Siemens 7PG2114 Application Manual
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7PG2113/4/5/6
Feeder Protection
Document Release History
This document is issue 2010/08. The list of revisions up to and including this issue is:
2010/08
Software Revision History
2009/04
2436H80003R1g-1c 7PG2113/5
2436H80004R1g-1c 7PG2114/6
The copyright and other intellectual property rights in this document, and in any model or article produced from it
(and including any registered or unregistered design rights) are the property of Siemens Protection Devices
Limited. No part of this document shall be reproduced or modified or stored in another form, in any data retrieval
system, without the permission of Siemens Protection Devices Limited, nor shall any model or article be
reproduced from this document unless Siemens Protection Devices Limited consent.
While the information and guidance given in this document is believed to be correct, no liability shall be accepted
for any loss or damage caused by any error or omission, whether such error or omission is the result of
negligence or any other cause. Any and all such liability is disclaimed.
©2010 Siemens Protection Devices Limited
7PG2113/4/5/6 Solkor Applications Guide
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Table of Contents
Related Manuals for Siemens 7PG2114
Summary of Contents for Siemens 7PG2114
- Page 1 Limited. No part of this document shall be reproduced or modified or stored in another form, in any data retrieval system, without the permission of Siemens Protection Devices Limited, nor shall any model or article be reproduced from this document unless Siemens Protection Devices Limited consent.
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Page 2: Table Of Contents
Settings Guidelines ......................... 42 6.2 Current Transformer Supervision ......................44 6.3 Voltage Transformer Supervision (60VTS) ................... 45 6.4 Trip/Close Circuit Supervision (74T/CCS)..................... 46 6.4.1 Trip Circuit Supervision Connections ..................46 ©2010 Siemens Protection Devices Limited Chapter 7 Page 2 of 49... - Page 3 Table 6-2 Determination of VT Failure (1 or 2 Phases) ................... 45 Table 6-3 Determination of VT Failure (3 Phases) ..................45 Table 6-4 Magnetic Inrush Bias ........................48 ©2010 Siemens Protection Devices Limited Chapter 7 Page 3 of 49...
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Page 4: Section 1: Pilot Wire Current Differential Scheme
Section 1: Pilot Wire Current Differential Scheme 1.1 General The 7PG2113 and 7PG2114 relays provide both pilot wire current differential protection and overcurrent and earth fault protection as well as other additional functions. The 7PG2115 and 7PG2116 additionally provide directional functionality for the overcurrent and earth fault protection. -
Page 5: Equipment Options
15kV B75 relay, 1 per circuit B74 relay, 1 per circuit Note: Although the 5kV scheme utilises a combined B75/B74 unit, the additional isolation requirements at 15kV necessitate that separate units must be used. ©2010 Siemens Protection Devices Limited Chapter 7 Page 5 of 49... -
Page 6: 1.4 Application Diagrams
Figure 1.4-1 Installation with Existing Solkor R, Rf or R/Rf relay. Figure 1.4-2 Standard 5kV Solkor R/Rf with Guard. Figure 1.4-3 Installation with existing 15kV Plain Solkor Rf with Guard. ©2010 Siemens Protection Devices Limited Chapter 7 Page 6 of 49... -
Page 7: Figure 1.4-4 5Kv Solkor Rf With Pilot Supervision
7PG2113/4/5/6 Solkor Applications Guide Figure 1.4-4 5kV Solkor Rf with Pilot Supervision. Figure 1.4-5 15kV Solkor Rf with Pilot Supervision. ©2010 Siemens Protection Devices Limited Chapter 7 Page 7 of 49... -
Page 8: Essential External Wiring And Settings
Guard but high enough to operate the differential protection. Time delay settings can be applied to avoid nuisance indications. Figure 1.5-1 Interconnection Wiring ©2010 Siemens Protection Devices Limited Chapter 7 Page 8 of 49... -
Page 9: Description Of Typical Setting File
This gives an alarm that the Solkor has tripped without the Guard E1 (=87L without This could indicate pilot open circuit Guard) (note that a fault occurs below the Guard setting but above the Rf setting will create an alarm) ©2010 Siemens Protection Devices Limited Chapter 7 Page 9 of 49... - Page 10 Operated by Backup EF & Guard EF, Self reset to match A,B&C indications Guard Override (Yellow) Self reset, follows binary input Backup inhibited (Yellow) Self reset, follows binary input ©2010 Siemens Protection Devices Limited Chapter 7 Page 10 of 49...
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Page 11: Application Considerations
It is also apparent that the effects are not easily analysed or modelled and thus in- service experience is the most reliable basis in deciding which types of pilot will be satisfactory. ©2010 Siemens Protection Devices Limited Chapter 7 Page 11 of 49... -
Page 12: Pilot Supervision
Injection Intertripping is generally difficult to apply successfully in conjunction with Overcurrent Guard relays since the remote Guard relay will block operations resulting from intertrip injection if the remote end CT current is below the Guard setting. ©2010 Siemens Protection Devices Limited Chapter 7 Page 12 of 49... -
Page 13: Capacitive Charging Currents
CTs will fail to cancel if the CTs are mismatched or if saturation occurs to different extents. This current may be higher than the through fault level upon which the CTs are usually sized ©2010 Siemens Protection Devices Limited Chapter 7 Page 13 of 49... -
Page 14: Section 2: Additional Functions
2 to reflect new load and fault currents RADIAL SUBSTATION Non-essential loads Figure 2.1-1 Example Use of Alternative Settings Groups The Current Differential protection has fixed settings which cannot be adjusted by settings groups. ©2010 Siemens Protection Devices Limited Chapter 7 Page 14 of 49... -
Page 15: Binary Inputs
LED indication and also have a parallel connection wired to directly trip the circuit via a blocking diode, see fig. 1.2-1: Figure 2.2-1 Example of Transformer Alarm and Trip Wiring ©2010 Siemens Protection Devices Limited Chapter 7 Page 15 of 49... -
Page 16: The Effects Of Capacitance Current
1.2-2. 2.2.3 AC Rejection The default pick-up time delay of 20ms provides immunity to ac current e.g. induced from cross site wiring. ©2010 Siemens Protection Devices Limited Chapter 7 Page 16 of 49... -
Page 17: Figure 2.2-2 Binary Input Configurations Providing Compliance With Eats 48-4 Classes Esi 1 And
7PG2113/4/5/6 Solkor Applications Guide Figure 2.2-2 Binary Input Configurations Providing Compliance with EATS 48-4 Classes ESI 1 and ESI 2 ©2010 Siemens Protection Devices Limited Chapter 7 Page 17 of 49... -
Page 18: Binary Outputs
LEDs are used to display features which routinely change state, such as Circuit-Breaker open or close. The status of hand reset LEDs is retained in capacitor-backed memory in the event of supply loss. ©2010 Siemens Protection Devices Limited Chapter 7 Page 18 of 49... -
Page 19: Section 3: Protection Functions
100.00 10.00 10.00 1.00 1.00 0.10 0.10 0.01 0.01 1000 1000 Current (x Is) Current (x Is) Figure 3.1-1 IEC NI Curve with Time ultiplier and Follower DTL Applied ©2010 Siemens Protection Devices Limited Chapter 7 Page 19 of 49... -
Page 20: Selection Of Overcurrent Characteristics
The characteristic curve shape is selected to be the same type as the other relays on the same circuit or to grade with items of plant e.g. fuses or earthing resistors. The application of IDMTL characteristic is summarised in the following table: ©2010 Siemens Protection Devices Limited Chapter 7 Page 20 of 49... -
Page 21: Reset Delay
Figure 3.1-3 Reset Delay ©2010 Siemens Protection Devices Limited Chapter 7 Page 21 of 49... -
Page 22: Voltage Dependent Overcurrent (51V)
The relay will revert to its usual settings (51-n) after elapse of the cold load period. This is determined either by a user set delay, or by the current in all 3-phases falling below a set level (usually related to normal load levels) for a user set period. ©2010 Siemens Protection Devices Limited Chapter 7 Page 22 of 49... -
Page 23: Instantaneous Overcurrent (50/50G/50N)
LV side has a much lower level of fault current. The 50-n elements have a very low transient overreach i.e. their accuracy is not appreciably affected by the initial dc offset transient associated with fault inception. ©2010 Siemens Protection Devices Limited Chapter 7 Page 23 of 49... -
Page 24: Directional Protection (67)
A number of studies have been made to determine the optimum MTA settings e.g. W.K Sonnemann’s paper “A Study of Directional Element Connections for Phase Relays”. Figure 2.6-1 shows the most likely fault angle for phase faults on Overhead Line and Cable circuits. ©2010 Siemens Protection Devices Limited Chapter 7 Page 24 of 49... -
Page 25: Figure 3.5-2 Phase Fault Angles
Note that the relays may be programmed with forward, reverse and non-directional elements simultaneously when required by the protection scheme. Load Figure 3.5-3 Application of Directional Overcurrent Protection ©2010 Siemens Protection Devices Limited Chapter 7 Page 25 of 49... -
Page 26: Out Of 3 Logic
OVERCURRENT> 67 2-out-of-3 Logic = ENABLED Enabling 2-out-of-3 logic will prevent operation of the directional phase fault protection for a single phase to earth fault. Dedicated earth-fault protection should therefore be used if required. ©2010 Siemens Protection Devices Limited Chapter 7 Page 26 of 49... -
Page 27: Directional Earth-Fault (50/51G, 50/51N, 51/51Sef)
Characteristic Angle will change if NPS Polarising is used. Once again the fault angle is completely predictable, though this is a little more complicated as the method of earthing must be considered. Figure 3.6-1 Earth Fault Angles ©2010 Siemens Protection Devices Limited Chapter 7 Page 27 of 49... -
Page 28: High Impedance Restricted Earth Fault Protection (64H)
The calculation of the value of the Stability Resistor is based on the worst case where one CT fully saturates and the other balancing CT does not saturate at all. A separate Siemens Protection Devices Limited Publication is available covering the calculation procedure for REF protection. To summarise this: The relay Stability (operating) Vs voltage is calculated using worst case lead burden to avoid relay operation for through-fault conditions where one of the CTs may be fully saturated. -
Page 29: Negative Phase Sequence Overcurrent (46Nps)
Their withstand is specified in two parts; continuous capability based on a figure of I , and short time capability based on a constant, K, where K = (I t. NPS overcurrent protection is therefore configured to match these two plant characteristics. ©2010 Siemens Protection Devices Limited Chapter 7 Page 29 of 49... -
Page 30: Undercurrent (37)
Phase Overcurrent. An Alarm is provided for θ at or above a set % of capacity to indicate that a potential trip condition exists and that the system should be scrutinised for abnormalities. ©2010 Siemens Protection Devices Limited Chapter 7 Page 30 of 49... -
Page 31: Under/Over Voltage Protection (27/59)
DTL also prevents operation during transient disturbances. The use of IDMTL protection is not recommended because of the difficulty of choosing settings to ensure correct co-ordination and security of supply. ©2010 Siemens Protection Devices Limited Chapter 7 Page 31 of 49... -
Page 32: Neutral Overvoltage (59N)
Typically NVD protection measures the residual voltage (3V ) directly from an open delta VT or from capacitor cones – see fig. 2.13-2 below. Figure 3.12-2 NVD Protection Connections ©2010 Siemens Protection Devices Limited Chapter 7 Page 32 of 49... -
Page 33: 3.12.1 Application With Capacitor Cone Units
Remedial action can then be taken, such as introducing a Balancer network of capacitors and inductors. Very high levels of NPS Voltage indicate incorrect phase sequence due to an incorrect connection. ©2010 Siemens Protection Devices Limited Chapter 7 Page 33 of 49... -
Page 34: Section 4: Ct Requirements
The remote end fault level will be distorted by any parallel infeed or backfeed and is only equivalent to the through fault level for truly radial systems. The following example shows a simple through fault current estimate based on Busbar levels and commonly available data. ©2010 Siemens Protection Devices Limited Chapter 7 Page 34 of 49... -
Page 35: Example Fault Current Estimation
= 33000/√3 = 19.05kV Fault level per phase = 1000/3 = 333MVA 333x10 17.5kA 19.05kV 19.05x10 17.5kA Ω Also, since X/R at the busbar = 20, We can evaluate the source impedance: ©2010 Siemens Protection Devices Limited Chapter 7 Page 35 of 49... - Page 36 Through Fault Current = 19.05x10 4.68kA 4.071 Through fault current = 4.68kA compared to 17.5kA Busbar fault current due to the effect of the line impedance. 19.05kV 17.5kA 4.68kA ©2010 Siemens Protection Devices Limited Chapter 7 Page 36 of 49...
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Page 37: Ct Requirements For Overcurrent And Earth Fault Protection
Where the REF function is used then this dictates that the other protection functions are also used with class PX CTs. A full explanation of how to specify CTs for use with REF protection, and set REF relays is available on our website: www.siemens.com/energy. ©2010 Siemens Protection Devices Limited Chapter 7 Page 37 of 49... -
Page 38: Section 5: Control Functions
For this reason each relay in an ARC scheme must be set with identical Instantaneous and Delayed sequence of trips. Figure 5.1-1 Sequence Co-ordination ©2010 Siemens Protection Devices Limited Chapter 7 Page 38 of 49... -
Page 39: Auto-Reclose Example 1
79 E/F Prot’n Trip 1 : Delayed 79 E/F Prot’n Trip 2 : Delayed 79 E/F Delayed Trips to Lockout : 3 Note that Instantaneous’ trips are inhibited if the shot is defined as ‘Delayed’ ©2010 Siemens Protection Devices Limited Chapter 7 Page 39 of 49... -
Page 40: Auto-Reclose Example 2 (Use Of Quicklogic With Ar)
OUTPUT CONFIG>OUTPUT MATRIX: 51-1 = V1 OUTPUT CONFIG>OUTPUT MATRIX: 50-2 = V2 OUTPUT CONFIG>OUTPUT MATRIX: E1 = V3 CONTROL & LOGIC>QUICK LOGIC: E1 = V1.!V2 INPUT CONFIG>INPUT MATRIX: 79 Lockout = V3 ©2010 Siemens Protection Devices Limited Chapter 7 Page 40 of 49... -
Page 41: 5.2 Quick Logic Applications
CONTROL & LOGIC>QUICK LOGIC: E1 = I1.I2.V1 If required a time delay can be added to the output using the CONTROL & LOGIC > QUICK LOGIC: E1 Pickup Delay setting . ©2010 Siemens Protection Devices Limited Chapter 7 Page 41 of 49... -
Page 42: Section 6: Supervision Functions
Any binary input can be mapped to this input, if it is energised when a trip initiation is received an output will be given immediately (the timers are by passed). ©2010 Siemens Protection Devices Limited Chapter 7 Page 42 of 49... -
Page 43: Figure 6.1-2 Single Stage Circuit Breaker Fail Timing
Operation ms from occuri CB Operate Time Stage 1 CBF Timer (Retrip) = 120ms Stage 2 CBF Timer (Backtrip) = 250ms Figure 6.1-3 Two Stage Circuit Breaker Fail Timing ©2010 Siemens Protection Devices Limited Chapter 7 Page 43 of 49... -
Page 44: Current Transformer Supervision
A 3-phase CT failure is considered so unlikely (these being independent units) that this condition is not tested for. Current Transformer Supervision (60CTS – 7PG2114/6) When a CT fails, the current levels seen by the protection become unbalanced. A large level of NPS current is therefore detected - around 0.3 x In for one or two CT failures. -
Page 45: Voltage Transformer Supervision (60Vts)
For this reason, the relay allows these protection elements - under-voltage, directional over-current, etc. - to be inhibited if a VT failure occurs. ©2010 Siemens Protection Devices Limited Chapter 7 Page 45 of 49... -
Page 46: Trip/Close Circuit Supervision (74T/Ccs)
Scheme 1 provides full Trip supervision with the circuit breaker Open or Closed. Where a ‘Hand Reset’ Trip contact is used measures must be taken to inhibit alarm indications after a CB trip. ©2010 Siemens Protection Devices Limited Chapter 7 Page 46 of 49... -
Page 47: Figure 6.4-2 Trip Circuit Supervision Scheme 2 (H6)
R = 3K3 typical BO 1 BO n Remote Alarm 7SR24 Figure 6.4-3 Trip Circuit Supervision Scheme 3 (H7) cheme 3 provides full Trip supervision with the circuit breaker Open or Closed. ©2010 Siemens Protection Devices Limited Chapter 7 Page 47 of 49... -
Page 48: Close Circuit Supervision Connections
NPS (unbalance) current present. An NPS / PPS ratio > 50% will result from a Broken Conductor condition. Operation is subject to a time delay to prevent operation for transitory effects. ©2010 Siemens Protection Devices Limited Chapter 7 Page 48 of 49... -
Page 49: Circuit-Breaker Maintenance
Typically estimates obtained from previous circuit-breaker maintenance schedules or manufacturers data sheets are used for setting these alarm levels. The relay instrumentation provides the current values of these counters. ©2010 Siemens Protection Devices Limited Chapter 7 Page 49 of 49...