the LB contact in tripping circuit
closed which is in series with trip logic circuit. In tripping
logic in-addition to opening logic from remote and local, it also
consists of protection logic. The protection logic activates the
contact for the specified protections like over current, earth
fault depending on the application. Once the any of the contact
closes then the current flow will energizes the 52 T coil same as
the closing coil. The tripping energizing operates the plunger and
opens the circuit breaker rapidly. Posted byRaju Sat03:11Email
ThisBlogThis!Share to TwitterShare to FacebookShare to Pinterest1
comment:1.
noddy dane25 March 2014 at 02:24Valuable information and
excellent design you got here! for more details something like
visit circuit breaker types get more informations.ReplyDeleteAdd
commentLoad more...Older PostHomeSubscribe to:Post Comments
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Power Plant InfromationSunday, 11 August 2013What is
synchronization and effects of poor synchronization in power
plant
Synchronization of Turbo Alternator or an AC generator is the
process of connecting the generator with grid power supply which is
an interconnection of large pool of generators and power
consumption loads. Simply the grid is parallel operation of some
number generators with same frequency. So to connect the Generator
in power plant in this pool of parallel running generators, The
incoming generator parameters like frequency, phase angle and
voltage should be matching with the existing grid frequency.
Before going detail description first let us understand what is
the need of synchronization of generator. Generator is connected
with the prime mover which provides the rotating magnetic field and
hence this rotating magnetic field will induces the voltage in the
stationary part. The frequency and phase angle of the voltage
signal is controlled by the prime mover speed and magnitude of the
voltage signal is controlled by the generator excitation.
To understand the phenomenon let us correlate the entire
operation with the person wants to catch a running travel bus.
Consider the travel bus is grid power supply and the person is
incoming generator. Now if the person wants to get in to the bus
then he should equally or little faster than the bus same the
generator tries connect to the grid should run equally or little
faster than the grid. Here the speed is measured with the frequency
because speed is proportional to the frequency( 50 Hz, 60 Hz). The
person is now running with the same speed of the bus but the bus
door is one end of the bus and he is at another end of the bus so
he needs to match with the door to get in to the bus. Like the same
if the generator is running at the same frequency of grid it cannot
be synchronized until unless the phase of the two voltages
matches.
Effects of poor synchronization: Prime mover damages if the
speed and rotor angle is not matches with grid voltage frequency
and phase angle due to rapid acceleration or deceleration. Let us
suppose generator has to connected to the grid frequency of 60 Hz.
But the breaker has closed with poor synchronization at the
generator frequency of 58Hz (i.e for two pole generator speed is
3480 out of 3600 rated), now once the breaker closes the generator
is connected in the pool of parallel generators which forces the
incoming generator to rotate at the same grid frequency. Due to
this sudden acceleration of the rotor from 3480 to 3600 rpm and a
sudden break at 3600 rpm damages the rotor mass. Same way in the
reverse when the generator is running higher frequency than the
grid frequency. A large currents may suddenly flow through the
Generator windings and Generator transformer windings due to poor
synchronizations which damages the windings. There will be power
and voltage oscillations because of this sudden acceleration and
deceleration of the rotor. It may leads to activation of the
generator protective relays which causes the major interruption so
the process should be started once again after clearing the
protection. Posted byRaju Sat03:28Email ThisBlogThis!Share to
TwitterShare to FacebookShare to Pinterest1 comment:1.
Deepraj Singh16 February 2014 at 01:42thankyou very much, i like
your way of explanation.DeeprajReplyDeleteAdd commentLoad
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Anonymous PosterGenerator Circuit Breaker 02/27/2009 7:06 AM
for one of our project we are using generator circuit breaker
(GCB) instead of station transformer. GCB is inbetween Gen. Trf and
Generator. So power (generator trf) trfr is back charged and feeds
the Unit aux. tr at starting. Once the load picksup, GCB is opened
and generator feed the UAT.At this stage, whether power flow will
be in back to the genertor?what is the recative implication on
genertor with this procedure?
Reply
Top of Form
Bottom of FormInterested in this topic? By joining CR4 you can
"subscribe" tothis discussion and receive notification when new
comments are added. Join CR4, The Engineer's Place for News and
Discussion!V.Ambarani.Associate
Join Date: Nov 2007Location: IndiaPosts: 41Good Answers: 3#1Re:
generator transformer (power transformer) 02/27/2009 8:38 AM
Dear Sir,Please note that in this case GCB is being used as
synchronisation breaker to synchronise external power source (say
Switchyard bus) and the generator connected to bus through
GSU-Generator step of up transformer.Hence GCB will be closed
during synchronisation and not opened as stated.Further
synchronisation will take place when unit-Generator is connected to
external source.Till that time UAT will be fed from external
source.Once synchronisation takesplace external source and
generator get locked and Generatorwill feed UAT. No back power will
flow.The reactive power willbe as per generator excitation
control.V.Ambarani=====================================================================__________________Best
Regards
Reply
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