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10 April 2020

Synchronization Check in AC systems

Introduction: In AC power system synchronization check is used when we are connecting two different systems. Two points are worth mentioning in this case:
  1. The connection is always made through circuit breaker (CB)
  2. We are not sure both the systems being connected through CB are different or same.
Therefore, synchronization check is used when closing circuit breaker to ensure we do not interconnect out of synchronism systems.

Implementation: There may be four cases when closing CB:
  1.  Dead line Dead Bus
  2.  Dead Line Live Bus
  3.  Live Line Dead Bus
  4.  Live Line Live Bus
In the first three cases, there is voltage only one side of CB, there no option of synchronization check. Therefore, CB is to be closed without any check. For radial feeders synchnization check is not used because we always close for Dead Line Live bus cases. In fourth case both side voltage is available. We have to check synchronization before closing the CB.

Parameters to be checked: For interconnecting two systems, we have to ensure the following three parameters are within limits: 

1. Phase angle differenceIt will lead to active power flow after CB closing. If it is more (typical value  +30 deg), large current will flow depending on system impedance. This may lead to damage to equipment or grid (or infinite bus). As shown in image below phase angle difference is δ. (Blue line is Bus voltage Green is Feeder voltage, Red is difference between Bus and Feeder voltage)


2. Voltage difference - It will lead to reactive power flow after CB closing. If it is more (typical value  +10%), large current will flow depending on system impedance. This may lead to damage to equipment or grid (or infinite bus). As shown in image below voltage difference is V1 - V2 after taking r.m.s. value (Blue line is Bus voltage Green is Feeder voltage, Red is difference between Bus and Feeder voltage)


3. Frequence differenceIn interconnected AC system all synchronus machines (Mostly generators) run at same frequency. All the machines have thier rotors magnetically locked with stator field which is rotating at grid frequency. If there are two different networks at different frequency, they have to run at same frequency after interconnection, otherwise interconnection will not work. Normally synchronization check is done that incoming feeder frequency is with permissible range typical value for frequency difference is +0.2% to +0.5 %. If any generator is rotating at higher or lower speed (prior to connection to grid), which means it has different frequency, is connected to grid, it will feel mechniacal shock upon CB close. Because if it is running slow (i.e. lower frequency), after CB close it has to run faster to match grid. But its prime mover input is low. It will start to run as motor, taking power from grid. In other case if it is running faster (i.e. higher frequency), after CB close it has to run slower. Due to more input to prime mover it will give more power than anticipated. As shown in image below frequency difference is f1 - f2.


In addition when first time interconnecting two systems, phase sequence is also to be checked. Subsequently, it is not required to be checked because phase sequence can not change without physical change in connections. As shown in image below both bus and incomer voltages have sequence R - Y - B.




In the image shown below, let us assume we are connecting generator-1 to Bus bar by closing CB-1. Before closing we have to check synchronization by comparing any one phse voltage (Normally R-phase) of Bus VT to Feeder-1 VT. We do not compare voltage of all phases, becuase phase sequence for both sides have been already been matched during first time charging. 

Synchronization check is more significant at generating stations when connecting any generator to grid. During synchronization operator is also having control of generator i.e. he can control frequency / voltage of the generator. 


Synchronization check is used at substations also before closing any CB, so that two different systems are not interconnected without checking synchronization. As shown in image below Before closing feeder CB at Station-B Synchronisation is is required.



In substation already connected through alternate route, frequency will be same on both sides of CB, but phase angle and voltage needs to be check by synchronization check. As shown below, Station-A and Station-B are alraedy connected through Station-C, But before closing feeder CB at Station-B, voiltage difference and phase angle difference needs to be checked.





06 April 2020

Calculation of relay settings for transmission lines - Distance protection


Introduction: Electricity is transferred on higher voltage for long distances. Transmission lines pass through forests, hills, fields etc befor reaching destination. Being exposed to uncontrolled atmosphere, faults on transmission lines are as high as 85% of the total faults in power system. These lines are protected by distance relays working on impedance function. Now with the advancement in optical fibre technology, line differential relays are also being used. Line differential relays are also having distance protection function which comes in to action whenever there is optical communication failure. In addition to protection these relays also work as fault locator which is also based on impedance measrement principle.

Line Parameters: Transmission line is a long conductor having resistance, inductance and capacitance distributed uniformly throughout the length. Following line constants are provided by designer based on calculations, which are used for relay settings:


Sr Parameter Unit
1 Positive sequence reactance  X1 ohm/km
2 Positive sequence resistance  R1 ohm/km
3 Zero sequence reactance  X0  ohm/km
4 Zero sequence resistance  R0  ohm/km

Conversion to Secondary value from Primary value: Above parameters are given for primary equipment. The protection relays are connected to primary equipment through Current transformer and Voltage transformer (CT and VT). Relay reads the current and voltage on secondary side of CT and VT. Therefore the parameters needs to be converted to secondary side as per CT and VT ratio.

Z secondary = Z primary x (CT Ratio / VT Ratio)

Setting calculation: We will drive settings for Station-A end relay of a 220kV line to station-B. Actual relay setting calculation will depend on many factors like relay make and model, network size etc. Here we are showing a simple example to get an idea of basics for relay setting calculation. 



VT ratio: 220kV/110V 
CT ratio: 800/1A

Primary side line parameters are:
X1 : 0.398 ohm/km
R1 : 0.069 ohm/km
X0 : 1.290 ohm/km
R0 : 0.281 ohm/km
Line length LL: 100 km
Next Longest line: 80 km



CT Ratio: 800/1 = 800
VT Ratio: 220kV/110V = 2000 
As shown in Fig-2:
Positive sequence impedance Z1 = Sqrt (R1^2 + X1^2) = 0.404 ohm/km
Line Angle = ArcTan (X1/R1) = 80.16 deg
Zero sequence impedance Z0 = Sqrt (R0^2 + X0^2) = 1.320 ohm/km

Line Angle = ArcTan (X0/R0) = 77.71 deg
Total line positive sequence impedance ZL = LL x Z1 = 40.4 ohm


Zone settings are shown in Fig-3 for a four zone protection relay. Zone-1, 2 & 3 are in forward direction and Zone-4 is in reverse direction. Typical zone settings are as below:

Zone-1: 80% of protected line = 40.04 x 0.8 = 32.320 ohm
Zone-2: 120% of protected line = 40.04 x 1.2 = 48.048 ohm
Zone-3: 100% of protected line + 120% of next longest line = 40.04 + (1.2 x 80 x 0.404) =  78.824 ohm
Zone-4: 10% of protected line = 40.04 x 0.1 = 4.04 ohm

Relay setting to be entered in relay (Secondary values):
Zone-1: Primary value x CTP/PTR = 32.320 x 800/2000 = 12.928 ohm
Zone-2: Primary value x CTP/PTR = 48.048 x 800/2000 = 19.219 ohm
Zone-3: Primary value x CTP/PTR = 78.824 x 800/2000 = 31.596 ohm
Zone-4: Primary value x CTP/PTR = 4.040 x 800/2000 = 1.616 ohm

Neutral compensation factor KZN = (Z0-Z1) / 3Z1 = 0.757
KZN Angle = ArcTan [(X0-X1)/(R0-R1)] - ArcTan (X1-R1) = -3.5 deg

Typical time settings for Zone is given below, however these are co-ordinated with relay settings of other elements of the network:

Zone-1 time delay: 0.0 sec
Zone-2 time delay: 0.5 sec
Zone-3 time delay: 1.0 sec
Zone-4 time delay: 0.5 sec