Power System Protection
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Transcript of Power System Protection
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Power System Protection 1
Power System Protection
Protection of power system deals with:
Protection against short-circuit faults
Causes of over-voltages
Insulation to withstand faults
Surge arresters and insulation coordination
Basic components of protection systems are:
Instrument transformers (voltage transformer and
current transformer)
Protective relays
Circuit breakers
Instrument Transformers
There are two basic types of instrument transformers: voltage transformers (VTs), formerly called potential transformers (PTs),
and current transformers (CTs). The transformer primary is connected to or into the power system and is insulated for the power
system voltage. The VT reduces the primary voltage and the CT reduces the primary current to much lower, standardized levels
suitable for operation of relays. Advantages associated with reduction of primary voltage and current values are:
Safety: Instrument transformers provide electrical isolation from the power system so that personnel working with relays
will work in a safer environment.
Economy: Lower-level relay inputs enable relays to be smaller, simpler, and less expensive.
Current Transformer (CT)
The primary winding of a current transformer usually consists of a single turn, obtained by
running the power systems primary conductor through the CT core. The secondary
generally has a large number of turns and produces a much smaller current, primary current
divided by the turn-ratio. Ideally, the CT secondary is connected to a current-sensing device
with zero impedance, such that the entire CT secondary current flows through the sensing
device.
Voltage Transformer (VT)
There are basically, two types of voltage transformers
used for protection equipment.
1. Electromagnetic type
2. Capacitor type (referred to as a CVT).
The electromagnetic transformers are used in voltage
circuits upto 110/132 kV. The capacitor VT is more
commonly used on extra high-voltage (EHV) networks.
Here the primary portion consists of capacitors
connected in series to split the primary voltage to
convenient values. Here the output voltage is isolated
through a transformer for safety purposes. Ideally, the
secondary of voltage transformers is connected to a voltage-sensing device with infinite impedance, such that the entire VT
secondary voltage is across the sensing device.
Fig. 0: Current transformer
Fig. 0: Equipment of protection system
Fig. 0: a) Electromagnetic type VT, b) Capacitor type VT (CVT)
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Power System Protection 2
Protective Relays
Protective relays are intelligent electronic devices which receive measured signals from the secondary side of CTs and VTs and
detect whether the protected unit is in a stressed condition or not. A trip signal is sent by protective relays to the circuit breakers
to disconnect the faulty components from power system if necessary. It is important that relays operate, when they should, in order
to protect power system but it is equally important that they dont operate falsely in order to avoid causing unnecessary power
disturbances.
Differential Relays
Differential relays are commonly used to protect generators,
buses, and transformers against internal faults. As the name
implies, these relays compare currents entering and leaving the
protected zone and operate when the differential current between
these currents exceed a pre-determined level. The basic method
of differential relaying for generator protection is illustrated in
the figure. The protection of only one phase is shown. The
method is repeated for the other two phases. When the relay in
any one phase operates, all three phases of the main circuit
breaker will open, as well as the generator neutral and field
breakers (not shown).
For the case of no internal fault within the generator windings, 1 = 2, and assuming identical CTs, 1 = 2
. For this case the
current in the relay operating coil is zero, and the relay does not operate. On the other hand, for an internal fault such as a phase-
to-ground or phase-to-phase short within the generator winding, 1 2, and 1 2
. Therefore, a difference current 1 2
flows
in the relay operating coil, which may cause the relay to operate.
Overcurrent Relays
In these relays, if the current being measured exceeds a minimum value, the relay
determines that a fault has occurred, giving a trip command to the circuit breaker
to operate. Instantaneous overcurrent relays respond to the magnitude of their
input current, CT secondary current , as shown by the trip and block regions in the figure. If the current magnitude || exceeds a specified adjustable current magnitude , called the pickup current, then the relay contacts close
instantaneously to energize the circuit breaker trip coil. If is less than the pickup current , then the relay contacts remain open, blocking the trip coil.
Generally, such relays operate on a delay time basis where this delay time is a
nonlinear function of the magnitude of the fault current i.e. larger the current magnitude, shorter the delay time. If is a large multiple of the pickup current , then the relay operates (or trips) after a small time delay. For smaller multiples of pickup, the
relay trips after a longer time delay. And if < , the relay remains in the blocking position.
Directional Overcurrent Relays
The protection offered by this relay is for faults only in one direction. For
example, in the figure, if the fault occurs right of its CT location, the
current I sensed by this relay would be lagging with respect to the voltage
at this location, causing the relay to trip the circuit breaker. Whereas for
the fault left of its CT location, the current would be leading and the relay
would be blocked from tripping the circuit breaker.
Fig. 0: Differential relaying for one phase of generator protection
Fig. 0: Instantaneous overcurrent relay block and
trip regions
Fig. 0: Directional overcurrent relay
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Power System Protection 3
Impedance (Distance) Relays
A distance relay, as its name implies, has the ability to detect a fault within a pre-set distance
along a transmission line or power cable from its location. Every power line has a resistance
and reactive per kilometer related to its design and construction so its total impedance will be
a function of its length or distance. A distance relay therefore looks at current and voltage and
responds to a voltage-to-current ratio. During a three-phase fault, current increases while bus
voltages close to the fault decrease. If, for example, current increases by a factor of 5 while
voltage decreases by a factor of 2, then the voltage-to-current ratio decreases by a factor of
10. That is, the voltage-to-current ratio is more sensitive to faults than current alone. A relay
that operates on the basis of voltage-to-current ratio is also called an impedance relay.
If the relays operating boundary is plotted, on an R/X diagram, its impedance characteristic
is a circle with its center at the origin of the coordinates and its radius will be the setting (reach) in ohms. The relay will operate
for all values less than its setting i.e. is for all points within the circle. This is known as a plain impedance relay and it will be
noted that it is non-directional, in that it can operate for faults behind the relaying point.
Pilot Relaying
Pilot relaying refers to a type of differential protection that compares the quantities at the terminals via a communication channel
rather than by a direct wire interconnection of the relays. Differential relaying of transmission lines requires pilot relaying because
the terminals are widely separated. Four types of communication channels are used for pilot relaying:
1. Pilot wires: Separate electrical circuits operating at dc, 50 to 60 Hz, or audio frequencies.
2. Power-line carrier: The transmission line itself is used as the communication circuit, with frequencies between 30 and
300 kHz being transmitted.
3. Microwave: A 2 to 12 GHz signal transmitted by line-of-sight paths between terminals using dish antennas.
4. Fiber optic cable: Signals transmitted by light modulation through electrically non-conducting cable.
Zones of Protection
To realize complete selectivity of protection, the power system is divided into discrete zones. Each zone encompasses one or more
power system equipment, and adjacent zones are overlapping so that no part of the power system is left unprotected.
In the figure, the first zone for the relay at A encompasses for
example 90% of the line. The remaining 10% is protected by
the relay at B. If the fault occurs in As first zone, the relay acts
instantly without any time delay. The second zone for the relay
at A encompasses for example 120% of the line, thus
overreaching in the next section. If the fault occurs in the
second zone assigned to it, it operates with a time delay of a
few hundred msec, thus allowing it to coordinate with the relay
that is its first zone. The adjacent zone consisting of line CD is
the third zone for the relay A for which it provides backup protection with a further time delay of 1 to 3 seconds.
Fig. 0: Impedance characteristic of a
distance relay
Fig. 0: Zones of protection