power system protection
DESCRIPTION
Presentation to understand the concepts of power system protection.TRANSCRIPT
Unit 1Power System Protection
Generation-typically at 4-20kV
Transmission-typically at 230-765kV
Subtransmission-typically at 69-161kV
Receives power from transmission system and transforms into subtransmission level
Receives power from subtransmission system and transforms into primary feeder voltage
Distribution network-typically 2.4-69kV
Low voltage (service)-typically 120-600V
TypicalBulkPower System
2GE Consumer & Industrial
Multilin
Objective of Power System Protection
Why power system protection?
Protection Zones
4GE Consumer & IndustrialMultilin
1. Generator or Generator-Transformer Units2. Transformers3. Buses4. Lines (transmission and distribution)5. Utilization equipment (motors, static loads, etc.)6. Capacitor or reactor (when separately protected)
Unit Generator-Tx zoneBus zone
Line zoneBus zone
Transformer zone Transformer zone
Bus zone
Generator
~XFMR Bus Line Bus XFMR Bus Motor
Motor zone
Application Principles
5
Protection zones
Generator
Xfmr Bus
Line
Bus
Application Principles
6
Protection zones – determined by CT location
Generator
Xfmr Bus
Line
Bus
Application Principles
7
Protection zones – determined by CT location
Generator
Xfmr Bus
Line
Bus
Transformer Zone
Application Principles
8
Protection zones – determined by CT location
Generator
Xfmr Bus
Line
Bus
Transformer zoneUnit generator-transformer
zone
Application Principles
9
Protection zones – determined by CT location
Generator
Xfmr Bus
Line
Bus
Transformer zoneUnit generator-transformer
zone
Bus zone
Application Principles
10
Protection zones – determined by CT location
Generator
Xfmr Bus
Line
Bus
Transformer zoneUnit generator-transformer
zone
Bus zone
Line zone
Application Principles
11
Protection zones – determined by CT location
Generator
Xfmr Bus
Line
Bus
Transformer zoneUnit generator-transformer
zone
Bus zone
Line zone
Bus zone
Application Principles
12
Protection zones – determined by CT location
Generator
Xfmr Bus
Line
Bus
Transformer zoneUnit generator-transformer
zone
Bus zone
Line zone
Bus zone
Line zone
Application Principles
13
Protection zones – determined by CT location
Generator
Xfmr Bus
Line
Bus
Transformer zoneUnit generator-transformer
zone
Bus zone
Line zone
Bus zone
Line zone
Note the overlap, so that there is no location where a fault would go undetected
Application Principles
14
Protection zones
MotorXfmr Bus
Line
Bus
Application Principles
15
Protection zones – determined by CT location
MotorXfmr Bus
Line
Bus
Application Principles
16
Protection zones – determined by CT location
MotorXfmr Bus
Line
Bus
Line zone
Application Principles
17
Protection zones – determined by CT location
MotorXfmr Bus
Line
Bus
Line zone
Bus zone
Application Principles
18
Protection zones – determined by CT location
MotorXfmr Bus
Line
Bus
Line zone
Bus zone
Xfmr zone
Application Principles
19
Protection zones – determined by CT location
MotorXfmr Bus
Line
Bus
Line zone
Bus zone
Xfmr zone
Bus zone
Application Principles
20
Protection zones – determined by CT location
MotorXfmr Bus
Line
Bus
Line zone
Bus zone
Xfmr zone
Bus zone
Motor zone
Application Principles
21
Protection zones – determined by CT location
MotorXfmr Bus
Line
Bus
Line zone
Bus zone
Xfmr zone
Bus zone
Motor zone
Again, note the overlapAlso note: A fault on a major element is covered by how many zones? A fault within a circuit breaker is covered by how many zones?
Zone Overlap
22GE Consumer & IndustrialMultilin
1. Overlap is accomplished by the locations of CTs, the key source for protective relays.
2. In some cases a fault might involve a CT or a circuit breaker itself, which means it can not be cleared until adjacent breakers (local or remote) are opened.Zone A Zone B
Relay Zone A
Relay Zone B
CTs are located at both sides of CB-fault between CTs is cleared from both remote sides
Zone A Zone B
Relay Zone A
Relay Zone B
CTs are located at one side of CB-fault between CTs is sensed by both relays, remote right side operate only.
Factors affecting power system protection
Selectivity= isolate only the faulty network and maintain the normal supply
Reliability = operate properly during the period of service
Speed= quick disconnectionDiscrimination = between fault and loading
conditionsSimplicity= simple and straight forwardSenstivity= operate correctly within its
zoneEconomics= max protection+ min cost
Art & Science of Protection
24GE Consumer & IndustrialMultilin
Selection of protective relays requires compromises:• Maximum and Reliable protection at minimum
equipment cost• High Sensitivity to faults and insensitivity to
maximum load currents• High-speed fault clearance with correct selectivity• Selectivity in isolating small faulty area• Ability to operate correctly under all predictable
power system conditions
Art & Science of Protection
25GE Consumer & IndustrialMultilin
• Cost of protective relays should be balanced against risks involved if protection is not sufficient and not enough redundancy.
• Primary objectives is to have faulted zone’s primary protection operate first, but if there are protective relays failures, some form of backup protection is provided.
• Backup protection is local (if local primary protection fails to clear fault) and remote (if remote protection fails to operate to clear fault)
Primary Equipment & Components
26GE Consumer & IndustrialMultilin
• Transformers - to step up or step down voltage level • Breakers - to energize equipment and interrupt fault
current to isolate faulted equipment• Insulators - to insulate equipment from ground and
other phases• Isolators (switches) - to create a visible and
permanent isolation of primary equipment for maintenance purposes and route power flow over certain buses.
• Bus - to allow multiple connections (feeders) to the same source of power (transformer).
Per unit and percent valuesRatio of actual to base values is per unit
values.Convert from per cent to per unit values by
dividing 100.
But why per unit values?
Advantages of per unit representation1. Ordinary parameters vary considerably with
variation of physical size, terminal voltage and power rating etc. while per unit parameters are independent of these quantities over a wide range of the same type of apparatus
2. It provide more meaningful information.3. The chance of confusion between line and
phase values in a three-phase balanced system is reduced.
4. Impedances of machines are specified by the manufacturer in terms of per unit values.
5. The per unit impedance referred to either side of a single-phase transformer is the same.
6. The per unit impedance referred to either side of a three -phase transformer is the same regardless of the connection whether they are ∆-∆, Y-Y or ∆-Y.
7. The computation effort in power system is very much reduced with the use of per unit quantities.
8. Usually, the per unit quantities being of the order of unity or less can easily be handled with a digital computer. Manual calculation are also simplified.
Advantages of per unit representation
Per Unit CalculationsA key problem in analyzing power systems is
the large number of transformers. – It would be very difficult to continually have to
refer impedances to the different sides of the transformers
This problem is avoided by a normalization of all variables.
This normalization is known as per unit analysis.
actual quantityquantity in per unit base value of quantity
30
Per Unit Conversion Procedure, 1f1. Pick a 1f VA base for the entire system, SB
2. Pick a voltage base for each different voltage level, VB. Voltage bases are related by transformer turns ratios. Voltages are line to neutral.
3. Calculate the impedance base, ZB= (VB)2/SB
4. Calculate the current base, IB = VB/ZB 5. Convert actual values to per unit
Note, per unit conversion affects magnitudes, not the angles. Also, per unit quantities no longer have units (i.e., a voltage is 1.0 p.u., not 1 p.u. volts)
31
Per Unit Solution Procedure1. Convert to per unit (p.u.) (many problems
are already in per unit)2. Solve3. Convert back to actual as necessary
32
Three Phase Per Unit
1. Pick a 3f VA base for the entire system, 2. Pick a voltage base for each different
voltage level, VB,LL. Voltages are line to line. 3. Calculate the impedance base
Procedure is very similar to 1f except we use a 3f VA base, and use line to line voltage bases
3BSf
2 2 2, , ,3 1 1
( 3 )3
B LL B LN B LNB
B B B
V V VZ
S S Sf f f
Exactly the same impedance bases as with single phase using the corresponding single phase VA base and voltage base!33
Three Phase Per Unit, cont'd4. Calculate the current base, IB
5. Convert actual values to per unit
3 1 13 1B B
, , ,
33 3 3B B B
B LL B LN B LN
S S SI IV V V
f f ff f
Exactly the same current bases as with single phase!
34
Example 1A 5 KVA 400/200 V, 50Hz, single phase transformer
has the primary and secondary leakage reactance each of 2.5 ohm. Determine the total reactance in per unit.
Sb= 5000 VAPrimary Base Voltage Vb1 = 400 VSecondary Base Voltage Vb2 = 200 V
X1e=X1+a2X2
a=N1/N2=400/200=2X1e=X1+a2X2=2.5 + 2.5 * 22 =12.5 ohm
Xpu= (Xactual/Zbase)Zb1= (V2
b1/Sb)=4002/5000=32 ohm Xpu= (Xactual/Zbase)= 12.5/32 = 0.390625
pu………………..1
X1pu = X1/Zb1X2pu = X2/Zb2Zb2 = (V2
b2/Sb)= 2002/5000=8 ohmX2pu = X2/Zb2 = 2.5/8 = 0.3125X1pu = X1/Zb1 = 3.5/32 = 0.078125Xpu= X1pu + X2pu = 0.390625……………………………..2
Both 1 and 2 matches which confirm that pu impedances are same on both sides of a transformer
Symmetrical Components
Symmetrical components
In a three-phase Y-connected system, the neutral current is the sum of the line currents:
Three phase fault
Single line to ground fault
V=Vf – IZ
Line to line fault
Double line to ground fault
sudden testA 7 KVA 1000/250 V, 50Hz, single phase transformer has the primary and secondary leakage reactance each of 5 ohm. Determine the total reactance in per unit.
50
A phasor is a representation of a sinusoidal voltage or current as a vector rotating about the origin of the complex plane.
AC Power and Phasors
phasors
Advantages of Phasors
Less Cumbersome (short hand notation)
Simpler Calculations (complex arithmetic, calculators can do), generally less need for integration and differentiation
Additional insights may be obtained about relations between currents, voltages, and power
Limitations
Applies only to sinusoidal steady-state systems
Power Calculated using phasors is only the time average
52GE Consumer & IndustrialMultilin
• Current transformers are used to step primary system currents to values usable by relays, meters, SCADA, transducers, etc.
• CT ratios are expressed as primary to secondary; 2000:5, 1200:5, 600:5, 300:5
• A 2000:5 CT has a “CTR” of 400
Current Transformers
Current into the Dot, Out of the DotCurrent out of the dot, in to the dot
53GE Consumer & IndustrialMultilin
Forward Power
I P
I S
I R
Relayor Meter
Forward Power
I P
I S
I R
Relayor Meter
54GE Consumer & IndustrialMultilin
VP
VS
Relay
• Voltage (potential) transformers are used to isolate and step down and accurately reproduce the scaled voltage for the protective device or relay
• VT ratios are typically expressed as primary to secondary; 14400:120, 7200:120
• A 4160:120 VT has a “VTR” of 34.66
Voltage Transformers
Typical CT/VT Circuits
55GE Consumer & IndustrialMultilin
Courtesy of Blackburn, Protective Relay: Principles and Applications
CT/VT Circuit vs. Casing Ground
Case ground made at IT locationSecondary circuit ground made at first
point of use 56GE Consumer & Industrial
Multilin
Case
Secondary Circuit