NR Electric PCS-978 Instruction Manual Download

Page: 345 / 480

7 Settings

PCS-978 Transformer Relay

7-9

Date: 2013-01-16

No.

Setting Item

Range

Step

Unit

Description

24.Opt_Up/Upp

0~1

Logic setting of selecting phase voltage or

phase-to-phase

voltage

for

calculation

overexcitation protection.

0: phase voltage; 1: phase-to-phase voltage.

24DT1.K_Set

1.0~1.7

0.001

Multiple setting of stage 1 definite-time overexcitation

protection for trip

24DT1.t_Op

0.1~9999

0.001

Time

delay

setting of

stage

definite-time

overexcitation protection for trip

24DT1.En

0: disable

1: enable

Logic settings of enabling stage 1 definite-time

overexcitation protection for trip

24DT1.OutMap

0000~FFFF

Tripping logic settings of stage 1 definite-time

overexcitation protection for trip

24DT2.K_Set

1.0~1.7

0.001

Multiple setting of stage 2 definite-time overexcitation

protection for alarm

24DT2.t_Op

0.1~9999

0.001

Time

delay

setting of

stage

definite-time

overexcitation protection for alarm

24DT2.En

0: disable

1: enable

Logic settings of enabling stage 2 definite-time

overexcitation protection for alarm

24IDMT.K0_Set

1.0~1.7

0.001

Highest-limit

multiple

setting

inverse-time

overexcitation protection: n0

24IDMT.t0_Op

0.1~9999

0.001

Time delay setting corresponding to highest-limit

setting: t0

24IDMT.K1_Set

1.0~1.7

0.001

Multiple setting 1 of inverse-time overexcitation

protection: n1

24IDMT.t1_Op

0.1~9999

0.001

Time delay setting corresponding to multiple setting 1:

24IDMT.K2_Set

1.0~1.7

0.001

Multiple setting 2 of inverse-time overexcitation

protection: n2

24IDMT.t2_Op

0.1-9999

0.001

Time delay setting corresponding to multiple setting 2:

24IDMT.K3_Set

1.0~1.7

0.001

Multiple setting 3 of inverse-time overexcitation

protection: n3

24IDMT.t3_Op

0.1~9999

0.001

Time delay setting corresponding to multiple setting 3:

24IDMT.K4_Set

1.0~1.7

0.001

Multiple setting 4 of inverse-time overexcitation

protection: n4

24IDMT.t4_Op

0.1~9999

0.001

Time delay setting corresponding to multiple setting 4:

24IDMT.K5_Set

1.0~1.7

0.001

Multiple setting 5 of inverse-time overexcitation

protection: n5

24IDMT.t5_Op

0.1~9999

0.001

Time delay setting corresponding to multiple setting 5:

24IDMT.K6_Set

1.0~1.7

0.001

Multiple setting 6 of inverse-time overexcitation

Summary of Contents for PCS-978

Page 1: ...PCS 978 Transformer Relay Instruction Manual NR Electric Co Ltd ...

Page 2: ......

Page 3: ...operly installed and handled in order to maintain it in a safe condition When electrical equipment is in operation dangerous voltages will be present in certain parts of the equipment Failure to observe warning notices incorrect use or improper use may endanger personnel and equipment and cause personal injury or physical damage Before working in the terminal strip area the equipment must be isola...

Page 4: ...rts of these devices are under high voltage Severe personal injury or significant equipment damage could result from improper behavior Only qualified personnel should work on this equipment or in the vicinity of this equipment These personnel must be familiar with all warnings and service procedures described in this manual as well as safety regulations In particular the general facility and safet...

Page 5: ...sed in order to prevent the connected circuit from overheating Connection cable Carefully handle the connection cable without applying excessive force Copyright Version 2 04 P N EN_YJBH5100 0086 0205 Copyright NR 2013 All rights reserved NR ELECTRIC CO LTD 69 Suyuan Avenue Jiangning Nanjing 211102 China Tel 86 25 87178185 Fax 86 25 87178208 Website www nrelect com www nari relays com Email nr_tech...

Page 6: ...Preface PCS 978 Transformer Relay IV Date 2013 01 16 ...

Page 7: ...s relay 5 Management Introduce the management function measurment and recording of this relay 6 Hardware Introduce the main function carried out by each module of this relay and providing the definition of pins of each module 7 Settings List settings including equipment settings communication settings description settings display settings logic link settings and etc and some notes about the settin...

Page 8: ...maintenance policy for this relay is outlined 14 Decommissioning and Disposal A general decommissioning and disposal policy for this relay is outlined 15 Manual Version History List the instruction manual version and the modification history records Typographic and Graphical Conventions Deviations may be permitted in drawings and tables when the type of designator can be obviously derived from the...

Page 9: ... time or inverse time characteristic 10ms 0ms Timer delay pickup 10ms delay dropoff 0ms non settable t1 0ms Timer t1 delay pickup settable 0ms t2 Timer t2 delay dropoff settable t1 t2 Timer t1 delay pickup t2 delay dropoff settable IDMT Timer inverse time characteristic Instrument current transformer Instrument voltage transformer ...

Page 10: ...Preface PCS 978 Transformer Relay VIII Date 2013 01 16 ...

Page 11: ...ion Protection 1 11 1 3 8 Mechanical Protection 1 12 1 3 9 Temperature Protection 1 12 1 3 10 Impedance Protection 1 12 1 3 11 Phase Overcurrent Protection 1 12 1 3 12 Ground Overcurrent Protection 1 12 1 3 13 Negative sequence overcurrent protection 1 13 1 3 14 Phase Overvoltage Protection 1 13 1 3 15 Residual Overvoltage Protection 1 13 1 3 16 Undervoltage Protection 1 13 1 3 17 Thermal Overload...

Page 12: ...12 10 09 Figure 1 2 2 Function diagram 2 for protecting an auto transformer 1 6 Figure 1 2 3 Function diagram 3 for protecting a reactor 1 6 List of Tables Table 1 2 1 Protective functions in PCS 978 1 4 Table 1 2 2 Miscellaneous functions in PCS 978 1 6 ...

Page 13: ...rmer or auto transformer in any voltage level protection of a shunt reactor which provides up to 36 analog input channels including current and voltage inputs PCS 978 provides full transformer protections configurable by user Ancillary functions of fault diagnostic disturbance records event records and communication function are integrated in the relay Applications of PCS 978 are shown as below ...

Page 14: ...e side a 2 winding power transformer b 2 winding power transformer with 2 circuit breakers on one side c 2 winding power transformer 2 two circuit breakers on two sides f 3 winding power transformer with 2 circuit breakers on two sides g 3 winding power transformer with 2 circuit breakers on each side Figure 1 1 1 2 winding and 3 winding applications ...

Page 15: ...wo sides a autotransformer with 1 circuit breaker at two sides b autotransformer with 2 circuit breakers on one side and 1 circuit breaker at the other side c autotransformer with 2 circuit breakers on two sides f autotransformer with 2 circuit breakers on two sides and 1 circuit breaker on the other one side g autotransformer with 2 circuit breakers on each side Figure 1 1 2 Autotransformer appli...

Page 16: ...al protection 7 87DR Biased restricted earth fault protection 64REF Biased winding differential protection 87W 87N Inter turn fault protection 32G 21G Definite time overexciation protection Inverse time overexcitation protection 24 Underfrequency protection Overfrequency protection 81U 81O Mechanical protection MR Temperature protection 26 Phase to phase impedance protection Phase to earth impedan...

Page 17: ...ower system the fault component could be analyzed into three parts the power frequency components before the fault the power frequency variables during the fault and the transient variables during the fault DPFC is the power frequency variable during the fault Function Diagram The function diagrams for protecting a three winding transformer an auto transformer and a reactor are respectively shown ...

Page 18: ... Function diagram 2 for protecting an auto transformer Shunt reactor 52 52 52 Bus I Bus II Neutral earthing reactor CT1 CT2 CT3 VT Line PCS 978 87R 7 87DR 50 87UR DIFF 87N NeuDiff 3I0 Cal 3I0 Cal 32G 21G IntTurn 3I0 Cal 50P 51P DT IDMT OC 50N 51N DT IDMT OC 49 THEM MR Mechanical signals or transducer signals from reactor 50G 51G DT IDMT OC Figure 1 2 3 Function diagram 3 for protecting a reactor M...

Page 19: ...events 1024 binary input events 1024 device log events Local HMI LCD and keypad Remote HMI PCS Explorer software or substation automation system software Rear communication ports to host Ports type RS 485 RJ45 Ethernet Fiber optic abbreviated as FO Ethernet Protocol type IEC 60870 5 103 IEC 61850 8 1 DNP 3 0 Specified when order Rear communication port to printer One RS 485 or RS 232 Time synchron...

Page 20: ...protection relays within a sampling interval On the premise of 24 samples per cycle all data measurement calculation and logic discrimination could be done within one sampling period The event recording and protection logic calculation are completed simultaneously Independent Fault Detector Independent fault detectors in fault detector DSP module for connecting power supply of output relays The re...

Page 21: ... 24 vector groups available for two winding transformer 288 vector groups available for 3 winding transformer Optional inrush current distinguished principles harmonic criterion second harmonic and third harmonic or waveform distortion There are two optional modes for harmonic criterion self adaptive blocking mode and phase to phase cross blocking mode Self adaptive blocking mode can enhance abili...

Page 22: ...transformer with two circuit breakers at HV and MV sides respectively Maximum 3 REF protections for each side of a three winding transformer Inrush current has no effect on REF protection RFE protection has high sensitivity to internal earth faults because there is no load current in the restraint current The tap of transformer has no effect on REF protection CT Transient detection function based ...

Page 23: ...on DPFC biased current differential protection is regardless of the load current and is sensitive to small internal fault current within the reactor Its performance against current transformer saturation is also good Reliable biased current differential protection Biased current differential protection with initial restraint slope consists of sensitive and conventional differential elements as wel...

Page 24: ...pedance Protection Two stage phase to phase impedance protection elements Two stage phase to earth impedance protection elements Power swing blocking releasing function 1 3 11 Phase Overcurrent Protection Four stage phase overcurrent protection with independent logic current and time delay settings Stage 1 stage 2 and stage 3 are definite time characteristic stage 4 can be selected as definite tim...

Page 25: ...urve 1 3 14 Phase Overvoltage Protection Two stage phase overvoltage protection with independent logic voltage and time delay settings Stage 1 and stage 2 definite time characteristic stage 2 can be selected as definite time or inverse time characteristic T The inverse time characteristic is selectable among IEC and ANSI IEEE standard inverse time characteristics and a user defined inverse time cu...

Page 26: ...d one stage for trip Fundamental current or 1st to 7th harmonic current is used for protection calculation NOTE Users muse declare current value calculation for thermal overload protection fundamental current or 1st to 7th harmonic current before making an order 1 3 18 Measurement Energy metering active and reactive energy are calculated ...

Page 27: ...5 2 4 Communication Port 2 5 2 4 1 EIA 485 Port 2 5 2 4 2 Ethernet Port 2 5 2 4 3 Optical Fibre Port 2 5 2 4 4 Print Port 2 6 2 4 5 Clock Synchronization Port 2 6 2 5 Type Tests 2 6 2 5 1 Environmental Tests 2 6 2 5 2 Mechanical Tests 2 6 2 5 3 Electrical Tests 2 6 2 5 4 Electromagnetic Compatibility 2 7 2 6 Certifications 2 7 2 7 Protective Functions 2 8 2 7 1 Transformer Current Differential Pro...

Page 28: ...se Overcurrent protection 2 12 2 7 11 Ground Overcurrent Protection 2 13 2 7 12 Negative Sequence Overcurrent Protection 2 14 2 7 13 Phase Overvoltage Protection 2 15 2 7 14 Residual Overvoltage Protection 2 15 2 7 15 Undervoltage Protection 2 16 2 7 16 Thermal Overload Protection 2 16 2 7 17 Breaker Failure Initiation 2 17 2 7 18 Pole Disagreement Protection 2 17 2 7 19 Phase Overcurrent Alarm El...

Page 29: ...al voltage input Linear to 1 170V 1 233V Thermal withstand continuously 10s 1s 200V 260V 300V 220 380 420 Burden at rated 0 20VA phase Un 0 80VA phase Un Voltage input channel Maximum 18 Maximum 9 2 1 2 Power Supply Standard IEC 60255 11 2008 Rated Voltage 110Vdc 125Vdc 220Vdc 250Vdc Variation 80 300Vdc Permissible AC ripple voltage 15 of the nominal auxiliary voltage Burden Conventional substatio...

Page 30: ...from ECVT directly NR1152 3 5 Mechanical Relay Module NR1533A 0 3 without IO burden BO Module 11 output contacts NR1521A 0 3 without BO burden Signal Output Module 11 signal contacts in 4 groups NR1523B 0 3 without BO burden Signal Output Module 11 signal contacts NR1521C 0 3 without BO burden BI Module 11 individual binary inputs NR1503 0 3 BI Module 18 binary inputs common negative NR1504 0 3 PW...

Page 31: ...utput Output type Tripping contact Signal contact Output mode Potential free contact Continuous carry 5A 380Vac 5A 250Vdc 8A 380Vac 8A 250Vdc Pickup time 8ms typical 3ms 10ms Dropoff time 5ms 5ms Breaking capacity L R 40ms 0 65A 48Vdc 0 30A 110Vdc 0 15A 220Vdc 1 20A 48Vdc 0 50A 110Vdc 0 25A 220Vdc Burden 300mW 400mW Maximal system voltage 380Vac 250Vdc 380Vac 250Vdc Test voltage across open contac...

Page 32: ...NR1102A 0 4 MON Module Management 64M DDR 4 x RJ45 Ethernet RS485 Syn RS232 printer NR1102B 0 4 MON Module Management 128M DDR 2 x RJ45 Ethernet RS485 Syn RS232 printer NR1102C 0 4 MON Module Management 256 DDR 4 x RJ45 Ethernet RS485 Syn RS232 printer NR1102M 0 4 MON Module Management 256M DDR 2 x RJ45 2 x FO ST Ethernet RS485 Syn RS232 printer NR1102J 0 4 MON Module Management 128M DDR 2 x RJ45 ...

Page 33: ...Readability of display may be impaired below 20 C Transport and storage temperature range 40 C to 70 C Permissible humidity 5 95 without condensation Pollution degree 2 Altitude 3000m 2 4 Communication Port 2 4 1 EIA 485 Port Baud rate 4 8kbit s 9 6kbit s 19 2kbit s 38 4kbit s 57 6kbit s 115 2kbit s Protocol IEC 60870 5 103 1997 Maximal capacity 32 Transmission distance 500m Safety level Isolation...

Page 34: ...232 Baud Rate 4 8kbit s 9 6kbit s 19 2kbit s 38 4kbit s 57 6kbit s 115 2kbit s Printer type EPSON 300K printer Safety level Isolation to ELV level 2 4 5 Clock Synchronization Port Type RS 485 Transmission distance 500m Maximal capacity 32 Timing standard PPS IRIG B Safety level Isolation to ELV level 2 5 Type Tests 2 5 1 Environmental Tests Dry cold test IEC60068 2 1 2007 Dry heat test IEC60068 2 ...

Page 35: ...V m rms f 900MHz Fast transient disturbance tests IEC 60255 22 4 2008 Power supply I O Earth class IV 4kV 2 5kHz 5 50ns Communication terminals class IV 2kV 5kHz 5 50ns Surge immunity test Per IEC 60255 22 5 2008 Power supply AC input I O port class IV 1 2 50us Common mode 4kV Differential mode 2kV Conducted RF Electromagnetic Disturbance IEC 60255 22 6 2001 Power supply AC I O Comm Terminal Class...

Page 36: ...nt differential protection Id differential current I0d residual differential current Iwd winding differential current d I DPFC differential current f U the overexcitation multiple 2 7 1 Transformer Current Differential Protection 2 7 1 1 Biased Differential Protection Current setting of knee point 1 87T I_Knee1 0 1 1pu 0 001pu steps Current setting of knee point 2 87T I_Knee2 4 8pu 0 001pu steps P...

Page 37: ...ce of current setting 2 5 of setting or 0 02pu whichever is greater Drop off to pickup ratio 95 Operating time 50Hz 20ms Id 1 5x 87T I_Instant 60Hz 20ms Id 1 5x 87T I_Instant Drop off time 30ms 2 7 1 3 DPFC Current Differential Protection Pickup current value 0 2pu Tolerance of operating current 10 Slope 1 value 0 6 fixed Slope 2 value 0 75 fixed Drop off to pickup ratio 95 Operating time 50Hz 30m...

Page 38: ...ion 50Hz 30ms Iwd 2 87W I_Biased 60Hz 25ms Iwd 2 87W I_Biased Tolerance of time setting 1 of setting 30ms I0d 2x 87W I_Biased Drop off time 30ms 2 7 4 Reactor Differential Protection 2 7 4 1 Biased Differential Protection Pickup up setting 87R I_Biased 0 05 5pu 0 001pu steps Slope setting 87R Slope 0 1 0 9 steps 0 001 Tolerance of operating current 5 of operating current or 0 02pu whichever is gre...

Page 39: ... time of definite time overexciation protection 1 of setting 30ms at 1 5 times f U setting Tolerance of operating time of inverse time overexcitation protection 2 5 of operating time or 30ms whichever is greater Drop off time of definite time overexcitation protection 30ms 2 7 7 Mechanical Protection Delay pickup up time setting MR t_DPU_n n 1 2 3 4 0 3600s 0 001s steps Pulse width setting MR t_PW...

Page 40: ... or 0 02In whichever is greater Drop off to pickup ratio 95 Operating time of instantaneous OC 50Hz 25 ms at 2 times current setting 60Hz 23 ms at 2 times current setting Time delay setting 50 51Pn t_Op n 1 2 3 0 00 3600s 0 001s steps Tolerance of time setting of DT OC 1 of setting 30ms at 2 times current setting Drop off time 30ms 2 7 10 2 Inverse time Phase Overcurrent Pickup current setting 50 ...

Page 41: ...rrent Protection Current setting 50 51Gn 3I0_Set n 1 2 3 0 04In 30In 0 001A steps Tolerance of current setting of DT ROC 2 5 of setting or 0 02In whichever is greater Drop off to pickup ratio 95 Operating time of instantaneous ROC 50Hz 25 ms at 2 times current setting 60Hz 23 ms at 2 times current setting Time delay setting 50 51Gn t_Op n 1 2 3 0 00 3600s 0 001s steps Tolerance of time setting of ...

Page 42: ...ng or 0 02In whichever is greater Drop off to pickup ratio 95 Operating time of instantaneous NegOC 50Hz 25 ms at 2 times current setting 60Hz 23 ms at 2 times current setting Time delay setting 50 51Q1 t_Op 0 00 3600s 0 001s steps Tolerance of time setting of DT NegOC 1 of setting 30ms at 2 times current setting Drop off time 30ms 2 7 12 2 Inverse time Negative Sequence Overcurrent Protection Pic...

Page 43: ...ater Drop off to pickup ratio 95 Multiple of the maximum operating current to the pickup setting 59P2 K_Iset 10 40 0 001 steps Time multiplier setting 59P2 TMS 0 05 3 2 0 001 steps Minimum delay setting 59P2 tmin 0 0 20s 0 001s steps Constant K 59P2 K 0 0 120 0 001 steps Constant C 59P2 C 0 0 20s 0 001s steps Operating time of IDMT OV 2 5 of operating time or 30ms whichever is greater for voltage ...

Page 44: ... UVn U_Set n 1 2 3 4 10 100V Lowest voltage threshold of voltage recovery 27 U_Recov 10 100V Tolerance of voltage setting 2 5 of setting or 0 1V whichever is greater Drop off to pickup ratio 102 Operating time of UV at zero time delay 50Hz 20ms at 0 8 times voltage setting 60Hz 20ms at 0 8 times voltage setting Time setting of DT UV 27 UVn t_Op n 1 2 3 4 0 05 100s Time setting of fault recovery 27...

Page 45: ...0s 20s 0 001s steps Time setting tolerance 1 of setting 30ms at 2 times current setting Drop off time 20ms 2 7 18 Pole Disagreement Protection Range of residual current setting 62PD 3I0_Set 0 04In 30In 0 001In steps Range of negative sequence current setting 62PD I2_Set 0 04In 30In 0 001In steps Current setting tolerance 2 5 of setting or 0 02 In whichever is greater Drop off to pickup ratio 95 Ra...

Page 46: ...f setting 30ms at 2 times current setting Drop off time 30ms 2 7 20 Residual Overvoltage Alarm Element Voltage setting 59GAlm 3U0_Set 2 200V Tolerance of voltage setting 2 5 of setting or 0 1V whichever is greater Drop off to pickup ratio 95 Time delay setting 59GAlm t_Op 0s 3600s 0 001s steps Tolerance of time setting 1 of setting 30ms at 1 2 times voltage setting Drop off time 30ms ...

Page 47: ... 2 6 Settings 3 32 3 3 Reactor Current Differential Protection 87R 3 34 3 3 1 Application 3 34 3 3 2 Function 3 34 3 3 3 Protection Principle 3 34 3 3 4 Logic 3 49 3 3 5 Inputs and Outputs 3 51 3 3 6 Settings 3 53 3 4 Restricted Earth Fault Protection 64REF 3 54 3 4 1 Application 3 54 3 4 2 Function 3 54 3 4 3 Protection Principle 3 54 3 4 4 Logic 3 61 3 4 5 Inputs and Outputs 3 63 3 4 6 Settings ...

Page 48: ...utputs 3 80 3 6 6 Settings 3 80 3 7 Overexcitation Protection 24 3 81 3 7 1 Application 3 81 3 7 2 Function 3 81 3 7 3 Protection Principle 3 81 3 7 4 Logic 3 83 3 7 5 Inputs and Outputs 3 84 3 7 6 Settings 3 86 3 8 Frequency Protection 81 3 89 3 8 1 Application 3 89 3 8 2 Function 3 89 3 8 3 Fault Detector 3 90 3 8 4 Protection Principle 3 90 3 8 5 Logic 3 92 3 8 6 Inputs and Outputs 3 94 3 8 7 S...

Page 49: ...ction 3 105 3 11 1 Application 3 105 3 11 2 Function 3 105 3 11 3 Protection Principle 3 105 3 11 4 Logic 3 109 3 11 5 Inputs and Outputs 3 111 3 11 6 Settings 3 112 3 12 Phase Overcurrent Protection 50 51P 3 113 3 12 1 Application 3 113 3 12 2 Function 3 114 3 12 3 Protection Principle 3 114 3 12 4 Logic 3 120 3 12 5 Inputs and Outputs 3 122 3 12 6 Settings 3 123 3 13 Ground Overcurrent Protectio...

Page 50: ...141 3 15 2 Function 3 141 3 15 3 Protection Principle 3 141 3 15 4 Logic 3 144 3 15 5 Inputs and Outputs 3 144 3 15 6 Settings 3 145 3 16 Residual Overvoltage Protection 59G 3 147 3 16 1 Application 3 147 3 16 2 Function 3 147 3 16 3 Protection Principle 3 147 3 16 4 Logic 3 149 3 16 5 Inputs and Outputs 3 149 3 16 6 Settings 3 150 3 17 Undervoltage Protection 27 3 152 3 17 1 Application 3 152 3 1...

Page 51: ...ut 3 164 3 19 5 Settings 3 165 3 20 Pole Disagreement Protection 62PD 3 166 3 20 1 Application 3 166 3 20 2 Protection Principle 3 166 3 20 3 Logic 3 166 3 20 4 Input and Output 3 167 3 20 5 Settings 3 168 3 21 Phase Overcurrent Alarm Element 50PAlm 3 168 3 21 1 Application 3 168 3 21 2 Function 3 169 3 21 3 Operation Principle 3 169 3 21 4 Logic 3 170 3 21 5 Inputs and Outputs 3 170 3 21 6 Settin...

Page 52: ...n 3 177 3 24 2 Function 3 177 3 24 3 Principle 3 178 3 24 4 Logic 3 178 3 24 5 Inputs and Outputs 3 179 3 24 6 Settings 3 180 3 25 Residual Current Element Curr1P 3 180 3 25 1 Application 3 180 3 25 2 Function 3 180 3 25 3 Inputs and Outputs 3 180 3 25 4 Settings 3 180 3 26 Residual Voltage Element Volt1P 3 181 3 26 1 Application 3 181 3 26 2 Function 3 181 3 26 3 Inputs and Outputs 3 181 3 26 4 S...

Page 53: ... differential protection for transformer 3 19 Figure 3 2 7 Schematic of wave symmetry principle 3 21 Figure 3 2 8 Logic diagram of current differential protection 3 27 Figure 3 2 9 Logic diagram of DPFC biased differential protection 3 28 Figure 3 2 10 Logic diagram of CT circuit failure 3 29 Figure 3 2 11 87T function block 3 30 Figure 3 3 1 Current compensation calculation process 3 38 Figure 3 ...

Page 54: ...ing differential protection 3 70 Figure 3 5 4 Logic diagram of winding differential protection of HV side 3 71 Figure 3 5 5 87W function block 3 72 Figure 3 6 1 Wiring diagram of shunt reactors in power system 3 76 Figure 3 6 2 Equivalent zero sequence network for case 1 3 76 Figure 3 6 3 Vector relation for case 1 3 77 Figure 3 6 4 Equivalent zero sequence network for case 2 3 77 Figure 3 6 5 Vec...

Page 55: ...Logic Diagram of phase overcurrent protection of x side 50 51Pn n 1 2 3 4 3 121 Figure 3 12 5 Logic Diagram of phase to phase VCE 3 121 Figure 3 12 6 Logic Diagram of negative sequence VCE 3 121 Figure 3 12 7 Function block 50 51P Each stage 3 122 Figure 3 13 1 Function diagram of ground overcurrent protection 3 127 Figure 3 13 2 Connection of VT and CT of directional element 3 129 Figure 3 13 3 D...

Page 56: ...k 50PAlm each stage 3 170 Figure 3 22 1 Logic diagram of residual overvoltage alarm element 59GAlm 3 172 Figure 3 22 2 Function block 59GAlm 3 173 Figure 3 23 1 Current pre processing logic diagram 3 175 Figure 3 23 2 Function block Curr3P 3 175 Figure 3 24 1 Voltage pre processing logic diagram 3 178 Figure 3 24 2 Function block Volt3P 3 179 Figure 3 25 1 Function block Curr1P 3 180 Figure 3 26 1...

Page 57: ...ut signals of 87W report 3 72 Table 3 5 4 Output signals of 87W measurements 3 73 Table 3 5 5 Setting list of 87W 3 73 Table 3 6 1 Input signals of IntTurn function block 3 80 Table 3 6 2 Output signals of IntTurn function block 3 80 Table 3 6 3 Output signals of IntTurn report 3 80 Table 3 6 4 Settings of IntTurn 3 80 Table 3 7 1 Input signals of function blocks 24DT and 24IDMT 3 85 Table 3 7 2 O...

Page 58: ...le 3 11 2 Output signals of function block 21 3 111 Table 3 11 3 Output signals of 21 report 3 112 Table 3 11 4 Setting list of 21 3 112 Table 3 12 1 Inverse time curve parameters of stage 4 phase overcurrent protection 3 116 Table 3 12 2 Voltage used for VCE 3 117 Table 3 12 3 Current and voltage used for directional element 3 118 Table 3 12 4 Input signals of function block 50 51P Each stage 3 1...

Page 59: ...ck 59G Each stage 3 144 Table 3 15 3 Output signals of function block 59G Each stage 3 145 Table 3 15 4 Output signals of 59G report 3 145 Table 3 15 5 Setting list of 59P Stage 1 3 145 Table 3 15 6 Setting list of 59P Stage 2 3 146 Table 3 16 1 Inverse time curve parameters of stage 2 residual overvoltage protection3 148 Table 3 16 2 Input signals of 59G Each stage 3 149 Table 3 16 3 Output signa...

Page 60: ...Table 3 21 4 Setting list of 50PAlm stage n n 1 2 3 171 Table 3 22 1 Input signals of 59GAlm 3 173 Table 3 22 2 Output signals of 59GAlm 3 173 Table 3 22 3 Output signals of 59G report 3 173 Table 3 22 4 Setting list of 59G 3 173 Table 3 23 1 Input signals of function block Curr3P 3 175 Table 3 23 2 Output signals of function block Curr3P 3 176 Table 3 23 3 Output signals of Curr3P report 3 176 Ta...

Page 61: ... signals of function block Volt1P 3 181 Table 3 26 3 Setting list of Volt1P 3 181 Table 3 27 1 Input signals of programmable tripping output element 3 184 Table 3 27 2 Setting list of programmable tripping output element 3 184 Table 3 28 1 Signals of intermediate variable element 3 185 ...

Page 62: ...3 Operation Theory PCS 978 Transformer Relay 3 p Date 2013 01 16 ...

Page 63: ...not operate The fault detector of fault detector DSP module consists of several independent fault detector elements which can monitor corresponding protection elements without influence to other protection elements For example biased current differential protection will not release trip command until both protection element of protection DSP module and the corresponding fault detector of fault det...

Page 64: ... windings by adopting Δ Y method High sensitive and securable DPFC biased differential protection DPFC biased current differential protection is regardless of the load current and is sensitive to small internal fault current within the transformer Its performance against current transformer saturation is also good Reliable biased current differential protection Biased current differential protecti...

Page 65: ... I 0 9x 87T I_Instant Equation 3 2 2 Where d I is the differential current of any phase 87T I_Instant is the setting of the unrestrained instantaneous differential protection Fault Detector of DPFC Differential Current The pickup of this fault detector will enable the DPFC biased differential protection and its operation equation is as follows m d dth dt d I I I I I I I 25 1 2 1 Equation 3 2 3 Whe...

Page 66: ...e to the mismatch between the CT ratios and the power transformer ratio The current value difference between each side shall be eliminated before calculation for current differential protection by amplitude compensation Calculate rated primary current at each side nBrm n bBrm U S I 1 1 3 Equation 3 2 4 Where Brm Branch side m n S is the maximum rated capacity i e the setting Sn n U1 is rated prima...

Page 67: ...f CT at branch 1 branch 2 and branch m of differential protection NOTE If Equation 3 2 6 is not met alarm signals ProtBrd Fail_Settings and FDBrd Fail_Settings are issued and displayed on LCD and the protective equipment being blocked at the same time NOTE If Equation 3 2 7 is not met DPFC biased differential protection must not be enabled Otherwise alarm signals ProtBrd Fail_Settings and FDBrd Fa...

Page 68: ...nable zero sequence current elimination for phase compensation of each side of transformer The setting is recommended to be set to 1 in general condition and only if one side of transformer without eathing transformer being connected to is not grounded the setting of corresponding side is recommended to be set to 0 For example The vector group of a transformer is Y0 Δ11 and the target o clock Clk_...

Page 69: ... 30 leading 1 0 1 1 1 0 0 1 1 3 1 1 0 1 1 1 0 0 1 1 3 1 2 shift 60 leading 0 0 1 1 0 0 0 1 0 1 1 2 2 1 1 1 2 1 3 1 3 Shit 90 leading 0 1 1 1 0 1 1 1 0 3 1 0 1 1 1 0 1 1 1 0 3 1 4 Shit 120 leading 0 1 0 0 0 1 1 0 0 1 2 1 1 1 2 2 1 1 3 1 5 Shift 150 leading 1 1 0 0 1 1 1 0 1 3 1 1 1 0 0 1 1 1 0 1 3 1 6 Shift 180 leading 1 0 0 0 1 0 0 0 1 2 1 1 1 2 1 1 1 2 3 1 7 Shift 150 lagging 1 0 1 1 1 0 1 1 1 3 ...

Page 70: ...A bBr C B A bBr C B A dC dB dA I I I I M I I I I M I I I I M I I I I M I I I I M I I I I M I I I Equation 3 2 8 The above equation can be simplified to the following 6 5 4 3 2 1 6 5 4 3 2 1 6 5 4 3 2 1 C C C C C C dC B B B B B B dB A A A A A A dA I I I I I I I I I I I I I I I I I I I I I Equation 3 2 9 Where I I I Cm Bm Am in the equation are vectors the secondary current of branch Br for abbrevia...

Page 71: ...ample In an ideal situation the differential current i e L I H I Id _ _ should be zero during the normal operation of the transformer or an external fault occurring I _L I_L Phase shift zero sequence current elimination M1 Magnitude compensation I2bBr1 Calculate differential current and restraint current PCS 978 HV side LV side Magnitude compensation I2bBr2 Phase shift zero sequence current elimin...

Page 72: ...ot operate 2 Internal short circuit e g fed with equal currents each side The following applies I _L I _H moreover I _L I _H Id I _H I _L I _H I _H 2 I _H Ir I _H I _L 2 I _H I _H 2 I _H Differential current Id are two times of restraint current Ir and corresponding to the total fault and current differential protection operates 3 Internal short circuit fed from one side only The following applies...

Page 73: ... 2 11 Where i I i 1 m are the phase currents of each branch from 1 to m of a transformer respectively d I is the differential current r I is the restraint current I_Biased is the pickup current of biased differential protection I_Knee1 and I_Knee2 are respectively current settings of knee point 1 and knee point 2 Slope1 Slope2 Slope3 are three slopes of biased differential protection Recommended v...

Page 74: ...onal Biased Differential Protection Conventional biased differential protection with higher setting and restraint coefficient comparing with sensitive biased differential protection is blocked only by an inrush current detection Conventional biased differential protection provides faster operation for severe internal faults Operation criterion of this biased differential protection is pu I pu I I ...

Page 75: ...rve of transformer conventional biased differential protection 3 2 3 8 Unrestrained Instantaneous Differential Protection Unrestrained instantaneous differential protection for transformer is to accelerate the operation speed for transformer s internal fault The element has no blocking element but to guard that the setting must be greater than the maximum inrush current Unrestrained differential e...

Page 76: ...ntial protections for transformer In above figure KP1 KP2 are respectively X axis values of knee point 1 and knee point 2 i e 87T I_Knee1 and 87T I_Knee2 A is the point shows normal operation of transformer B is the point shows CT saturation C D E and F are points show internal faults or external fault of transformer 1 Sensitive biased differential protection element will send tripping signal moni...

Page 77: ... is the deeper shadow area in the figure above When an internal fault occurs differential current rises greatly and the operating point moves to F in the tripping area of conventional biased differential protection NOTE Only the second harmonic criterion is adapted to distinguishing inrush current for blocking conventional biased differential protection 3 Unrestrained instantaneous differential pr...

Page 78: ...perfect performance of fault detection 3 2 3 10 2 Operation Criterion DPFC Deviation of Power Frequency Component biased differential protection reflects variation of load condition to perform a sensitive protection for the transformer Lab tests show that it is more sensitive than the biased differential relay under the heavy load condition The operation criteria of DPFC biased differential are as...

Page 79: ...t current and differential current is phase segregated DPFC biased differential protection is blocked by inrush current overexcitation and CT circuit failure Advantages of DPFC differential protection DPFC biased differential protection has the higher anti CT saturation characteristic the sensitivity of which to slight inter turn fault is maintained during normal operation of transformer Floating ...

Page 80: ...a_HVS I b_LVS Ib_LVS Max 1 3A 0 1A 0 1 1A 180 1A 180 0 3A Conclusion DPFC differential protection is more sensitive than biased differential protection during an internal fault 2 An external fault I a_HVS 2A 0 I b_LVS 2A 180 other phase supposed zero Biased differential protection for the fault Id I a_HVS I b_LVS 2A 0 2A 180 0A Ir 0 5x I a_HVS I b_LVS 0 5x 2A 0 2A 180 2A DPFC differential protecti...

Page 81: ...t blocking principle If the logic setting is set as 0 discrimination by waveform distortion is enabled and if it is set as 1 discrimination by harmonics is enabled 3 2 3 11 1 Distinguishing by Harmonics In PCS 978 series protection equipment the second and third harmonics of differential current can be used to distinguish inrush current Its criteria are st d rd d st d nd d I Inrush 87T K_Hm3_ I I ...

Page 82: ...iased differential elements If En_Hm3_Inrush is set to 1 then the third harmonic criterion is used as inrush blocking function only for sensitive biased differential element at the same time 3 2 3 11 2 Distinguishing by Wave Distortion The differential current is basically the fundamental sinusoidal wave during a fault When the transformer is energized plentiful harmonics will appear and the wavef...

Page 83: ...Inrush is set to 1 then the third harmonic criterion is used as inrush blocking function only for sensitive biased differential element at the same time 3 2 3 11 3 Inrush Blocking Mode Users can select the inrush blocking mode of harmonic by the logic setting 87T Opt_BlkMode_Inrush When it is set to 0 above described self adaptive blocking mode is adopted and when set to 1 the phase to phase cross...

Page 84: ...d Idc Table 3 2 2 Comparison of different blocking modes Situation Harmonic of each phase current Mode 1 self adaptive blocking mode Mode 2 phase to phase crossing block mode Mode 3 Phase blocking Mode 1 Ida great harmonic Diff prot not operate Diff prot not operate Diff prot not operate Idb great harmonic Idc great harmonic 2 Ida little harmonic Diff prot operate Diff prot operate Diff prot opera...

Page 85: ...nd CT is still saturated caused by AC excitation which is called stable CT saturation According to our lab tests it is found that the second harmonic component is greater than the third harmonic component at CT transient saturation stage and the third harmonic is greater than the secondary harmonic at the CT stable saturation stage Therefore the second and third harmonics both can be used to detec...

Page 86: ...oefficient of third or fifth harmonic overexcitation detection and the recommended value is 0 25 If the logic setting 87T Opt_Hm3 Hm5_OvExc is set to 0 the 3rd harmonic is selected for calculation and if set to 1 5th harmonic is selected Correspondingly the setting 87T K_Hm3 Hm5_OvExc is to set 3rd or 5th harmonic coefficient 5th harmonic is recommended to be selected for overexcitation calculatio...

Page 87: ...side increases after fault detector picks up The maximum phase current is greater than 1 1pu after the fault detector picks up DPFC element of any phase to phase voltage of any side picks up 2 Second case if CT circuit abnormality of differential protection alarm i e 87T Alm_Diff is issued and negative sequence current of one side is greater than 0 04 times maximum phase current of the correspondi...

Page 88: ...ting is set as 1 biased REF protection is blocked 6 Biased winding differential protection can be blocked when CT circuit failure is detected by configuring the logic setting 87W En_CTS_Blk If this logic setting is set as 0 biased winding differential protection is not blocked If this logic setting is set as 1 biased winding differential protection is blocked NOTE The operation time of biased diff...

Page 89: ...ff SIG FD_InstDiff SIG FD_BiasDiff 0ms 500ms 0ms 500ms 0ms 500ms 87T Op_Instant 87T Op_Biasd Figure 3 2 8 Logic diagram of current differential protection Where Idmax is the maximum value of three phase differential currents f U is the value indicating the degree of overexcitation of transformer Flg_ConvBiasDiff is the internal flag indicating that operation criteria of conventional biased differe...

Page 90: ...criptions of three flags of inrush current in logic figures are given below Internal flag Related Criterion Flg_Inrush_SensBiasDiff Second harmonic or wave distortion alternative Third harmonic selectable Flg_Inrush_ConvBiasDiff Second harmonic or wave distortion alternative Flg_Inrush_DPFC_Diff Second harmonic or wave distortion alternative 3 2 4 2 Logic of DPFC Biased differential Protection 0ms...

Page 91: ... signal indicating that the fault detector of biased differential protection picks up Upp is the secondary phase to phase rated voltage Flg_DPFCVolt is the internal flag indicating that DPFC element of any phase to phase voltage of any side picks up Flg_CurrIncrease is the internal flag indicating that any phase current of any side increases after fault detector picks up Ipmax 1 1pu represents tha...

Page 92: ...binary input When the input is 1 the protection is not reset Table 3 2 4 Output signals of 87T function block No Signal Description 1 St Current differential protection starts 2 Op Transformer current differential protection operates 3 Op_Instant Instantaneous differential protection operates 4 Op_Biased Biased differential protection operates 5 Op_DPFC DPFC differential protection operates 6 Alm_...

Page 93: ... function recorded as IO events NOTE DFR is disturbance and fault recording also called oscillograph function Table 3 2 6 Output signals of 87T measurements No Signal Description Unit 1 87T Ida 87T Idb 87T Idc Three phase differential current pu 2 87T Ithra 87T Ithrb 87T Ithrc Threshold of three phase restraint current pu 3 87T Ida_Hm2_Pct 87T Idb_Hm2_Pct 87T Idc_Hm2_Pct Second harmonic percentage...

Page 94: ...9 0 001 Slope 2 of biased differential protection 7 87T Slope3 0 1 0 9 0 001 Slope 3 of biased differential protection 8 87T K_Hm2_Inrush 0 05 0 3 0 001 Coefficient of 2 nd harmonics for inrush current detection 9 87T K_Hm3_Inrush 0 05 0 3 0 001 Coefficient of 3 rd harmonics for inrush current detection 10 87T I_Alm 0 05 1 5 0 001 pu Setting of differential current abnormality alarm 11 87T K_Hm3 H...

Page 95: ...ssed by a hexadecimal number of 4 digits from 0000H to FFFFH The tripping logic setting of the equipment is specified as follows bit 15 14 13 12 11 10 9 8 7 6 5 4 3 2 1 0 Function TrpOutput16 TrpOutput15 TrpOutput14 TrpOutput13 TrpOutput12 TrpOutput11 TrpOutput10 TrpOutput09 TrpOutput08 TrpOutput07 TrpOutput06 TrpOutput05 TrpOutput04 TrpOutput03 TrpOutput02 TrpOutput01 NOTE TrpOutput01 just means ...

Page 96: ...t decaying DC component in inrush current which may result in the difference of transient transfer characteristics between CTs at two ends of reactor and therefore differential current occurs Inrush current can be distinguished to avoid maloperation of current differential protection by detecting harmonic of differential current and measured current and adopting asynchronous method for recognition...

Page 97: ...this fault detector will enable the biased differential protection and its operation equation is as follows d I 87R I_Biased Equation 3 3 1 Where d I is the differential current of any phase 87R I_Biased is the pickup current of biased differential protection Fault detector of instantaneous differential protection The pickup of this fault detector will enable the unrestrained instantaneous differe...

Page 98: ...ng is not required 3 3 3 3 Amplitude Compensation During the normal operation the magnitudes of secondary current of both ends of reactor are different due to the mismatch between the CT ratios The current value difference shall be eliminated before calculation for current differential protection by amplitude compensation Calculate rated primary current at each side n n b U S I 3 1 Equation 3 3 4 ...

Page 99: ...messages are issued When viewing settings and values of conventional current differential protection in the relay user will find the unit pu per unit The current in differential protection calculation is not actual secondary value but per unit value which is got by actual secondary value of each side of reactor divided by reactor secondary rated current of each branch i e 2 2 1 2 b b I I 3 3 3 4 C...

Page 100: ... inputs for an example In an ideal situation the differential current i e Id I _Line I _Neu should be zero during the normal operation of the transformer or an external fault occurring I _Neu I_Neu PCS 978 Line side Neutral Side I _Line I_Line Magnitude compensation Kph1 I2b1 Calculate differential current and restraint current Magnitude compensation Kph2 I2b2 I _Neu I _Line CT1 CT2 Figure 3 3 1 C...

Page 101: ... _Line No differential current Id 0 restraint current Ir corresponds to double the through flowing current and current differential protection does not operate 2 Internal short circuit I _Line I _Neu The following applies I _Neu 0 5xI _Line Id I _Line I _Neu I _Line 0 5xI _Line 1 5x I _Line Ir I _Neu 0 5x I _Line Differential current Id are three times of restraint current Ir and corresponding to ...

Page 102: ...fferential protection current of neutral side is taken as restraint current When an internal fault occurs current partly flows into ground through the short circuit point so current at neutral side will decrease and therefore the sensitivity of differential protection is improved 87R I_Biased is the pickup current of biased differential protection 87R Slope is the slope of biased differential prot...

Page 103: ...ventional biased differential protection with higher setting and restraint coefficient comparing with sensitive biased differential protection is blocked only by an inrush current detection Conventional biased differential protection provides fast operation for severe internal faults Operation criterion of this biased differential protection is pu I pu pu I I pu I pu I r r d r d 8 0 2 1 8 0 6 0 8 ...

Page 104: ... accelerate the operation speed for reactor s internal fault The element has no blocking element but to guard that the setting must be greater than the maximum unbalanced current caused by inrush current Unrestrained differential element shall operate to clear the fault when any phase differential current is higher than its setting Its operation criterion is d I 87R I_Instant Equation 3 3 12 Where...

Page 105: ...ed by criteria of CT transient characteristic difference and CT circuit failure optional It can ensure sensitivity of protection and avoid the unwanted operation when CT is saturated during an external fault or caused by inrush current Its operation area is the tint shadow area in the figure above When a slight intern fault occurs differential current rises not greatly and the operating point move...

Page 106: ...3 9 DPFC Biased Differential Protection Element 3 3 3 9 1 DPFC Concept 24 k I k I I DPFC Deviation of Power Frequency Component is the power frequency component of fault component which is the differential value between the sampling value at this time point and that at a cycle before k I is the sampling value at the time point 24 k I is the sampling value at a cycle before 24 is the sampling point...

Page 107: ...I I 2 1 I I Id Equation 3 3 13 Where dt I is the floating threshold varied with the change of load current from time to time The change of load current is small and gradually under normal or even power swing condition the adaptive floating threshold dt I is higher than the change of current under these conditions and hence the element maintains stability dth I is fixed threshold and need not use t...

Page 108: ...peration of DPFC differential protection due to system frequency deviation external faults and CB tripping process The sensitivity of current differential protection is improved greatly when DPFC differential protection enabled especially in the situation faults with fault resistance and fault and faults close to neutral side 3 3 3 9 3 Fault Calculation Examples During normal operation Ia_Line 0 5...

Page 109: ...l to 1 and for other phases m is less than 1 3 3 3 10 CT Saturation Detection During reactor energization or a system disturbance decaying DC component is caused because magnetic flux of reactor can not change suddenly The decaying DC component will result in transient CT saturation and differential current occurs correspondingly CT saturation should be detected and block reactor differential prot...

Page 110: ... is the basic principle of asynchronous method 3 3 3 10 2 Harmonic Criterion If the following criterion is satisfied then sensitive biased differential element will be blocked If any harmonic of one phase current meets the following equation it will be considered that the phase differential current is caused by the difference between CT transient characteristics and sensitive percent differential ...

Page 111: ...t 87R Op signals are both reset Default values of Inputs 87R En1 and 87R En2 are 1 and 87R Blk is 0 when those inputs are not connected to external signals or settings 3 3 4 1 Logic of Current Differential Protection SIG Flg_ConvBiasDiff SIG SIG SET SIG 87R Op_Instant EN 87R En_Biased SIG SIG SIG 87R En1 87R En2 87R Blk EN 87R En_Biased SIG SIG SIG 87R En1 87R En2 87R Blk Flg_SensBiasDiff Flg_CT_S...

Page 112: ...ks up FD_BiasDiff is the signal indicating that the fault detector of biased differential protection picks up 3 3 4 2 Logic of DPFC Biased differential Protection 0ms 500ms EN 87R En_DPFC SIG SIG SIG 87R En1 87R En2 87R Blk SIG FD_DPFC_Diff 87R Op_DPFC SIG Flg_DPFC_Diff SIG SIG SIG Flg_Hm2 Hm3 Flg_Asynchr_CTSat Flg_CTS Figure 3 3 8 Logic diagram of DPFC biased differential protection Where Flg_DPF...

Page 113: ...ential protection starts 2 Alm_CTS Alarm message indicating that CT secondary circuit of differential protection fails 3 Alm_Diff Alarm message indicating CT secondary circuit of differential protection abnormal 4 Op_Instant Instantaneous differential protection operates 5 Op_Biased Biased differential protection operates 6 Op_DPFC DPFC differential protection operates Above input signals and outp...

Page 114: ...s of three phase currents of CT at line side used for differential protection pu Ib_Corr_L pu Ic_Corr_L pu I0_Corr_L Corrected values of calculated residual current at line side 2 Ia_Corr_N Corrected values of three phase currents of CT at neutral side used for differential protection pu 3 Ib_Corr_N pu 4 Ic_Corr_N pu 5 I0_Corr_N Corrected values of calculated residual current at neutral side 6 I2b...

Page 115: ...detection 5 87R K_Hm3 0 05 0 3 0 001 Coefficient of 3 rd harmonics for CT saturation detection 6 87R I_Alm 0 1 1 5 0 001 pu Setting of differential current abnormality alarm 7 87R En_Instant 0 disable 1 enable 1 Logic setting of enabling disabling unrestrained instantaneous differential protection 8 87R En_Biased 0 disable 1 enable 1 Logic setting of enabling disabling conventional biased differen...

Page 116: ...inputs for REF protection and the maximum current inputs applied for an auto transformer with two circuit breakers at HV and MV sides respectively Maximum 3 REF protections for each side of a three winding transformer Inrush current has no effect on REF protection RFE protection has high sensitivity to internal earth faults because there is no load current in the restraint current The tap of trans...

Page 117: ...ing an external earth fault HV side LV side 3I0Cal _H Magnitude compensation HV side REF Protection I _HNP I_H I_HNP Figure 3 4 1 REF application 1 for two winding transformer with one CB at one side LV side 3I0Cal _H1 Magnitude compensation HV side REF Protection Magnitude compensation 3I0Cal _H2 Magnitude compensation HV side 1 HV side 2 I _HNP I_HNP I_H1 I_H2 Figure 3 4 2 REF application 2 for ...

Page 118: ...ide of transformer I_HNP is primary value of neutral current of HV side I_CW is primary value of common winding neutral CT I _HNP and I _CW are respectively secondary value of neutral current of HV side and common winding neutral CT 3I0Cal _H 3I0Cal _H1 3I0Cal _H2 3I0Cal _M are respectively secondary values of calculated residual current from three phase current of each side of transformer 3 4 3 2...

Page 119: ...ted sides as the reference side If the multiple of the maximum CT primary ratio to the minimum CT primary rating is greater than 4 then reference side shall be taken as 4 and other sides shall be calculated proportionally Otherwise the reference side shall be taken as 1 and other sides will be calculated proportionally The currents used in the following analysis have been corrected that means the ...

Page 120: ... I I I are rated secondary values of CTs of each branch CTNP n I _ 2 is the rated secondary value of neutral CT NOTE Because the polarity of neutral CT is at transformer side current from neutral CT is subtracted in the differential current calculation The equation of calculating residual restraint current is max 0 04 03 02 01 0 NP r I I I I I I Equation 3 4 5 Where r I0 is the residual restraint ...

Page 121: ... I_NP 3I0Cal 3I0Cal 2x 3I0Cal I0r Max 3I0Cal I_HNP Max 3I0Cal 3I0Cal 3I0Cal Differential current 0Id are two times of restraint current I0r and corresponding to the total fault and restricted earth fault protection operates 3 4 3 5 Operation Criterion The operation criteria of REF protection are as follows NP 0 04 03 02 01 d 0 NP 0 04 03 02 01 r 0 r 0 d 0 r 0 d 0 I I I I I I I I I I I max I ased 6...

Page 122: ...re three branches constitute the REF protection of HV side and m is equal to 3 3 4 3 7 Detection of CT Transient Characteristic Difference Non identical CT characteristics can cause unbalance current During phase to phase faults and three phase faults the unbalance of three phase CTs results in residual current which may lead to maloperation of RFE protection Therefore positive sequence current re...

Page 123: ...ormality without the pickup of the fault detector of REF protection and differential CT circuit failure with the pickup of the fault detector pickup 3 4 3 9 1 CT Circuit Abnormality of REF Protection If the following operation formula is met for 10s CT circuit abnormality alarm of REF protection will be issued without blocking the protection The operation formula is as follows I 1 0 _Biased x 64RE...

Page 124: ...acteristic is detected Flg_CTS is the internal flag indicating CT circuit failure is distinguished Flg_CTSaturation is the internal flag indicating CT saturated 3I0Ext_H is the measured residual current of HV side FD_REF_HVS is the signal indicating that the fault detector of REF protection of HV side picks up For restricted earth fault protection if following three conditions are met the protecti...

Page 125: ...the input is 1 the protection is not reset and time delay will be cleared Table 3 4 2 Output signals of 64REF function block No Signal Description 1 St Restricted earth fault protection starts 2 Op Restricted earth fault protection operates 3 Alm_Diff Alarm message indicating CT secondary circuit of restricted earth fault protection abnormal 4 Alm_CTS Alarm message indicating that CT secondary cir...

Page 126: ...rected value of calculated residual current of x side branch m m 1 2 3 4 In 4 x 64REF I0_Corr_Neu Corrected value of current from neutral CT of x side In 5 x 64REF Ang 3I0 _Br1 Brm Angle of calculated residual current between x side branch 1 and branch m m 2 3 4 deg 6 x 64REF Ang 3I0 _Br1 Neu Angle between calculated residual current of HV side branch 1 and current from neutral CT of x side deg 7 ...

Page 127: ...al current of each side and common winding for the protection calculation and three phase CT polarity is easy to be checked The operation principle of which is similar to that of REF protection but compared to REF protection winding differential protection can operate not only during internal earth faults but also during phase to phase faults 3 5 2 Function Maximum 5 group CT inputs applied for an...

Page 128: ...tude compensation Winding differential protection Magnitude compensation I _H I _M CW side I_CW I_H I_M Figure 3 5 1 Winding differential protection applied to auto transformer HV side LV side Magnitude compensation Winding differential protection I _HBush Magnitude compensation Magnitude compensation HV side 1 HV side 2 I _H1 I _H2 I_H1 I_H1 I_Bush Figure 3 5 2 Winding differential protection use...

Page 129: ...l current 87W I_Biased is the pickup setting of winding differential protection 3 5 3 3 Amplitude Compensation If CTs used for winding differential protection have differential primary rated value then the current compensation is carried out in the program automatically with parameters input Following gives the criteria of calculating correction coefficient wb n n wph K I I K max _ 1 1 and 4 min m...

Page 130: ... I I I K I I I I I K I I I I I K I I I I Equation 3 5 3 The above equation can be simplified to the following 05 04 03 02 01 0 5 4 3 2 1 5 4 3 2 1 5 4 3 2 1 I I I I I I I I I I I I I I I I I I I I I I I I wd C C C C C wC B B B B B wdB A A A A A wdA Equation 3 5 4 Where wdA I wdB I wdC I 0 wd I are respectively three phase and residual winding differential currents n Cn Bn An I I I I 0 are respecti...

Page 131: ...ope S W I Knee I W I I_Biased T I Equation 3 5 6 Where 1 w I 5 w I are currents of five branches respectively wd I is winding differential current wr I is winding restraint current 87W I_Biased is the pickup value of biased winding differential protection 87W I_Knee is the setting of knee point of biased winding differential protection and 0 5In is recommended 87W Slope is the restraint coefficien...

Page 132: ... and m is equal to 3 3 5 3 7 CT Saturation Detection The CT saturation detection principle of winding differential protection is the same as that of current differential protection and please refer to Section 3 2 3 12 for details 3 5 3 8 CT Supervision for Winding Differential Protection 3 5 3 8 1 CT Circuit Abnormality of Winding Differential Protection If the following operation formula is met f...

Page 133: ...s satisfied Flg_CTS is the internal flag indicating CT circuit failure is distinguished Flg_CTSaturation is the internal flag indicating CT saturated FD_WdgDiff_HVS is the signal indicating that the fault detector of winding differential protection of HV side picks up For winding differential protection if following three conditions are met the protection will be enabled 1 Logic setting x 87W En i...

Page 134: ...t When the input is 1 the protection is not reset Table 3 5 2 Output signals of 87W function block No Signal Description 1 St Winding differential protection starts 2 Op_Phase Phase winding differential protection operates 3 Op_Residual Residual differential protection operates 4 Alm_Diff Alarm message indicating CT secondary circuit of winding differential protection abnormal 5 Alm_CTS Alarm mess...

Page 135: ...thra 87W Ithrb 87W Ithrc Thereshold of three phase restraint current of winding differential protection In 4 87W Ithr0 Thereshold of residual restraint current of residual differential protection In 5 87W Ia_Corr_Brm 87W Ib_Corr_Brm 87W Ic_Corr_Brm Corrected values of three phase current of winding differential protection of branch m n 1 2 3 4 5 In 6 87W I0_Corr_Brm Corrected value of residual dif...

Page 136: ...operation of the power system The inter turn fault is a common internal fault occurred in reactor but current differential protection cannot operate during inter turn faults Considering ground overcurrent protection cannot be taken as the fast protection for inter turn faults a dedicated protection for inter turn protection of reactor is needed to be equipped Inter turn faults in reactors present ...

Page 137: ...ng etc Residual power directional element and zero sequence impedance element are adopted to consist inter turn fault protection of reactor 3 6 3 2 Fault Detector The pickup of this fault detector DPFC inter turn fault detector will enable the inter turn fault differential protection and its operation equation is as follows 2 1 25 1 I I I I I I d dth dt d Equation 3 6 1 Where dt I is the floating ...

Page 138: ...F1 The fault point is zero sequence source the equivalent zero sequence network is shown below Zr2 U0 Fault PS Zs I0 Figure 3 6 2 Equivalent zero sequence network for case 1 Where Zs equivalent system impedance Zs Zr1 Zs1 ZL Zs2 U0 relay detected zero sequence voltage I0 relay detected zero sequence current FaultPS fault power source It is an external earth fault so viewing from reactor relay loca...

Page 139: ... 2 Where Zs equivalent system impedance Zs Zr1 Zs1 ZL Zs2 Zr1 1 impedance of Zr1 part 1 Zr1 2 impedance of Zr1 part 2 U0 relay detected zero sequence voltage I0 relay detected zero sequence current FaultPS fault power source It is an internal inter turn fault so viewing from reactor relay location zero sequence current flows from reactor to ground through system reactance Therefore the equation be...

Page 140: ... Equation 3 6 2 Where 0 0 3 3 I U are respectively calculated residual voltage and calculated residual current from VT and CT1 i e CT at the line side of reactor b Z is the zero sequence impedance of reactor including neutral earthing reactor i e IntTurn Z0 K is the floating coefficient adaptive to variation of zero sequence voltage and current from 0 to 0 8 3 6 3 4 Zero sequence Impedance Element...

Page 141: ...rn 0ms 500ms IntTurn St IntTurn Op Figure 3 6 6 Logic diagram of inter turn fault protection Where Flg_ZSImpedance is the internal flag indicating that zero sequence impedance element operates Flg_ResidPwrDir is the internal flag indicating that residual power directional element operates FD_DPFC_IntTurn is the internal flag indicating that DPFC inter turn fault detector operates Alm_CTS is the al...

Page 142: ... reset Table 3 6 2 Output signals of IntTurn function block No Signal Description 1 St Inter turn fault protection starts 2 Op Inter turn fault protection operates Above input signals and output signals can be used for programmable logic and following output signals are only for LCD display of equipment and oscillograph function Table 3 6 3 Output signals of IntTurn report No Signal Description 1 ...

Page 143: ...requency range for normal operation is 45 55Hz for 50Hz working frequency of power system and 55 65Hz for 60Hz working frequency of power system Overexcitation protection can be configured at any side of transformer through PCS Explorer and it is recommended to be equipped at the side without OLTC tap 3 7 2 Function Overexcitation protection has following functions Voltage for protection calculati...

Page 144: ...d out in the relay and users need not calculate the ratio of VT when configure settings Definite time operation criterion f U 24DTn k_Set Equation 3 7 2 Where f U is overexcitation multiple 24DTn k_Set is multiplier setting of stage n n 1 2 definite time overexcitation protection Stage 1 is for tripping and stage 2 for alarming Inverse time overexcitation protection realizes inverse time character...

Page 145: ...erexcitation condition disappears thermal accumulation value decreases to zero in 10s Overexcitation multiple comprises overexcitation information at current instant and also overexcitation information integrated over various time intervals from its beginning Inverse time characteristic curve can be specified by several overexcitation multiple settings and the relation between various settings of ...

Page 146: ...N 24IDMT En SIG 24IDMT Kn_Set f U IDMT IDMT 24IDMT Op 24IDMT Alm Figure 3 7 3 Logic diagram of inverse time overexcitation protection Where 24IDMT Kn_Set n 0 1 2 9 is the multiple setting of inverse time overexcitation For inverse time overexcitation protection when following three conditions are met the protection will be enabled 1 Logic setting 24IDMT En is set to 1 2 Enabling inputs 24IDMT En1 ...

Page 147: ...put 2 it can be binary inputs or settings such as function enabling binary inputs logic links etc 3 En2 4 Blk Function blocking input such as function blocking binary input If the input is 1 the protection is not reset and time delay will be cleared Table 3 7 2 Output signals of function block 24DT1 for trip No Signal Description 1 St Protection starts 2 Op Protection operates to trip Table 3 7 3 ...

Page 148: ...overexcitation alarm element starts 7 24IDMT St Inverse time overexcitation protection starts Start signals of protection element 8 24DT1 TrigDFR Definite time overexcitation protection picks up to trigger DFR function 9 24DTIDMT TrigDFR Inverse time overexcitation protection picks up to trigger DFR function Signals of protection element triggering DFR function recorded as IO events Table 3 7 6 Ou...

Page 149: ... 0 001 s Time delay setting of stage 2 definite time overexcitation protection for alarm 3 24DT2 En 0 disable 1 enable 1 Logic settings of enabling stage 2 definite time overexcitation protection for alarm Table 3 7 10 Settings of 24IDMT No Setting Item Range Step Unit Description 1 24IDMT K0_Set 1 0 1 7 0 001 Highest limit multiple setting of inverse time overexcitation protection n0 2 24IDMT t0_...

Page 150: ...99 0 001 s Time delay setting corresponding to multiple setting 8 t8 19 24IDMT K9_Set 1 0 1 7 0 001 Lowest limit multiple setting of inverse time overexcitation n9 20 24IDMT t9_Op 0 1 9999 0 001 s Time delay setting corresponding to lowest limit multiple setting t9 21 24IDMT K_Alm 0 5 0 99 0 001 Multiple setting of inverse time overexcitation protection for alarming 22 24IDMT En_Alm 0 disable 1 en...

Page 151: ...alanced 3 8 2 Function Underfrequency Protection In order to prevent possible maloperation of underfrequency protection in conditions of high harmonics voltage circuit failures and so on such blocking measures are carried out as follows a Blocking in undervoltage condition If the positive voltage U 0 15Un the calculation of protection is not carried out and the output relay will be blocked b df dt...

Page 152: ...on is as follows f 81U f_Pkp Equation 3 8 1 Where f is the measured system frequency 81U f_Pkp is the frequency pickup settings of underfrequency protection Fault detector of overfrequency protection The pickup of this fault detector will enable overfrequency protection which operation criterion is as follows f 81O f_Pkp Equation 3 8 2 Where f is the measured system frequency 81O f_Pkp is the freq...

Page 153: ...Fx En_df dt_Blk x 1 2 3 or 4 is set as 1 when Equation 3 8 3 and Equation 3 8 4 are met it is decided that a fault occurred and the corresponding stage underfrequency protection is blocked at the same time for the purpose of waiting for operation of other related protection The blocking signal will not reset until the system frequency recovers i e the system frequency is greater than the setting 8...

Page 154: ...re 3 8 1 Logic diagram of underfrequency protection Where fmin and fmax are respectively settings f_Low_FreqAlm and f_High_FreqAlm x In_VT is the input signal indicating that VT of x side in service x represents some side such as HVS MVS etc The signal can be configured as a binary input according to user requirements and if the binary input is not configured the default value of the signal is 1 F...

Page 155: ...Set SIG Flg_En81O SIG Flg_Blk81O EN 81O OF1 En EN 81O OF2 En EN 81O OF3 En EN 81O OF4 En Flg_Blk81O OTH U1 0 15Un SIG f fmin or f fmax SIG x In_VT 1 Figure 3 8 2 Logic diagram of overfrequency protection Where Flg_En81O is the internal signal to enable overfrequency protection Flg_Blk81O is the internal signal to block overfrequency protection For overfrequency protection when following three cond...

Page 156: ...n enabling binary inputs logic links etc 4 En2 5 Blk Function blocking input such as function blocking binary input If the input is 1 the protection is not reset and time delay will be cleared Table 3 8 2 Output signals of 81U function block No Signal Description 1 St Overfrequency protection starts 2 UF1 Op Overfrequency protection stage 1 operates 3 UF2 Op Overfrequency protection stage 2 operat...

Page 157: ... Overfrequency protection stage 4 operates Tripping reports of protection element 9 81U St Underfrequency protection starts 10 81O St Overfrequency protection starts Start signals of protection element 11 81U TrigDFR Underfrequency protection picks up to trigger DFR function 12 81O TrigDFR Overfrequency protection picks up to trigger DFR function Signals of protection element triggering DFR functi...

Page 158: ...Time delay of OF stage 4 16 81O OF4 En 0 disable 1 enable Logic setting of enabling disabling stage 4 of overfrequency protection 17 81O OF4 OutMap 0000 FFFF Tripping logic setting of stage 4 of overfrequency protection 18 81U f_Pkp 40 60Hz 0 01 Hz Pickup setting of underfrequency protection 19 81U df dt_Blk 0 05 20 0 01 Hz s Setting of df dt blocking underfrequency protection 20 81U UF1 f_Set 45 ...

Page 159: ...UF3 OutMap 0000 FFFF Tripping logic setting of stage 3 of underfrequency protection 35 81U UF4 f_Set 45 60 0 01 Hz Frequency setting of stage 4 of underfrequency protection 36 81U UF4 t_Op 0 1 6000 0 001 s Time delay of stage 4 of underfrequency protection 37 81U UF4 En 0 disable 1 enable Logic setting of enabling disabling stage 4 of underfrequency 38 81U UF4 En_df dt_Blk 0 disable 1 enable Logic...

Page 160: ...opto coupler circuits After CPU receives those signals transformer relay will record them as events and send tripping command with settable time delays Because the drop out time of mechanical input signals is usually too long the setting MR t_PW_n n 1 2 3 and 4 can be set to avoid the relay sending long time tripping command 3 9 4 Logic EN MR En_n SIG MR En1 SIG MR En2 SIG MR Blk SIG MR Inputn MR ...

Page 161: ...s function blocking binary input If the input is 1 the protection is not reset and time delay will be cleared Table 3 9 2 Output signals of function block MR No Signal Description 1 Sig1 Output signal of repeating MR signal input 1 2 Sig2 Output signal of repeating MR signal input 2 3 Sig3 Output signal of repeating MR signal input 3 4 Sig4 Output signal of repeating MR signal input 4 5 Op1 MR1 me...

Page 162: ...e Logic setting of enabling MR1 mechanical protection 4 MR OutMap_1 0000 FFFF Tripping logic setting of enabling MR1 mechanical protection 5 MR t_DPU_2 0 3600 0 001 s Delay pickup time of tripping command of MR2 mechanical protection 6 MR t_PW_2 0 10 0 001 s Pulse width of tripping command of MR2 mechanical protection 7 MR En_2 0 disable 1 enable Logic setting of enabling MR2 mechanical protection...

Page 163: ...nputs between 0 4mA DC can also be processed and all the analog inputs between 0 4mA DC will be processed as 4mA Therefore 0 20mA analog DC input can be processed 3 10 3 Protection Principle The protection device can receive signals from external temperature transducers and convert these signals into digital data as required via DC analog input module NR1410B The actual operation temperature of a ...

Page 164: ...e values of transformer corresponding to three transducer inputs is greater than the setting for tripping temperature alarm element operate to issue the related alarm signal The operation criterion is as follows T 26 T_Alm Equation 3 10 3 Where T is maximum value among three phase temperature values of transformer corresponding to three transducer inputs 26 T_Alm is the temperature setting for ala...

Page 165: ...l transducer 3 In_PhC DC input signal of phase C from external transducer 4 En1 Function enabling input1 and input 2 it can be binary inputs or settings such as function enabling binary inputs logic links etc 5 En2 6 Blk Function blocking input such as function blocking binary input If the input is 1 the protection is not reset and time delay will be cleared Table 3 10 2 Output signals of function...

Page 166: ...se C signal from transducer input Measured values for LCD display 3 10 6 Settings Table 3 10 5 Settings of 26 No Setting Item Range Step Unit Description 1 Tmax_Transducer 100 1000 0 01 C Maximum temperature setting corresponding to the maximum input of transducer 2 Tmin_Transducer 100 1000 0 01 C Minimum temperature setting corresponding to the minimum input of transducer 3 26 T_Trp 1000 1000 0 0...

Page 167: ...verview Impedance protection consists of phase to phase impedance protection and phase to earth protection CT polarity of each side is at busbar side and directions of settings are based on this polarity 3 11 3 2 Fault Detector The fault detector of impedance protection includes the fault detector of DPFC phase to phase current and the fault detector of negative sequence current Impendence protect...

Page 168: ...ting characteristic of phase to phase impedance relay with relay characteristic angle RCA 21 RCA i e m shown in the following figure also called reach angle In this figure Zn is the reverse impedance setting x 21 ZP1 2 Z_Fwd pointing to system direction and Zp is the forward impedance setting x 21 ZP1 2 Z_Rev pointing to transformer direction p Z jx R m n Z Figure 3 11 1 Operating characteristic o...

Page 169: ...etting x 21 K0 and recommended value is 0 2 k is generally 0 6 if protection direction points to local busbar and k is 0 0 1 if protection direction points to transformer 3 11 3 5 Power Swing Blocking Releasing PSBR PCS 978 adopts releasing power swing blocking to avoid maloperation of distance protection resulting from power swing In another word in order to avoid unwanted operation of impedance ...

Page 170: ... detectors of impedance protection picks up but the duration of keeping operating is less than 10ms I1 21 I_OC_PSBR Equation 3 11 6 Where I1 and 21 I_OC_PSBR please refer to above descriptions 2 Unsymmetrical fault PSBR element The operation criterion 1 2 0 I m I I Equation 3 11 7 Where m is the internal fixed coefficient which can ensure UF PSBR operate during power swing with an internal unsymme...

Page 171: ...s 1 When N OS N U U U 08 0 03 0 the SF PSBR element will operate after 150ms 2 When N OS N U U U 25 0 1 0 the SF PSBR element will operate after 500ms NOTE If time delay of impedance protection is more than 1 5 s PSBR function is not needed for the impedance protection 3 11 4 Logic The logic of phase to earth impedance protection is same to that of phase to phase impedance protection and stage 1 o...

Page 172: ... PSBR element picks up Flg_Pkp_FDPSBR is the internal flag indicating that fault detector PSBR element picks up FD_Z_x is the operation flag of the fault detector of DPFC phase to phase current or that of negative sequence current of x side Flg_Pkp_PSB is the internal flag indicating that power swing blocking releasing element picks up x Alm_VTS is the alarm message indicating voltage transformer ...

Page 173: ...ry inputs or settings such as function enabling binary inputs logic links etc 4 En2 5 Blk Function blocking input such as function blocking binary input If the input is 1 the protection is not reset and time delay will be cleared Table 3 11 2 Output signals of function block 21 No Signal Description 1 St Impedance protection starts 2 ZP1 Op Stage 1 of phase to phase impedance protection operates 3...

Page 174: ...ce protection of x side picks up to trigger DFR function Signals of protection element triggering DFR function recorded as IO events 3 11 6 Settings Table 3 11 4 Setting list of 21 No Setting Item Range Step Unit Description 1 x 21 RCA 1 89 0 01 deg Relay characteristic angle also called reach angle 2 x 21 I_OC_PSBR 0 04 150 0 001 A Current setting of PSBR element 3 x 21 En_PSBR 0 1 0 disable 1 en...

Page 175: ...on 20 x 21 ZG2 Z_Fwd 0 05 200 0 01 Ω Forward impedance setting of stage 2 of phase to earht impedance protection 21 x 21 ZG2 Z_Rev 100 1000 0 01 Ω Reverse impedance setting of stage 2 of phase to earth impedance protection 22 x 21 ZG2 t_Op 0 05 20 0 001 s Time delay of stage 2 of phase to earth impedance protection 23 x 21 ZG2 En 0 disable 1 enable 1 Logic setting of enabling disabling stage 2 of ...

Page 176: ... element can be selected to control each stage phase overcurrent protection Directional element can be selected to control each stage phase overcurrent protection with three options no direction forward direction and reverse direction Second harmonic can be selected to block each stage phase overcurrent protection 3 12 3 Protection Principle 3 12 3 1 Overview Phase overcurrent protection consists ...

Page 177: ...t setting of stage n n 1 2 3 or 4 of phase overcurrent protection of x side If any phase current is greater than the setting of any stage enabled phase overcurrent protection the stage phase overcurrent protection will operate after time delay if voltage control element operates or voltage control element not enabled directional element operates or directional element not enabled and the stage pro...

Page 178: ...n x 51P4 Opt_Curve Time Characteristic K α C 0 Definite time 1 IEC Normal inverse 0 14 0 02 0 2 IEC Very inverse 13 5 1 0 0 3 IEC Extremely inverse 80 0 2 0 0 4 IEC Short time inverse 0 05 0 04 0 5 IEC Long time inverse 120 0 1 0 0 6 ANSI Extremely inverse 28 2 2 0 0 1217 7 ANSI Very inverse 19 61 2 0 0 491 8 ANSI Inverse 0 0086 0 02 0 0185 9 ANSI Moderately inverse 0 0515 0 02 0 114 10 ANSI Long ...

Page 179: ... setting or negative sequence voltage is greater than its setting Criteria U x 50 51P Upp_VCE or 2 U x 50 51P U2_VCE Equation 3 2 3 Where U is the phase to phase voltage of x side 2 U is the negative sequence voltage of x side x 50 51P Upp_VCE is the phase to phase undervoltage setting of x side x 50 51P U2_VCE is the negative sequence overvoltage setting of x side Voltage of any side can be used ...

Page 180: ...t is less than current threshold neither of forward and reverse directions is met When a fault occurs at forward direction the angle between polarizing voltage ref U and fault current dir I is I U dir ref k arg Equation 3 12 3 When a fault occurs at reverse direction the angle is Relay characteristic angle sen setting x 50 51P RCA i e the angle polarizing voltage leading fault current is given as ...

Page 181: ...y and directional phase overcurrent is blocked and if the setting is set to 0 then directional element picks up automatically and directional phase overcurrent becomes non directional ground overcurrent protection 3 12 3 6 Harmonic Blocking Element When phase overcurrent protection is set to protect transformer during transformer energization in order to prevent inrush current leading to maloperat...

Page 182: ...blocking coefficient and recommended value is 0 15 If fundamental component of any phase current is lower than the minimum operating current 0 04In then harmonic calculation is not carried out and harmonic blocking element does not operate 3 12 4 Logic Logic diagram of phase overcurrent is shown in the following figure including phase overcurrent element voltage control element and directional ele...

Page 183: ...k 1 SET x 50 51Pn Opt_Dir SIG x 50 51Pn I3P SET 50 51Pn En_Hm2_Blk SIG Sig_U2 or Sig_Upp x 50 51Pn St x 50 51Pn Op Figure 3 12 4 Logic Diagram of phase overcurrent protection of x side 50 51Pn n 1 2 3 4 SIG 50 51Pn En SIG 50 51Pn Blk SIG x Alm_VTS SET x 50 51P Upp_VCE EN x 50 51P En_VTS_Blk 1 U Sig_Upp Figure 3 12 5 Logic Diagram of phase to phase VCE SIG 50 51Pn En SIG 50 51Pn Blk SIG x Alm_VTS S...

Page 184: ...ion block is disabled 50 51Pn St 50 51Pn Op signals are both reset Default values of Inputs 50 51Pn En1 50 51Pn En2 are 1 and 50 51Pn Blk is 0 when those inputs are not connected to external signals or settings 3 12 5 Inputs and Outputs 50 51P I3P U3P En1 En2 Blk St Op Figure 3 12 7 Function block 50 51P Each stage Table 3 12 4 Input signals of function block 50 51P Each stage No Signal Descriptio...

Page 185: ...ion stage 4 of x side operates Tripping reports of protection element 5 x 50 51P1 St Phase overcurrent protection stage 1 of x side starts 6 x 50 51P2 St Phase overcurrent protection stage 2 of x side starts 7 x 50 51P3 St Phase overcurrent protection stage 3 of x side starts 8 x 50 51P4 St Phase overcurrent protection stage 4 of x side starts Start signals of protection element 9 x 50 51P1 TrigDF...

Page 186: ...tem Range Step Unit Description 1 x 50 51Pn I_Set 0 04A 30In 0 001 A Current setting of stage n of phase overcurrent protection 2 x 50 51Pn t_Op 0 3600 0 001 s Time delay of stage n of phase overcurrent protection 3 x 50 51Pn En_VCE 0 disable 1 enable Logic setting of enabling voltage control element for phase overcurrent protection 4 x 50 51Pn Opt_Dir 0 2 1 Logic setting of selecting control mode...

Page 187: ...Please refer to Section 3 12 3 3 for details 10 x 50 51P4 En_VCE 0 disable 1 enable 1 Logic setting of enabling voltage control element for phase overcurrent protection 11 x 50 51P4 Opt_Dir 0 2 1 Logic setting of selecting control mode of directional element to stage 4 of phase overcurrent protection 0 no direction 1 forward direction 2 reverse direction 12 x 50 51P4 En_Hm2_Blk 0 disable 1 enable ...

Page 188: ...ection with independent logic current and time delay settings Stage 1 stage 2 and stage 3 are definite time characteristic stage 4 can be selected as definite time or inverse time characteristic The inverse time characteristic is selectable among IEC and ANSI IEEE standard inverse time characteristics and a user defined inverse time curve Directional element can be selected to control each stage g...

Page 189: ...ng x 50 51Gn Opt_3I0 n n 1 2 or 3 or x 50 51G4 Opt_3I0 x 50 51Gn 3I0_Set is the current setting of stage n n 1 2 or 3 of ground overcurrent protection of x side If ground current is greater than the setting of any stage enabled ground overcurrent protection the stage ground overcurrent protection will operate after time delay if directional element operates or directional element not enabled and n...

Page 190: ...ing table Table 3 13 1 Inverse time curve parameters of stage 4 ground overcurrent protection x 50 51G4 Opt_Curve Time Characteristic K α C 0 Definite time 1 IEC Normal inverse 0 14 0 02 0 2 IEC Very inverse 13 5 1 0 0 3 IEC Extremely inverse 80 0 2 0 0 4 IEC Short time inverse 0 05 0 04 0 5 IEC Long time inverse 120 0 1 0 0 6 ANSI Extremely inverse 28 2 2 0 0 1217 7 ANSI Very inverse 19 61 2 0 0 ...

Page 191: ... is the operating quantity When a fault occurs at forward direction the angle polarizing voltage ref U leading fault current dir I is I U dir ref k arg Equation 3 13 3 When a fault occurs at reverse direction the angle is Relay characteristic angle sen setting x 50 51G RCA i e the angle polarizing voltage leading fault current is given as the directional setting and the forward operating range is ...

Page 192: ...ional ground overcurrent protection 3 13 3 5 Harmonic Blocking Element In order to prevent effects of sympathetic inrush current on ground overcurrent relay harmonics blocking function can be selected for every stage of this relay When the percent of second harmonic to fundamental component of zero sequence current is greater than setting x 50 51G K_Hm2 harmonic blocking element operates to block ...

Page 193: ...tage are same except that stage 4 can be selected as inverse time characteristic and that stage 4 is taken as an example to show the logic Timer t t Direction Check 2nd Hm Detect Fwd Rev Non Dir Inverse for ROC4 only EN x 50 51Gn En SIG SIG SIG SIG x 50 51Gn I3P I1P SET SIG SIG SET 1 SET SIG SET x 50 51Gn En1 x 50 51Gn En2 x 50 51Gn Blk x 50 51Gn I_Set x 50 51G U3P x 50 51Gn Opt_Dir x Alm_VTS x 50...

Page 194: ...phase current data including calculated residual current 2 I1P Measured neutral current data 3 U3P Three phase voltage data including calculated residual voltage 4 En1 Function enabling input1 and input 2 it can be binary inputs or settings such as function enabling binary inputs logic links etc 5 En2 6 Blk Function blocking input such as function blocking binary input If the input is 1 the protec...

Page 195: ...protection stage 3 of x side picks up to trigger DFR function 12 x 50 51G4 TrigDFR Ground overcurrent protection stage 4 of x side picks up to trigger DFR function Signals of protection element triggering DFR function recorded as IO events 3 13 6 Settings Table 3 13 5 Setting list of control and blocking elements of 50 51G No Setting Item Range Step Unit Description 1 x 50 51G RCA 0 360 1 deg Rela...

Page 196: ...3I0_Set 0 04A 30In 0 001 A Pickup setting of stage 4 of ground overcurrent protection 2 x 50 51G4 K_3I0set 10 40 0 001 Multiplier of the maximum operating residual current to the pickup setting of stage 4 of ground overcurrent protection 3 x 50 51G4 t_Op 0 3600 0 001 s Time delay of stage 4 of ground overcurrent protection 4 x 50 51G4 TMS 0 05 3 2 0 001 Time multiplier setting of stage 4 of ground...

Page 197: ...an be set according to requirements If the current is greater than x 50 51G4 K_3I0set x x 50 51G4 3I0_Set the operating time of IDMT becomes flat i e the operating time is equal to the operating time of IDMT at the point residual current equal to x 50 51G4 K_3I0set x x 50 51G4 3I0_Set If x 50 51G4 tmin is not set to 0 then maximum operating current is not valid and users only can set the setting x...

Page 198: ...re 2 I is negative sequence current of x side x 50 51Q1 3I0_Set is the current setting of stage 1 of negative sequence overcurrent protection of x side If negative sequence current is greater than the setting of the stage enabled negative sequence overcurrent protection the stage protection will operate after time delay and the stage protection will drop off instantaneously after fault current dis...

Page 199: ...nverse 0 0086 0 02 0 0185 9 ANSI Moderately inverse 0 0515 0 02 0 114 10 ANSI Long time extremely inverse 64 07 2 0 0 25 11 ANSI Long time very inverse 28 55 2 0 0 712 12 ANSI Long time inverse 0 086 0 02 0 185 13 Programmable User defined If all available curves do not comply with user application user may configure setting x 50 51Q2 Opt_Curve to 13 to customize the inverse time curve characteris...

Page 200: ...isabled x 50 51Qn St x 50 51Qn Op signals are both reset Default values of inputs x 50 51Qn En1 and x 50 51Qn En2 are 1 and x 50 51Qn Blk is 0 when those inputs are not connected to external signals or settings 3 14 5 Inputs and Outputs Each stage negative sequence overcurrent protection has the identical function block shown as follows 50 51Q I3P En1 En2 Blk St Op Figure 3 14 2 Function block 50 ...

Page 201: ...50 51Q1 St Negative sequence overcurrent protection stage 1 of x side starts 4 x 50 51Q2 St Negative sequence overcurrent protection stage 2 of x side starts Start signals of protection element 5 x 50 51Q1 TrigDFR Ground overcurrent protection stage 1 of x side picks up to trigger DFR function 6 x 50 51Q2 TrigDFR Ground overcurrent protection stage 2 of x side picks up to trigger DFR function Sign...

Page 202: ... overcurrent protection 8 x 50 51Q2 Alpha 0 02 5 0 001 The exponent alpha of stage 2 of negative sequence overcurrent protection 9 x 50 51Q2 Opt_Curve 0 13 1 Logic setting for selecting operating characteristic curve of stage 2 of negative sequence overcurrent protection Please refer to Section 3 14 3 2 for details 10 x 50 51Q2 En 0 disable 1 enable 1 Logic setting of enabling stage 2 of negative ...

Page 203: ...verse time characteristics and a user defined inverse time curve Phase voltage or phase to phase voltage can be selected for protection calculation 1 out of 3 or 3 out of 3 logic can be selected for protection criterion 3 15 3 Protection Principle 3 15 3 1 Operation Criterion Users can select phase voltage or phase to phase voltage for the protection calculation If setting x 59Pn En_Vpp is set to ...

Page 204: ..._Set Equation 3 15 3 Set x 59Pn U_ U Set x 59Pn U_ U Set x 59Pn U_ U ca bc ab Equation 3 15 4 Where max _ U is the maximum value of phase to phase value of one side ab U bc U ca U are phase to phase voltages of one side x 59Pn U_Set is the setting of stage n n 1 or 2 overvoltage protection of the corresponding side When x 59Pn Opt_1P 3P is set as 0 1 out of 3 logic Equation 3 15 3 is selected as o...

Page 205: ...te time 1 IEC Normal inverse 0 14 0 02 0 2 IEC Very inverse 13 5 1 0 0 3 IEC Extremely inverse 80 0 2 0 0 4 IEC Short time inverse 0 05 0 04 0 5 IEC Long time inverse 120 0 1 0 0 6 ANSI Extremely inverse 28 2 2 0 0 1217 7 ANSI Very inverse 19 61 2 0 0 491 8 ANSI Inverse 0 0086 0 02 0 0185 9 ANSI Moderately inverse 0 0515 0 02 0 114 10 ANSI Long time extremely inverse 64 07 2 0 0 25 11 ANSI Long ti...

Page 206: ...e protective function block is disabled x 59Pn St x 59Pn Op signals are both reset Default values of Inputs x 59Pn En1 x 59Pn En2 are 1 and x 59Pn Blk is 0 when those inputs are not connected to external signals or settings 3 15 5 Inputs and Outputs 59P U3P En1 En2 Blk St Op Figure 3 15 2 Function block 59G Each stage Table 3 15 2 Input signals of function block 59G Each stage No Signal Descriptio...

Page 207: ...of x side starts 4 x 59P2 St Phase overvoltage protection stage 2 of x side starts Start signals of protection element 5 x 59P1 TrigDFR Phase overvoltage protection stage 1 of x side picks up to trigger DFR function 6 x 59P2 TrigDFR Phase overvoltage protection stage 2 of x side picks up to trigger DFR function Signals of protection element triggering DFR function recorded as IO events 3 15 6 Sett...

Page 208: ...logic for operation criterion of stage 2 of phase overvoltage protection 6 x 59P2 TMS 0 05 3 2 0 001 Time multiplier setting of stage 2 of phase overvoltage protection 7 x 59P2 tmin 0 20s 0 001 s Minimum delay of stage 2 of phase overvoltage protection 8 x 59P2 K 0 120 0 001 The constant K of stage 2 of phase overvoltage protection 9 x 59P2 C 0 20 0 001 s The constant C stage 2 of phase overvoltag...

Page 209: ...e and time delay settings Stage 1 is definite time characteristic stage 2 can be selected as definite time or inverse time characteristic The inverse time characteristic is selectable among IEC and ANSI IEEE standard inverse time characteristics and a user defined inverse time curve 3 16 3 Protection Principle 3 16 3 1 Operation Criterion 0 3U x 59Gn 3U0_Set Equation 3 16 1 Where 0 3U is measured ...

Page 210: ... the following table Table 3 16 1 Inverse time curve parameters of stage 2 residual overvoltage protection x 59G2 Opt_Curve Time Characteristic K α C 0 Definite time 1 IEC Normal inverse 0 14 0 02 0 2 IEC Very inverse 13 5 1 0 0 3 IEC Extremely inverse 80 0 2 0 0 4 IEC Short time inverse 0 05 0 04 0 5 IEC Long time inverse 120 0 1 0 0 6 ANSI Extremely inverse 28 2 2 0 0 1217 7 ANSI Very inverse 19...

Page 211: ...al overvoltage protection 59Gn n 1 2 For any stage residual overvoltage protection if following three conditions are met the stage protection will be enabled 1 Logic setting x 59Gn En is set to 1 2 Enabling inputs x 59Gn En1 x 59Gn En2 are both set to 1 3 Blocking input x 59Gn Blk is set to 0 When the protective function block is disabled x 59Gn St x 59Gn Op signals are both reset Default values o...

Page 212: ...ble 3 16 4 Output signals of 59G report No Signal Description 1 x 59G1 Op Residual overvoltage protection stage 1 of x side operates 2 x 59G2 Op Residual overvoltage protection stage 2 of x side operates Tripping reports of protection element 3 x 59G1 St Residual overvoltage protection stage 1 of x side starts 4 x 59G2 St Residual overvoltage protection stage 2 of x side starts Start signals of pr...

Page 213: ...min 0 20s 0 001 s Minimum delay of stage 2 of residual overvoltage protection 5 x 59G2 TMS 0 05 3 2 0 001 Time multiplier setting of stage 2 of residual overvoltage protection 6 x 59G2 K 0 0 120 0 001 The constant K of stage 2 of residual overvoltage protection 7 x 59G2 C 0 0 20 0 001 s The constant C stage 2 of residual overvoltage protection 8 x 59G2 Alpha 0 02 5 0 001 The exponent alpha stage 2...

Page 214: ...by the lack of system reactive power is almost symmetrical and does not change suddenly so the undervoltage protection adopts the positive sequence voltage for the protection calculation If negative sequence voltage is greater than 0 15Un or positive sequence voltage changes suddenly the undervoltage protection is blocked Undervoltage load shedding protection has the unique capability of fault dis...

Page 215: ...ndervoltage caused by abnormality contestations such as load back feed higher harmonics circuit connection etc following blocking criteria are equipped 1 Undervoltage blocking If positive sequence voltage is lower than 0 15Un undervoltage protection is blocked 2 Negative sequence blocking If negative sequence voltage is greater than 0 15Un undervoltage is blocked 3 Rate of change of voltage blocki...

Page 216: ... t_Op 0ms x 27 St SIG x In_VT 1 Figure 3 17 1 Logic diagram of undervoltage protection Where U1 is the positive sequence voltage x In_VT is the input signal indicating that VT of x side in service x represents some side such as HVS MVS etc The signal can be configured as a binary input according to user requirements and if the binary input is not configured the default value of the signal is 1 Flg...

Page 217: ...is not reset and time delay will be cleared Table 3 17 2 Output signals of function block 27 No Signal Description 1 St Undervoltage protection starts 2 UV1 Op Stage 1 undervoltage protection operates 3 UV2 Op Stage 2 undervoltage protection operates 4 UV3 Op Stage 3 undervoltage protection operates 5 UV4 Op Stage 4 undervoltage protection operates 6 Alm_Unrecov Alarm signal indicating that the vo...

Page 218: ... x 27 UV1 En 0 disable 1 enable 1 Logic setting of enabling stage 1 of undervoltage protection 8 x 27 UV1 OutMap 0000 FFFF 1 Tripping logic setting of stage 1 of undervoltage protection 9 x 27 UV2 U_Set 0 100 0 001 V Voltage setting of stage 2 of undervoltage protection 10 x 27 UV2 t_Op 0 05 100 0 001 s Time delay of stage 2 of undervoltage protection 11 x 27 UV2 En_du dt_Blk 0 disable 1 enable 1 ...

Page 219: ... transformer oil The thermal overload protection estimates the internal heat content of the transformer temperature continuously This estimation is made by using a thermal model of the transformer with two time constants which is based on current measurement Two stages are available When the temperature increases to the alarm value the protection issues alarm signal to remind the operator for atte...

Page 220: ...current limit characteristic is given by the following equation 2 2 2 2 ln B eq p eq I k I I I t Equation 3 18 2 Where t is the theoretical operate time following application of the overload current is the heating thermal time constant of the protected equipment i e x 49 Tau eq I is the equivalent heating current i e actual measured current p I is the steady state load current prior to the overloa...

Page 221: ...l accumulation value is greater than the setting for alarm alarm output contacts which can be connected to block the auto recloser of a circuit breaker will operate 3 18 4 Logic Timer t t EN x 49 En_Alm SIG x 49 En1 SIG x 49 En2 SIG x 49 Blk SIG x 49 I3P SET x 49 Ib_Set Timer t t x 49 St x 49 Alm x 49 Op Figure 3 18 2 Logic diagram of thermal overload protection of x side For thermal overload prot...

Page 222: ...18 2 Output signals of function block 49 No Signal Description 1 St Protection starts 2 Op Protection operates 3 Alm Protection issues alarm signal Above input signals and output signals can be used for programmable logic and following output signals are only for LCD display of equipment NOTE Symbol x represents some side of transformer defined by user through PCS Explorer software which may be H ...

Page 223: ...ttings Table 3 18 5 Setting list of 49 No Setting Item Range Step Unit Description 1 x 49 K_Trp 1 3 0 001 Setting of thermal capacity for tripping 2 x 49 K_Alm 1 3 0 001 Setting of thermal capacity for alarming 3 x 49 Ib_Set 0 04A 30In 0 001 A Base current setting 4 x 49 Tau 0 1 100 0 001 min Thermal time constant 5 x 49 En_Trp 0 disable 1 enable 1 Logic setting of enabling tripping function 6 x 4...

Page 224: ... current criterion 3I0 x 50BF 3I0_Set Equation 3 19 2 Where 3I0 is three times calculated zero sequence current of some side x 50BF 3I0_Set is zero sequence current of breaker failure protection of the corresponding side 3 Negative sequence current criterion I2 x 50BF I2_Set Equation 3 19 3 Where I2 is negative sequence current of some side x 50BF I2_Set is negative sequence current of breaker fai...

Page 225: ...Init SIG FD_BFP_x x 50BF t1_Op 0ms x 50BF St x 50BF Op_t1 Figure 3 19 1 Logic diagram of breaker failure protection of x side Where x repents some side of transformer may be HVS MVS or LVS In is rated secondary current of CT max _ I is the maximum value of three phase current of x side 3I0 is calculated residual current of x side I2 is negative sequence current of x side FD_BFP_x is the operation ...

Page 226: ...4 En2 5 Blk Function blocking input such as function blocking binary input If the input is 1 the protection is not reset and time delay will be cleared Table 3 19 2 Output signals of function block 50BF No Signal Description 1 St Breaker failure protection starts 2 Op_t1 Delay 1 of breaker failure protection operates 3 Op_t2 Delay 2 of breaker failure protection operates 4 Alm_Init Alarm message i...

Page 227: ...001 A Current setting of phase current criterion 2 x 50BF 3I0_Set 0 04A 30In 0 001 A Current setting of residual current criterion 3 x 50BF I2_Set 0 04A 30In 0 001 A Current setting of negative sequence current criterion 4 x 50BF En_Ip 0 disable 1 enable 1 Logic setting of enabling disabling phase current criterion to control breaker failure protection 5 x 50BF En_I2 0 disable 1 enable 1 Logic set...

Page 228: ...disagreement fault is detected after a certain delay the transformer relay will initiate a trip command to trip all poles of the switching equipment 3 20 2 Protection Principle Initiate signal Input signal of pole disagreement position 62PD In_PD_CB is used to initiate pole disagreement protection Current control element There are two current control elements for pole disagreement protection resid...

Page 229: ... En1 En2 Blk St Op Alm Figure 3 20 2 Function block 62PD Table 3 20 1 Input signals of function block 62PD No Signal Description 1 I3P Three phase current data including calculated residual current 2 In_PD_CB Input signal of indicating pole disagreement state of a circuit breaker 3 En1 Function enabling input1 and input 2 it can be binary inputs or settings such as function enabling binary inputs ...

Page 230: ... 20 4 Setting list of pole disagreement protection No Setting Item Range Step Unit Description 1 x 62PD 3I0_Set 0 04A 30In 0 001 A Current setting of residual current criterion 2 x 62PD I2_Set 0 04A 30In 0 001 A Current setting of negative sequence current criterion 3 x 62PD t_Op 0 20 0 001 s Time delay of pole disagreement protection for tripping 4 x 62PD t_Alm 0 20 0 001 s Time delay of breaker ...

Page 231: ...se overcurrent alarm element has following functions Two stage definite time phase overcurrent alarm element with independent logic current and time delay settings Outputs of phase overcurrent alarm element only applied for alarm signals Fundamental current or 1st to 7th harmonic current is used for protection calculation Drop off coefficient of phase overcurrent alarm element is settable NOTE Use...

Page 232: ...x 59Almn Alm and x 59Almn Op signals are both reset Default values of Inputs x 59Almn En1 and x 59Almn En2 are 1 and x 59Almn Blk is 0 when those inputs are not connected to external signals or settings 3 21 5 Inputs and Outputs 50PAlm I3P En1 En2 Blk St Alm Figure 3 21 2 Function block 50PAlm each stage Table 3 21 1 Input signals of function block 50PAlm each stage No Signal Description 1 I3P Thr...

Page 233: ...n element 3 x 50PAlm1 St Phase overcurrent alarm stage 1 of x side starts 4 x 50PAlm2 St Phase overcurrent alarm stage 2 of x side starts Start signals of protection element 3 21 6 Settings Table 3 21 4 Setting list of 50PAlm stage n n 1 2 No Setting Item Range Step Unit Description 1 x 50PAlmn I_Set 0 04A 30In 0 001 A Current setting of stage n of phase overcurrent alarm element 2 x 50PAlmn t_Op ...

Page 234: ...f instantaneously after fault voltage disappears 3 22 4 Logic EN x 59GAlm En SIG x 59GAlm En1 SIG x 59GAlm En2 SIG x 59GAlm Blk SIG x 59GAlm U3P U1P SET x 59GAlm U_Set x 59GAlm t_Op 0ms x 59GAlm St x 59GAlm Alm Figure 3 22 1 Logic diagram of residual overvoltage alarm element 59GAlm For residual overvoltage alarm element if following three conditions are met the stage alarm element will be enabled...

Page 235: ...lay will be cleared Table 3 22 2 Output signals of 59GAlm No Signal Description 1 Alm Alarm element operates 2 St Alarm element starts Above input signals and output signals can be used for programmable logic and following output signals are only for LCD display of equipment NOTE Symbol x represents some side of transformer defined by user through PCS Explorer software which may be H HV HVS HVS1 H...

Page 236: ...se current element is for the protection logic calculation 3 23 2 Function Three phase current element has following functions Pre process three phase currents Calculate information related to three phase current Monitor the secondary circuit of current including CT circuit abnormality and CT circuit failure 3 23 3 Principle CT circuit abnormality supervision If any one of the following two criter...

Page 237: ...G Ic 0 04In 1 AlmL_CTS OnLoad Figure 3 23 1 Current pre processing logic diagram Where Ia Ib and Ic are sampled three phase current values 3I0 is calculated residual current I2 is the negative sequence current 3 23 5 Inputs and Outputs Curr3P ia ib ic I3P Ang Ia Ang Ib Ang Ic AlmL_CTS AlmH_CTS OnLoad Figure 3 23 2 Function block Curr3P Table 3 23 1 Input signals of function block Curr3P No Signal ...

Page 238: ... HVS HVS1 HVS2 etc If only one protection element is equipped the prefix x may disappear Table 3 23 3 Output signals of Curr3P report No Signal Description 1 x AlmL_CTS Current transformer circuit of x side is abnormal 2 x AlmH_CTS Current transformer circuit of x side fails Alarm reports of equipment during operation Table 3 23 4 Output signals of Curr3P measurements No Signal Description 1 x Ua ...

Page 239: ...urrent value from neutral CT at neutral point of x side 27 x Ang Ua Ia Angle between phase A voltage and current of x side 28 x Ang Ub Ib Angle between phase B voltage and current of x side 29 x Ang Uc Ic Angle between phase C voltage and current of x side Path Main menu Measurements Measurements1 x Measurements Main menu Measurements Measurements2 x Measurements 3 23 6 Settings Table 3 23 5 Setti...

Page 240: ... to 100V 1 Positive sequence voltage is less than 30 V and any phase current is greater than 0 04 In 2 Positive sequence voltage is less than 30 V and the breaker is in closed position 3 The negative sequence voltage is greater than 8 V 4 The 3rd harmonic magnitude of phase voltage is greater than 10V If the secondary phase to phase rated voltage is set to 110V all corresponding operating voltage ...

Page 241: ...ice 6 OnLoad A flag indicating sampled current valid Table 3 24 2 Output signals of function block Volt3P No Signal Description 1 U3P A voltage data set 2 Ang Ua Phase angle of phase A voltage 3 Ang Ub Phase angle of phase B voltage 4 Ang Uc Phase angle of phase C voltage 5 Alm_VTS Alarm message of VT secondary circuit abnormality NOTE Symbol x represents some side of transformer defined by user t...

Page 242: ...al current etc All calculated information of three phase current element is for the protection logic calculation 3 25 2 Function Residual current element has following functions Pre process measured residual current Calculate information related to residual current 3 25 3 Inputs and Outputs Curr1P 3i0 I1P Ang 3I0 Figure 3 25 1 Function block Curr1P Table 3 25 1 Input signals of function block Curr...

Page 243: ... element is for the protection logic calculation 3 26 2 Function Residual voltage element has following functions Pre process measured residual voltage Calculate information related to voltage current 3 26 3 Inputs and Outputs Volt1P 3u0 U1P Ang 3U0 Figure 3 26 1 Function block Volt1P Table 3 26 1 Input signals of function block Volt1P No Signal Description 1 3u0 Measured residual voltage Table 3 ...

Page 244: ...fixed in program dwell time to ensure sufficient time of tripping command for CB opening 3 27 2 Output Map of Protection Element Each protection element has its corresponding tripping logic setting used to configure tripping output contacts of each element and total 10 groups of tripping output contacts can be controlled by tripping logic settings Therefore user can configure the tripping output c...

Page 245: ...presents Tripoutputxx xx 01 02 15 The bit corresponding to the breaker to be tripped shall be set as 1 and other bits shall be 0 For example if differential protection operates to make TrpOutput1 TrpOutput2 TrpOutput3 contacts pickup the bit 1 and bit 2 and bit 3 positions shall be filled with 1 and other bit positions shall be filled with 0 Then a hexadecimal number 0007H is formed as the trippin...

Page 246: ... 10 Input signals of programmable tripping output element 3 27 5 Settings Table 3 27 2 Setting list of programmable tripping output element No Setting Item Range Step 1 OutMap_ProgTrp01 0000 FFFF Setting of programmable tripping output element 1 2 OutMap_ProgTrp02 0000 FFFF Setting of programmable tripping output element 2 3 OutMap_ProgTrp03 0000 FFFF Setting of programmable tripping output elemen...

Page 247: ...ample Where HVS 50 51P1 Op is the operation flag of stage 1 of overcurrent protection of HV side LVS 50 51P1 Op is the operation flag of stage 1 of overcurrent protection of MV side Sig_Spare01 is the signal of intermediate variable 1 for logic programming LED10 is the programmable LED10 3 28 2 Inputs and Outputs The following signals of intermediate variable are used to transfer signals so they a...

Page 248: ...e variable 12 for logic programming 13 Sig_Spare13 Signal of intermediate variable 13 for logic programming 14 Sig_Spare14 Signal of intermediate variable 14 for logic programming 15 Sig_Spare15 Signal of intermediate variable 15 for logic programming 16 Sig_Spare16 Signal of intermediate variable 16 for logic programming 17 Sig_Spare17 Signal of intermediate variable 17 for logic programming 18 S...

Page 249: ...ware Configuration Supervision 4 2 4 3 Equipment Operation Supervision 4 2 4 3 1 Current Transformer Supervision CTS 4 2 4 3 2 Voltage Transformer Supervision VTS 4 6 4 3 3 Frequency Supervision 4 7 4 4 Failure and Abnormality Alarms 4 7 4 4 1 Hardware Self supervision Alarms 4 8 4 4 2 Equipment Operation Alarms 4 11 List of Tables Table 4 4 1 Description of equipment self check alarm message 4 8 ...

Page 250: ...4 Supervision PCS 978 Transformer Relay 4 b Date 2013 01 16 ...

Page 251: ...rinted 4 2 Relay Self supervision 4 2 1 Relay Hardware Supervision All chips on each module are monitored to ensure whether they are damaged or have errors If any one of them is detected damaged or having error the corresponding alarm signal ProtBrd Fail_DSP or FDBrd Fail_DSP is issued with equipment being blocked AC current and voltage samplings of protection DSP module and fault detector DSP mod...

Page 252: ...on if plug in module configuration is not consistent to the design drawing of an applied specific the alarm signal Fail_BoardConfig is issued with the equipment being blocked 4 3 Equipment Operation Supervision 4 3 1 Current Transformer Supervision CTS The CTS function will be always processed all the time which includes following two aspects The CTS logic in the relay is designed to detect the CT...

Page 253: ...s CT circuit abnormality alarm of winding differential protection will be issued without blocking the protection The operation criterion is as follows 1 0 _ 87 2 0 n wd I Biased I W Max I Equation 4 3 2 Where wd I is winding differential current 87W I_Biased is the pickup value of biased winding differential protection n I is the rated secondary current of CT 4 3 1 2 CT Circuit Abnormality of CT I...

Page 254: ... combined method of voltage and current 1 First case if none of following four conditions is satisfied after the fault detector of biased differential current or biased residual differential current or biased winding differential current picks up it will be judged as CT circuit failure and the CT circuit failure alarm 87T Alm_CTS 87R Alm_CTS 64REF Alm_CTS 87W Alm_CTS or x AlmH_CTS x represents som...

Page 255: ...mer sensitive biased differential protection is blocked 4 Reactor sensitive biased differential protection can be blocked when CT circuit failure is detected by configuring the logic setting 87R En_CTS_Blk If this logic setting is set as 0 reactor sensitive biased differential protection is not blocked If this logic setting is set as 1 reactor sensitive biased differential protection is blocked 5 ...

Page 256: ...CTS is the internal flag indicating that CT circuit failure is distinguished x AlmH_CTS is the alarm signal of CT circuit failure of x side of transformer 87T Alm_CTS is the alarm signal of CT circuit failure for current differential protection If CT circuit failure for REF protection or winding differential protection is detected the corresponding signal 64REF Alm_CTS or 87W Alm_CTS will be issue...

Page 257: ...Where Up_3rd is the 3rd harmonic value of phase voltage U2 and U1 are respectively negative sequence voltage value and positive sequence current value 52b is the binary input of auxiliary normally closed contact of a circuit breaker OnLoad is a flag indicating there is load current detected In_VT is the input signal of indicating VT in service Alm_VTS is the alarm message of VT secondary circuit a...

Page 258: ...l_SettingItem_Chgd After configuration file is updated settings of the file and settings saved on the device are not matched 5 ProtBrd Fail_Settings Error is found during checking settings on protection module 6 FDBrd Fail_Settings Error is found during checking settings on fault detector module 7 ProtBrd Fail_Memory Error is found during checking the memory data on protection module 8 FDBrd Fail_...

Page 259: ...r or reboot the equipment and the alarm message will disappear and the equipment will restore to normal operation state 3 Fail_BoardConfig Step 1 Go to the menu Information Board Info check the abnormality information Step 2 For the module with abnormality if the module is not used then remove and if the module is used then check whether the module is installed properly and work normally After the...

Page 260: ...treatment is needed Just wait the completion of communication test or exit the test 20 Alm_TimeSyn Step1 Check whether the selected clock synchronization mode matches the clock synchronization source Step 2 Check whether the wiring connection between the equipment and the clock synchronization source is correct Step 3 Check whether the setting for selecting clock synchronization i e Opt_TimeSyn is...

Page 261: ...h another one with greater memory NOTE If the equipment still cannot restore to normal operation state after suggested procedures please inform the manufacturer or the agent for maintenance 4 4 2 Equipment Operation Alarms During the equipment normal operation VT and CT circuit and some binary input circuits are always monitored by the relay If any abnormality of them occurs or any alarm element o...

Page 262: ...4 4 Troubleshooting for equipment operation alarm message No Item Description Alarm Signals Device is not blocked but the corresponding biased differential protection can be blocked by configuring the corresponding logic setting HEALTHY LED keeps being lit on ALARM LED is lit on 1 87T Alm_CTS Please check the corresponding CT secondary circuit After the abnormality is eliminated equipment can retu...

Page 263: ...Alarm Signals Device is not blocked HEALTHY LED keeps been lit on ALARM LED is not lit on but users can configure ALARM LED being lit on through PCS Explorer 16 x 50PAlm1 Alm Please treat according to the specific application requirements 17 x 50PAlm2 Alm 18 x 59GAlm Alm NOTE Symbol x represents some side of transformer defined by user through PCS Explorer software which may be H HV HVS HVS1 HVS2 ...

Page 264: ...4 Supervision PCS 978 Transformer Relay 4 14 Date 2013 01 16 ...

Page 265: ...ay 5 a Date 2013 01 16 5 Management Table of Contents 5 1 Overview 5 1 5 2 Measurement 5 1 5 3 Event fault Records 5 3 5 3 1 Introduction 5 3 5 3 2 Event Recording 5 3 5 3 3 Disturbance and Fault Recording 5 3 5 3 4 Present Recording 5 4 ...

Page 266: ...5 Management PCS 978 Transformer Relay 5 b Date 2013 01 16 ...

Page 267: ... value of 1st 7th harmonics is used for the protection calculation The calculation of other protection elements of the device is based on fundamental current or voltage amplitude and harmonic blocking function is selectable for some protections refer to Chapter 3 Operation Theory for details 1 RMS Value 1 Access path Press key to enter main menu firstly 2 Select the item Measurements and press key...

Page 268: ...n the LCD Angle between currents of each side Angle between voltages of each side Angle between voltage and current of each side Angle between corrected currents of each side for conventional current differential protection Angle between corrected currents of each REF protection Please refer to each protection element in the Chapter of Operation Theory for detailed sample value and phase angle 3 M...

Page 269: ...ly All the records are stored in non volatile memory and when the available space is exhausted the oldest report will be automatically overwritten by the latest one Abnormality alarm reports An abnormality alarm being detected during relay self check supervision or an alarm of secondary circuit abnormality or protection alarm element will also be logged as individual events Binary input status cha...

Page 270: ...lative time is the time when protection element operates to send tripping signal after fault detector picks up 3 Faulty phase The faulty phase detected by the operating element is showed in the record report 4 Trip mode This shows the protection element that issues the tripping command If no protection operates to trip but only equipment fault detector picks up fault report will record the title o...

Page 271: ...5 Management PCS 978 Transformer Relay 5 5 Date 2013 01 16 Each time recording includes 2 cycle waveform before triggering and up to 250 cycles can be recorded ...

Page 272: ...5 Management PCS 978 Transformer Relay 5 6 Date 2013 01 16 ...

Page 273: ...ule 2 Fault Detector Calculation 6 12 6 3 5 BI Module Binary Input 6 13 6 3 6 BO Module Binary Output 6 18 6 3 7 Mechanical Relay Modules Optional 6 23 6 3 8 AI Module Analog Input 6 24 6 3 9 NET DSP module Optional 6 49 6 3 10 HMI Module 6 49 6 4 Tripping Output Group 6 50 6 5 Output Contact 6 51 6 5 1 Tripping Output Contact 6 51 6 5 2 Signal Output Contact 6 51 6 6 Typical Configuration 6 52 6 ...

Page 274: ...n 2 6 28 Figure 6 3 12 CT VT connection for typical application 3 6 30 Figure 6 3 13 CT VT connection for typical application 4 6 32 Figure 6 3 14 CT VT connection for typical application 5 6 34 Figure 6 3 15 CT VT connection for typical application 6 6 37 Figure 6 3 16 CT VT connection for typical application 7 6 40 Figure 6 3 17 CT VT connection for tyipical application 8 6 43 Figure 6 3 18 Pin ...

Page 275: ...d by AD for protection calculation and fault detector respectively When DSP module completes all the protection calculation the result will be sent to 32 bit CPU on MON module to be recorded Protection DSP module carries out protection logic calculation tripping output and MON module completes SOE sequence of event record waveform recording printing communication between protection and SAS and com...

Page 276: ...tage to low voltage signals with current transformers and voltage transformers respectively BI module provides binary input via opto couplers with rating voltage among 24V 48V 110V 125V 220V 250V opto coupler configurable BO trip module provides all tripping outputs BO signal module provides all kinds of signal output contact including annunciation signal remote signal fault and disturbance signal...

Page 277: ...L BO_ALM BO_COM2 OPTO PWR PWR GND BO_FAIL 5V ALM BO_ALM BO_FAIL OK ON OFF ETHERNET NR1102M Figure 6 1 3 Typical rear view of PCS 978 6 2 Typical Wiring 6 2 1 Conventional CT VT Wiring Typical configuration of PCS 978 connected to conventional CT VT configuration is given as below for reference MON module DSP module 1 DSP module 2 PWR module AC AI module 1 AC AI module 2 BI module BO module 1 for t...

Page 278: ...Uc Three phase voltage 0613 0617 0615 0614 0616 0618 Ua Ub Uc Three phase voltage 0607 0608 3I0 Neutral current 0609 0610 0611 0612 Three phase current Three phase current Three phase current A B C CB3 HV side CB1 MV side CB2 LV side A B C A B C BO_Trp_2 2 BO_Trp_3 1 BO_Trp_3 2 BO_Trp_4 1 BO_Trp_4 2 BO_Trp_5 1 BO_Trp_5 2 BO_Trp_6 1 BO_Trp_6 2 BO_Trp_6 3 BO_Trp_7 1 BO module 2 for trip BO_Trp_7 2 B...

Page 279: ...1 13 12 NR1102 BI MON NR1504 NR1521 BO NR1521 BO 06 10 11 14 15 NR1523B BO Slot No Module ID DSP NR1156 AI NR1401 NR1156 DSP AI NR1401 6 2 2 ECT EVT Wiring Typical configuration of PCS 978 connected to ECT EVT configuration is given as below for reference MON module DSP module 1 DSP module 2 PWR module Slot No 01 02 03 08 09 10 11 12 13 14 P1 NR1301 NR1102 NR1151 NR1151 04 05 06 BI module BO modul...

Page 280: ...1305 1306 1307 1308 1309 1310 1311 1312 1313 1314 1315 1316 1317 1318 1319 1320 1321 1322 Electrical Etherneto SCADA Ethernet C Ethernet D Grounding Screw Ethernet A Ethernet B Optional Ethernet C Ethernet D Optional Optical Ethernet to SCADA PCS 978 SV from ECT EVT at each side transformer NET DSP module 1 FO interface for SV channel LC Type TX RX TX RX TX RX Ch1 Ch2 Ch8 NET DSP module 2 FO inter...

Page 281: ...Module Terminal Definition Equipment consists of power supply module MON module DSP module analog input module opto coupler input module tripping output module signal output module input and output signal for mechanical relay The definition and application of each module and its terminal is introduced as follows 6 3 1 PWR Module Power Supply The power supply module NR1301 is a DC DC converter with...

Page 282: ... 2 04 05 NC 06 BO_ALM Device abnormality alarm output 2 04 06 NO 07 OPTO Positive pole of power supply for Low voltage BI module 24V 08 OPTO Negative pole of power supply for Low voltage BI module 24V 09 Not used 10 PWR Positive pole of power supply for the device 250 220V 125 110V 11 PWR Negative pole of power supply for the device 250 220V 125 110V 12 GND Grounded connection of the device NOTE T...

Page 283: ...rformance built in processor FLASH SRAM SDRAM Ethernet controller and other peripherals Its functions include management of the complete device human machine interface communication and waveform recording etc The MON module uses the internal bus to receive the data from other modules of the device It communicates with the LCD module by RS 485 bus This module is provided with 100BaseT Ethernet inte...

Page 284: ...Ethernet To SCADA Twisted pair wire RS 485 01 SYN To clock synchronization 02 SYN 03 SGND 04 RS 232 05 RTS To printer 06 TXD 07 SGND NR1102M 256M DDR 4 RJ45 Ethernet To SCADA Twisted pair wire RS 485 01 SYN To clock synchronization 02 SYN 03 SGND 04 RS 232 05 RTS To printer 06 TXD 07 SGND NR1102J 256M DDR 2 RJ45 Ethernet To SCADA Twisted pair wire 2 FO Ethernet To SCADA Optical fibre ST RS 485 01 ...

Page 285: ...on 10 SYN 11 SGND 12 RS 232 13 RTS To printer 14 TXD 15 SGND 16 The correct method of connection is shown in Figure 6 3 3 Generally the shielded cables with two pairs of twisted pairs inside shall be applied One pair of the twisted pairs are respectively used to connect the and terminals of differential signal the other pair of twisted pairs are used to connect the signal ground of the interface i...

Page 286: ...module is connected to ECVT it can receive the real time synchronous sample data from merging unit through the multi mode optical fibre interface 6 3 4 DSP Module 2 Fault Detector Calculation The module consists of high performance digital signal processor optical fibre interface 16 digit high accuracy ADC that can perform synchronous sampling and other peripherals The functions of this module inc...

Page 287: ... applied for ECVT to receive signal from motherboard bus NR1152 It is used to ECVT 8 receiving channels applied for ECVT to receive signal directly 6 3 5 BI Module Binary Input There are two kinds of BI modules available NR1503 and NR1504 Up to 2 BI modules can be equipped with on device The input voltage can be selected to be 24V 48V NR1503D or NR1504D or 110V 220V 125V 250V NR1503A or NR504A Thi...

Page 288: ...of BI module is described as below BI_n n 01 02 10 11 can be configured as a specified binary input by PCS Explorer software NR1503 01 02 03 04 05 06 07 08 09 10 11 12 13 14 15 BI_Pulse_GPS NR1503 BI_RstTarg BI_05 BI_07 BI_08 BI_09 BI_10 BI_11 BI_06 16 17 18 19 20 21 22 BI_Print BI_Maintenance Opto11 Opto01 Opto02 Opto03 Opto04 Opto05 Opto06 Opto07 Opto08 Opto09 Opto10 Figure 6 3 4 Pin definition ...

Page 289: ...504 Figure 6 3 4 Pin definition of BI module NR1504 Pin description for NR 1503 and NR1504 are shown as follows respectively 1 NR1503 Pin No Symbol Description 01 BI_TimeSyn Binary input of time synchronization pulse 02 Opto01 Negative pole of first binary input 03 BI_Print Binary input of triggering printing 04 Opto02 Negative pole of second binary input 05 BI_Maintenance Binary input of indicati...

Page 290: ...ance Binary input of indicating the protection device is under maintenance state 05 BI_RstTarg Binary input of resetting signal of protective equipment 06 BI_05 Configurable binary input 5 07 BI_06 Configurable binary input 6 08 Blank Not used 09 BI_07 Configurable binary input 7 10 BI_08 Configurable binary input 8 11 BI_09 Configurable binary input 9 12 BI_10 Configurable binary input 10 13 BI_1...

Page 291: ...he BI is energized During equipment maintenance or testing the BI is then energized not to send reports via communication port local display and printing still work as usual The BI should be de energized when the equipment is restored back to normal 4 Binary input BI_RstTarg It is used to reset latching signal relay and LCD displaying The reset is done by pressing a button on the panel NOTE The ra...

Page 292: ...sent change 1 b For the receiving end of SV message if the value of bit Test of quality Q of sampling data in the SV message received by it is 1 the relevant protection functions will be disabled but under maintenance state the protection device should calculate and display the magnitude of sampling data c For duplicated protection function configurations all merging units of control module config...

Page 293: ...signal output module for option NR1523B and NR 1521C NR1523B The NR1523B module is a standard binary output module for signal which can provide 11 signal output contacts without control by fault detector Among those contacts contacts BO_Signal_n n 1 2 7 10 are normally open NO contacts and BO_Signal_8 and BO_Siganl_9 are normally closed NC contacts All contacts in the module can be configured as s...

Page 294: ...21 Figure 6 3 6 Pin definition of signal output module NR1523B NOTE If more magnetic latched contacts or normally closed NC contacts are required please specific when placing order Pin No Original Symbol New defined Symbol Description 01 BO_Signal_1 BO_Signal_1 1 The NO contact 1 of 1st group of signal output 02 03 BO_Signal_2 BO_Signal_1 2 The NO contact 2 of 1st group of signal output 04 05 BO_S...

Page 295: ... contact of 7th group of output 20 21 BO_Signal_11 BO_Prot The NO magnetic latched contact for indicating protection operation 22 NR1521C The NR1521C module is a binary output module for signal which can provide 11 NO signal output contacts without control by fault detector BO_Signal_n n 1 2 7 11 All contacts in the module can be configured as specified signal output contacts of some protection by...

Page 296: ...BO_Signal_9 BO_Signal_10 Figure 6 3 7 Pin definition of signal output module NR1521C Pin No Original Symbol New defined Symbol Description 01 BO_Signal_1 BO_Signal_1 The NO contact of 1st group of signal output 02 03 BO_Signal_2 BO_Signal_2 The NO contact of 2nd group of signal output 04 05 BO_Signal_3 BO_Signal_3 The NO contact of 3rd group of signal output 06 07 BO_Signal_4 BO_Signal_4 The NO co...

Page 297: ...220Vdc and NR1536B 110Vdc 125V are input and output modules IO module for mechanical protection and this module is used to output various signals issue trip commands and accept reset command A 22 pin connector is fixed on the front of this module The pin definition of the connector is described as below 04 03 02 01 Reset Signal ResetInput BI_MR1 Binary Input Signals of Mechanical protection High V...

Page 298: ...d when binary input BI_MR4 is energized 3 rd group output contacts 20 16 BO_MR1_3 NO contact is closed when binary input BI_MR1 is energized 20 17 BO_MR2_3 NO contact is closed when binary input BI_MR2 is energized 20 18 BO_MR3_3 NO contact is closed when binary input BI_MR3 is energized 20 19 BO_MR4_3 NO contact is closed when binary input BI_MR4 is energized Power supply input of module 20 Pwr P...

Page 299: ...hannels The rated values of current inputs are selected at order A 24 pin connector is fixed on the front of this module The pin definition of the connector is described as below NR1401 NR1401 01 03 05 07 09 11 13 15 17 19 02 04 06 08 10 12 14 16 18 20 U2 U3 U3n I6 21 23 22 24 U4 U5 U6 U4n U6n U5n I1 I1n I2 I2n I3 I3n I4 I4n I5 I5n I6n U2n U1 U1n NR1401 01 03 05 07 09 11 13 15 17 19 02 04 06 08 10...

Page 300: ...ithout voltage input AI Module Configuration Slot No Module ID Type 04 NR1401 12 current channels The CT VT wiring diagram for the application is shown below 0401 0402 0403 0404 0405 0406 0419 0420 A B C HV side 0421 0422 0407 0408 0409 0410 0411 0412 0413 0414 0415 0416 0417 0418 A B C LV side 2 A B C LV side 1 PCS 978 Figure 6 3 10 CT VT connection for typical application 1 The following table l...

Page 301: ...ent input of LV side 1 0413 I7 Ia_L2 The phase A current input of LV side 2 polarity 0414 I7n Ian_L2 The phase A current input of LV side 2 0415 I8 Ib_L2 The phase B current input of LV side 2 polarity 0416 I8n Ibn_L2 The phase B current input of LV side 2 0417 I9 Ic_L2 The phase C current input of LV side 2 polarity 0418 I9n Icn_L2 The phase C current input of LV side 2 0419 I10 3I0_H The neutral...

Page 302: ...an_H The phase A current input of HV side 0403 I2 Ib_H The phase B current input of HV side polarity 0404 I2n Ibn_H The phase B current input of HV side 0405 I3 Ic_H The phase C current input of HV side polarity 0406 I3n Icn_H The phase C current input of HV side 0407 I4 Ia_L The phase A current input of LV side polarity 0408 I4n Ian_L The phase A current input of LV side 0409 I5 Ib_L The phase B ...

Page 303: ...side polarity 0420 U1n Uan_H The phase A voltage input of HV side 0421 U2 Ub_H The phase B voltage input of HV side polarity 0422 U2n Ubn_H The phase B voltage input of HV side 0423 U3 Uc_H The phase C voltage input of HV side polarity 0424 U3n Ucn_H The phase C voltage input of HV side 3 Two winding transformer application 3 In this application there is one branch at HV and LV side respectively w...

Page 304: ...olarity 0402 I1n Ian_H The phase A current input of HV side 0403 I2 Ib_H The phase B current input of HV side polarity 0404 I2n Ibn_H The phase B current input of HV side 0405 I3 Ic_H The phase C current input of HV side polarity 0406 I3n Icn_H The phase C current input of HV side 0407 I4 Ia_L The phase A current input of LV side polarity 0408 I4n Ian_L The phase A current input of LV side 0409 I5...

Page 305: ...phase A voltage input of HV side 0421 U2 Ub_H The phase B voltage input of HV side polarity 0422 U2n Ubn_H The phase B voltage input of HV side 0423 U3 Uc_H The phase C voltage input of HV side polarity 0424 U3n Ucn_H The phase C voltage input of HV side 4 Two winding transformer application 4 In this application there is one branch at HV and LV side respectively with voltage input AI Module Confi...

Page 306: ...H The phase A current input of HV side polarity 0402 I1n Ian_H The phase A current input of HV side 0403 I2 Ib_H The phase B current input of HV side polarity 0404 I2n Ibn_H The phase B current input of HV side 0405 I3 Ic_H The phase C current input of HV side polarity 0406 I3n Icn_H The phase C current input of HV side 0407 I4 Reserved 0408 I4n Reserved 0409 I5 Reserved 0410 I5n Reserved 0411 I6 ...

Page 307: ...c_L The phase C current input of LV side polarity 0606 I3n Icn_L The phase C current input of LV side 0607 I4 3I0_H The neutral current input of HV side polarity 0608 I4n 3I0n_H The neutral current input of HV side 0609 I5 Reserved 0610 I5n Reserved 0611 I6 3I0_L The neutral current input of LV side polarity 0612 I6n 3I0n_L The neutral current input of LV side 0613 U1 Ua_L The phase A voltage inpu...

Page 308: ...D Type 04 NR1401 6 current inputs and 6 voltage inputs 06 NR1401 6 current inputs and 6 voltage inputs The CT VT wiring diagram for the application is shown below 0401 0402 0403 0404 0405 0406 A B C HV side 0611 0612 0407 0408 0409 0410 0411 0412 0413 0414 0415 0416 0417 0418 PCS 978 0619 0620 0613 0614 0615 0616 0617 0618 0623 0622 A B C LV side Figure 6 3 14 CT VT connection for typical applicat...

Page 309: ...input of HV side 0415 U2 Ub_H The phase B voltage input of HV side polarity 0416 U2n Ubn_H The phase B voltage input of HV side 0417 U3 Uc_H The phase C voltage input of HV side polarity 0418 U3n Ucn_H The phase C voltage input of HV side 0419 U4 Reserved 0420 U4n Reserved 0421 U5 Reserved 0422 U5n Reserved 0423 U6 Reserved 0424 U6n Reserved Pin No Original Symbol New defined Symbol Description 06...

Page 310: ...7 U3 Uc_L The phase C voltage input of LV side polarity 0618 U3n Ucn_L The phase C voltage input of LV side 0619 U4 3U0_H The residual current input of HV side polarity 0620 U4n 3U0n_H The residual current input of HV side 0621 U5 Reserved 0622 U5n Reserved 0623 U6 3U0_L The residual current input of LV side polarity 0624 U6n 3U0n_L The residual current input of LV side 6 Three winding Transformer...

Page 311: ... pin definition of AI module Pin No Original Symbol New defined Symbol Description 0401 I1 Ia_H The phase A current input of HV side polarity 0402 I1n Ian_H The phase A current input of HV side 0403 I2 Ib_H The phase B current input of HV side polarity 0404 I2n Ibn_H The phase B current input of HV side 0405 I3 Ic_H The phase C current input of HV side polarity 0406 I3n Icn_H The phase C current i...

Page 312: ...hase B voltage input of MV side 0423 U6 Uc_M The phase C voltage input of MV side polarity 0424 U6n Ucn_M The phase C voltage input of MV side Pin No Original Symbol New defined Symbol Description 0601 I1 Ia_L The phase A current input of LV side polarity 0602 I1n Ian_L The phase A current input of LV side 0603 I2 Ib_L The phase B current input of LV side polarity 0604 I2n Ibn_L The phase B curren...

Page 313: ...tage input of HV side 0621 U5 3U0_M The residual voltage input of MV side polarity 0622 U5n 3U0n_M The residual voltage input of MV side 0623 U6 3U0_L The residual voltage input of LV side polarity 0624 U6n 3U0n_L The residual voltage input of LV side 7 Three winding Transformer application 2 In this application PCS 978 supports 4 CT groups two neutral CT and 3 three phase VTs AI Module Configurat...

Page 314: ...1 The phase A current input of HV side 1 polarity 0402 I1n Ian_H1 The phase A current input of HV side 1 0403 I2 Ib_H1 The phase B current input of HV side 1 polarity 0404 I2n Ibn_H1 The phase B current input of HV side 1 0405 I3 Ic_H1 The phase C current input of HV side 1 polarity 0406 I3n Icn_H1 The phase C current input of HV side 1 0407 I4 Ia_H2 The phase A current input of HV side 2 polarity...

Page 315: ...ew defined Symbol Description 0601 I1 Ia_M The phase A current input of MV side polarity 0602 I1n Ian_M The phase A current input of MV side 0603 I2 Ib_M The phase B current input of MV side polarity 0604 I2n Ibn_M The phase B current input of MV side 0605 I3 Ic_M The phase C current input of MV side polarity 0606 I3n Icn_M The phase C current input of MV side 0607 I4 Ia_L The phase A current inpu...

Page 316: ... LV side polarity 0624 U3n Ucn_L The phase C voltage input of LV side 8 Auto transformer three winding application In this application PCS 978 supports 6 CT groups 3 neutral CTs and 3 three phase VTs with broken delta voltage input For auto transformer or three winding transformer application users can wire PCS 978 according to the following wiring diagram AI Module Configuration Slot No Module ID...

Page 317: ...19 0620 0621 0622 0623 0624 PCS 978 Portion of PCS 978 A B C A B C LV side 2 Figure 6 3 17 CT VT connection for tyipical application 8 The following tables list the pin definition of AI module Pin No Original Symbol New defined Symbol Description 0401 I1 Ia_H1 The phase A current input of HV side 1 polarity 0402 I1n Ian_H1 The phase A current input of HV side 1 0403 I2 Ib_H1 The phase B current in...

Page 318: ...n_M The phase A voltage input of MV side 0421 U5 Ub_M The phase B voltage input of MV side polarity 0422 U5n Ubn_M The phase B voltage input of MV side 0423 U6 Uc_M The phase C voltage input of MV side polarity 0424 U6n Ucn_M The phase C voltage input of MV side Pin No Original Symbol New defined Symbol Description 0601 I1 Ia_M1 The phase A current input of MV side 1 polarity 0602 I1n Ian_M1 The p...

Page 319: ...ymbol Description 0801 I1 Ia_L1 The phase A current input of LV side 1 polarity 0802 I1n Ian_L1 The phase A current input of LV side 1 0803 I2 Ib_L1 The phase B current input of LV side 1 polarity 0804 I2n Ibn_L1 The phase B current input of LV side 1 0805 I3 Ic_L1 The phase C current input of LV side 1 polarity 0806 I3n Icn_L1 The phase C current input of LV side1 0807 I4 Ia_L2 The phase A curren...

Page 320: ...mal current Icth According to the maximum load current Rated short time thermal current Ith and rated dynamic current Idyn According to the maximum fault current Rated secondary current Isn Accuracy limit factor Kalf Ipn Rated primary current amps Icth Rated continuous thermal current amps Ith Rated short time thermal current amps Idyn Rated dynamic current amps Isn Rated secondary current amps Ka...

Page 321: ...phase current input ohms Ipn Rated primary current amps For example Kalf 30 Isn 5A Rct 1ohm Sbn 60VA Esl kalf Isn Rct Rbn kalf Isn Rct Sbn Isn 2 30 5 1 60 52 510V Ipcf 40000A RL 0 5ohm Rr 0 1ohm Rc 0 1ohm Ipn 2000A Esl 2 Ipcf Isn Rct Rb Ipn 2 Ipcf Isn Rct Rr 2 RL RC Ipn 2 40000 5 1 0 1 2 0 5 0 1 2000 440V Esl Esl 6 3 8 4 DC Analog Input Module NR1410B Transducer input module NR1410B can receive si...

Page 322: ...inition of DC analog output module Typical connection of the module with external transducers is shown in the figure below and there is a jumper between pin S1 and pin S6 on module NR1410B to control the input signal type of the module 4 20mA To_Transducer_24V Transducer_24V_Return S1 Jumper External Transducer Input_ Input_ S6 NR1410B R Figure 6 3 19 Typical connection of the module with external...

Page 323: ...l E2E and P2P defined in IEEE1588 protocol can be selected This module supports Ethernet IEEE802 3 time adjustment message format UDP time adjustment message format and GMRP The view of the network DSP module is shown as below NR1136A NR1136C RX Figure 6 3 20 View of the NET DSP module 6 3 10 HMI Module The display panel consists of liquid crystal display module keyboard LED and ARM processor The ...

Page 324: ...t group Controlled contacts Contact amount 0 TrpOutp1 the 1st group of tripping output contacts 1301 1302 1303 1304 1305 1306 3 1 TrpOutp2 the 2nd group of tripping output contacts 1307 2808 1309 1310 2 2 TrpOutp3 the 3rd group of tripping output contacts 1311 1312 1313 1314 2 3 TrpOutp4 the 4th group of tripping output contacts 1315 1316 1317 1318 2 4 TrpOutp5 the 5th group of tripping output con...

Page 325: ...ual reset and then the output contact can drop off The number of signal output contacts can be flexibly configured according t user requirement Tripping output Contact When the protection element operates the equipment sends tripping command to drive the tripping output contact and signal contact simultaneously For example when differential protection operates in addition to the pickup of tripping...

Page 326: ...arth fault protection of HV side 64REF Biased restricted earth fault protection of MV side 64REF Biased restricted earth fault protection of LV side 64REF Overexcitation protection 24 1 stage definite time for trip 1 stage definite time for alarm 1 stage inverse time for trip and alarm Backup protection of each side identical configuration Phase overcurrent protection 50P 51P 67P 4 stages for trip...

Page 327: ...B P1 PWR module NR1301 Equipment consists of power supply module MON module DSP module Analog input module opto coupler input module tripping output module and signal output module PWR module DSP module MON module and tripping output group of PCS 978 for the application have similar terminal definitions to those modules in above sections so please refer to the them for details Other modules have s...

Page 328: ...definition of AC analog output module for the application The pin definition of the AC analog input module at slot 04 is shown as follows Pin No Original Symbol New defined Symbol Description 0401 I1 Ia_H The phase A current input of HV side 0402 I1n Ian_H 0403 I2 Ib_H The phase B current input of HV side 0404 I2n Ibn_H 0405 I3 Ic_H The phase C current input of HV side 0406 I3n Icn_H 0407 I4 Ia_M ...

Page 329: ...al Symbol New defined Symbol Description 0601 I1 Ia_L The phase A current input of LV side 0602 I1n Ian_L 0603 I2 Ib_L The phase B current input of LV side 0604 I2n Ibn_L 0605 I3 Ic_L The phase C current input of LV side 0606 I3n Icn_L 0607 I4 I0_H Neutral current input of HV side 0608 I4n I0n_H 0609 I5 I0_M Neutral current input of MV side 0610 I5n I0n_M 0611 I6 I0_L Neutral current input of LV s...

Page 330: ...8 1417 BO_Trp_10 1420 1419 BO_Trp_11 1422 1421 1301 1302 1303 1304 1305 1306 1307 1308 1309 1310 1311 1312 1313 1314 BO_Trp_1 NR1521 1315 1316 1317 1318 1319 1320 1321 1322 BO_Trp_2 BO_Trp_3 BO_Trp_4 BO_Trp_5 BO_Trp_6 BO_Trp_7 BO_Trp_8 BO_Trp_9 BO_Trp_10 BO_Trp_11 BO_Trp_1 1302 1301 BO_Trp_2 1304 1303 BO_Trp_3 1306 1305 BO_Trp_4 1308 1307 BO_Trp_5 1310 1309 BO_Trp_6 1312 1311 BO_Trp_7 1314 1313 BO...

Page 331: ... definition of the tripping output module at slot 14 is shown as follows Pin No Original Symbol New defined Symbol Description 1401 BO_Trp_1 BO_Trp_6 1 The NO contact 1 of 6th group of output 1402 1403 BO_Trp_2 BO_Trp_6 2 The NO contact 2 of 6th group of output 1404 1405 BO_Trp_3 BO_Trp_6 3 The NO contact 3 of 6th group of output 1406 1407 BO_Trp_4 BO_Trp_7 1 The NO contact 1 of 7th group of outpu...

Page 332: ...l_1 2 1504 1503 BO_Signal_2 1 1506 1505 BO_Signal_2 1 1508 1507 BO_Signal_3 1 1510 1509 BO_Signal_3 2 1512 1511 BO_Signal_4 1514 1513 BO_Signal_5 1516 1515 BO_Signal_6 1518 1517 BO_Signal_7 1520 1519 BO_Prot 1522 1521 Figure 6 6 4 Pin definition of signal output module for the application The pin definitions of the signal output module at slot 15 is shown as follows Pin No Original Symbol New defi...

Page 333: ... The NO contact of 4th group of output 1514 1515 BO_Signal_8 BO_Signal_5 The NC contact of 5th group of output 1516 1517 BO_Signal_9 BO_Signal_6 The NC contact of 6th group of output 1518 1519 BO_Signal_10 BO_Signal_7 The NO contact of 7th group of output 1520 1521 BO_Signal_11 BO_Prot The NO magnetic latched contact for indicating protection operation 1522 ...

Page 334: ...6 Hardware Description PCS 978 Transformer Relay 6 60 Date 2013 01 16 ...

Page 335: ...ettings 7 10 7 3 8 Mechanical Protection Settings 7 12 7 3 9 Temperature Protection Settings 7 13 7 3 10 Impedance Protection Settings 7 14 7 3 11 Phase Overcurrent Protection Settings 7 15 7 3 12 Ground Overcurrent Protection Settings 7 17 7 3 13 Negative Sequence Overcurrent Protection 7 18 7 3 14 Phase Overvoltage Protection Settings 7 19 7 3 15 Residual Overvotlage Protection Settings 7 20 7 3...

Page 336: ...t of impedance protection of x side HVS MVS LVS 7 14 Table 7 3 11 Setting list of phase overcurrent protection x HVS MVS LVS stage n n 1 2 3 7 15 Table 7 3 12 Setting list of ground overcurrent protection x HVS MVS LVS stage n n 1 2 3 7 17 Table 7 3 13 Setting list of 50 51Q of x side x HVS MVS LVS 7 18 Table 7 3 14 Setting list of phase overvoltage protection x HVS MVS LVS 7 19 Table 7 3 15 Setti...

Page 337: ...q 50Hz 60Hz Select system working frequency 3 PrimaryEquip_Name Max 20 characters Name of the protected primary equipment such as transformer line etc 4 Sn 0 1 5000 0 001 MVA Transformer capacity 5 87R Sn 0 1 5000 0 001 MVA Reactor capacity 6 87R Un 0 1 2000 0 001 kV Primary rated phase to phase voltage of reactor 7 Un_HVS 0 2000 0 001 kV Primary rated voltage of HV side stated on nameplate 8 Un_M...

Page 338: ... side MVS MV side etc Setting explanation 1 Active_Grp The current protection setting group number and total 10 group settings are provided The device settings communication settings and system settings are common for all protection groups 2 Sn Un_HVS Un_MVS Un_LVS x U1n x U2n x I1n x I2n During the calculation of current differential protection in order to get current correction ratio of each sid...

Page 339: ...Then it is needed to decide whether zero sequence current is eliminated and select the corresponding matrix If an earthing transformer is connected at LV side out the protection zone of differential protection then matrix of relative o clock 0 without zero sequence current elimination can be selected If an earthing transformer is connected at LV side in the protection zone of differential protecti...

Page 340: ...1 4 Un_HVS Un_MVS Un_LVS Setting principle of rated phase to phase voltages of each side is to take the primary rated voltage marked on the nameplate of transformer as the primary rated voltage of corresponding side For an on load tap changing transformer the voltage of transformer with tap in middle position can be taken as the value of this setting As to other kind of transformers actual operati...

Page 341: ...Delt x U2n_Delt Set those settings respectively according to the actual primary value and secondary value of the corresponding side VT Setting path Access path in menu is Main Menu Settings System Settings 7 3 Protection Settings NOTE There are some symbols mentioned in the following sections and the meaning of them is given here Un rated secondary voltage of VT In rated secondary current of CT al...

Page 342: ...etection 12 87T En_Instant 0 disable 1 enable 1 Logic setting of enabling disabling unrestrained instantaneous differential protection 13 87T En_Biased 0 disable 1 enable 1 Logic setting of enabling disabling conventional biased differential protection 14 87T En_DPFC 0 disable 1 enable 1 Logic setting of enabling disabling DPFC current differential protection 15 87T Opt_Inrush_Ident 0 1 1 Logic se...

Page 343: ...ficient of 3 rd harmonics for CT saturation detection 6 87R I_Alm 0 1 1 5 0 001 pu Setting of differential current abnormality alarm 7 87R En_Instant 0 disable 1 enable 1 Logic setting of enabling disabling unrestrained instantaneous differential protection 8 87R En_Biased 0 disable 1 enable 1 Logic setting of enabling disabling conventional biased differential protection 9 87R En_DPFC 0 disable 1...

Page 344: ... setting of biased winding differential protection 3 87W Slope 0 1 0 9 0 001 Percentage restraint coefficient of biased winding differential protection 4 87W En_CTS_Blk 0 disable 1 enable 1 Logic setting of enabling disabling blocking winding differential protection during CT circuit failure 5 87W En_Phase 0 disable 1 enable 1 Logic setting of enabling disabling phase winding differential protecti...

Page 345: ...otection for alarm 9 24IDMT K0_Set 1 0 1 7 0 001 Highest limit multiple setting of inverse time overexcitation protection n0 10 24IDMT t0_Op 0 1 9999 0 001 s Time delay setting corresponding to highest limit setting t0 11 24IDMT K1_Set 1 0 1 7 0 001 Multiple setting 1 of inverse time overexcitation protection n1 12 24IDMT t1_Op 0 1 9999 0 001 s Time delay setting corresponding to multiple setting ...

Page 346: ...g of enabling inverse time overexcitation protection for alarm 31 24IDMT t_Cooling 0 1 9999 0 001 s Cooling time of inverse time overexcitation protection 32 24IDMT En_Trp 0 disable 1 enable 0 Logic setting of enabling inverse time overexcitation protection for trip 33 24IDMT OutMap 0 FFFF 1 Tripping logic setting of inverse time overexcitation protection 7 3 7 Frequency Protection Settings Table ...

Page 347: ...ency protection 18 81U f_Pkp 40 60Hz 0 01 Hz Pickup setting of underfrequency protection 19 81U df dt_Blk 0 05 20 0 01 Hz s Setting of df dt blocking underfrequency protection 20 81U UF1 f_Set 45 60 0 01 Hz Frequency setting of stage 1 of underfrequency protection 21 81U UF1 t_Op 0 1 6000 0 001 s Time delay of stage 1 of underfrequency protection 22 81U UF1 En 0 disable 1 enable 1 Logic setting of...

Page 348: ...ction 37 81U UF4 En 0 disable 1 enable Logic setting of enabling disabling stage 4 of underfrequency 38 81U UF4 En_df dt_Blk 0 disable 1 enable Logic setting of enabling disabling df dt blocking function for stage 4 of underfrequency protection 39 81U UF4 OutMap 0000 FFFF Tripping logic setting of stage 4 of underfrequency protection 7 3 8 Mechanical Protection Settings Table 7 3 8 Setting list of...

Page 349: ...hanical protection 7 3 9 Temperature Protection Settings Table 7 3 9 Settings of temperature protection No Setting Item Range Step Unit Description 1 Tmax_Transducer 100 1000 0 01 C Maximum temperature setting corresponding to the maximum input of transducer 2 Tmin_Transducer 100 1000 0 01 C Minimum temperature setting corresponding to the minimum input of transducer 3 26 T_Trp 1000 1000 0 01 C Te...

Page 350: ... phase impedance protection 8 x 21 ZP1 OutMap 0000 FFFF Tripping logic setting of stage 1 of phase to phase impedance protection 9 x 21 ZP2 Z_Fwd 0 05 200 0 01 Ω Forward impedance setting of stage 2 of phase to phase impedance protection 10 x 21 ZP2 Z_Rev 100 1000 0 01 Ω Reverse impedance setting of stage 2 of phase to phase impedance protection 11 x 21 ZP2 t_Op 0 05 20 0 001 s Time delay of stage...

Page 351: ...phase undervoltage setting 2 x 50 51P U2_VCE 2 200 0 001 V Negative sequence overvoltage setting 3 x 50 51P RCA 0 360 1 deg Relay characteristic angle of phase overcurrent protection 4 x 50 51P K_Hm2 0 05 1 0 0 001 Harmonic blocking coefficient of phase overcurrent protection 5 x 50 51P I_Rls_Hm Blk 0 04 150 0 001 A Current setting of releasing harmonic blocking function of phase overcurrent prote...

Page 352: ... x 50 51P4 tmin 0 20 0 001 s Minimum delay of stage 4 of phase overcurrent protection 20 x 50 51P4 K 0 120 0 001 The constant K of stage 4 of phase overcurrent protection 21 x 50 51P4 C 0 20 0 001 s The constant C stage 4 of phase overcurrent protection 22 x 50 51P4 Alpha 0 02 5 0 001 The exponent alpha of stage 4 of phase overcurrent protection 23 x 50 51P4 Opt_Cur ve 0 13 1 Logic setting for sel...

Page 353: ...ground overcurrent protection 7 x 50 51Gn Opt_Dir 0 2 1 Logic setting of selecting control mode of residual directional element to stage n of ground overcurrent protection 0 no direction 1 forward direction 2 reverse direction 8 x 50 51Gn Opt_3I0 0 1 1 Logic setting of selecting residual current for the calculation of stage n of ground overcurrent protection 0 Measured residual current 1 Calculate...

Page 354: ...d direction 2 reverse direction 22 x 50 51G4 Opt_3I0 0 1 1 Logic setting of selecting residual current for the calculation of stage 4 of ground overcurrent protection 0 Measured residual current 1 Calculated residual current 23 x 50 51G4 En_Hm2 _Blk 0 disable 1 enable 1 Logic setting of enabling harmonic blocking stage 4 of ground overcurrent protection 0 disable 1 enable 24 x 50 51G4 En 0 disable...

Page 355: ...gative sequence overcurrent protection 12 x 50 51Q2 Alpha 0 02 5 0 001 The exponent alpha of stage 2 of negative sequence overcurrent protection 13 x 50 51Q2 Opt_Curve 0 13 1 Logic setting for selecting operating characteristic curve of stage 2 of negative sequence overcurrent protection 14 x 50 51Q2 En 0 disable 1 enable 1 Logic setting of enabling stage 2 of negative sequence overcurrent protect...

Page 356: ... x 59P2 TMS 0 05 3 2 0 001 Time multiplier setting of stage 2 of phase overvoltage protection 13 x 59P2 tmin 0 20s 0 001 s Minimum delay of stage 2 of phase overvoltage protection 14 x 59P2 K 0 120 0 001 The constant K of stage 2 of phase overvoltage protection 15 x 59P2 C 0 20 0 001 s The constant C stage 2 of phase overvoltage protection 16 x 59P2 Alpha 0 02 5 0 001 The exponent alpha stage 2 of...

Page 357: ...C stage 2 of residual overvoltage protection 12 x 59G2 Alpha 0 02 5 0 001 The exponent alpha stage 2 of residual overvoltage protection 13 x 59G2 Opt_Curve 0 13 1 Logic setting for selecting operating characteristic curve of stage 2 of residual overvoltage protection 14 x 59G2 En 0 disable 1 enable 1 Logic setting of enabling stage 2 of residual overvoltage protection 0 disable 1 enable 15 x 59G2 ...

Page 358: ...ge 3 of undervoltage protection 17 x 27 UV3 En 0 disable 1 enable 1 Logic setting of enabling stage 3 of undervoltage protection 18 x 27 UV3 OutMap 0000 FFFF 1 Tripping logic setting of stage 3 of undervoltage protection 19 x 27 UV4 U_Set 0 100 0 001 V Voltage setting of stage 4 of undervoltage protection 20 x 27 UV4 t_Op 0 05 100 0 001 s Time delay of stage 4 of undervoltage protection 21 x 27 UV...

Page 359: ...f enabling disabling residual sequence current criterion to control breaker failure protection 15 x 50BF t1_Op 0 20 0 001 s Time delay 1 of breaker failure protection 16 x 50BF En_t1 0 disable 1 enable 1 Logic setting of enabling disabling time delay 1 of breaker failure protection 17 x 50BF OutMap_t1 0000 FFFF Tripping logic setting of time delay 1 of breaker failure protection 18 x 50BF t2_Op 0 ...

Page 360: ...OP 0 7 1 0 0 95 Drop off ratio of stage n of phase overcurrent alarm element 4 x 50PAlmn En 0 disable 1 enable 1 Logic setting of enabling stage n of phase overcurrent alarm element 7 3 21 Residual Overvoltage Alarm Element Table 7 3 21 Setting list of residual overvoltage alarm element x HVS MVS LVS No Setting Item Range Step Unit Description 1 x 59GAlm 3U0_Set 2 200 0 001 V Voltage setting of re...

Page 361: ... 0 5V supporting 0 5V DC signal 0 20mA supporting 0 20mA DC signal PT100 supporting AC voltage signal from PT100 voltage transformer Setting explanation 1 HDR_EncodeMode The setting is to select encoding format of header file Default value of HDR_EncodeMode is 1 i e UTF 8 code and please set it to 0 i e GB18030 according to the special requirement 2 Opt_Caption_103 The setting is to select the cap...

Page 362: ... port 3 7 Mask_LAN3 000 000 000 000 255 255 255 255 Subnet mask of Ethernet port 3 8 En_LAN3 0 disable 1 enable Enable disable the IP address of port 3 9 IP_LAN4 0 disable 1 enable IP address of Ethernet port 4 10 Mask_LAN4 000 000 000 000 255 255 255 255 Subnet mask of Ethernet port 4 11 En_LAN4 0 disable 1 enable Enable disable the IP address of port 4 12 Gateway 000 000 000 000 255 255 255 255 ...

Page 363: ... IEC103 protocol Default value 60 22 Format_Measmt 0 1 Select the format of measurement data sent to SCADA through IEC103 protocol 23 Baud_Printer 4800 9600 19200 38400 57600 115200 bps Baud rate of printer port 24 En_AutoPrint 0 disable 1 enable Enable disable automatic printing function 25 Opt_TimeSyn Conventional SAS Advanced NoTimeSyn Select the mode of time synchronization of equipment 26 IP_...

Page 364: ...0 IEC 60870 5 103 protocol 1 Modbus protocol 2 Reserved 3 Reserved 4 Format_Measmt The setting is used to select the format of measurement data sent to SCADA through IEC103 protocol 0 GDD data type through IEC103 protocol is 12 1 GDD data type through IEC103 protocol is 7 i e 754 short real number of IEEE standard 5 En_AutoPrint If automatic print is required for disturbance report after protectio...

Page 365: ... mode is selected if there is no conventional clock synchronization signal connected to NET DSP module SAS mode is enabled automatically with the alarm signal Alm_TimeSyn being issued simultaneously 3 When NoTimeSyn mode is selected the device will not send alarm signals without NOTE The clock message via IEC103 protocol is invalid when the device receives the IRIG B signal through RC 485 port 7 I...

Page 366: ...East 6 th East 7 th East 8 th East 9 th East 10 th East 11 th Setting 6 7 8 9 10 11 Time zone East West 12 th West 1 st West 2 nd West 3 rd West 4 th West 5 th Setting 12 12 1 2 3 4 5 Time zone West 6 th West 7 th West 8 th West 9 th West 10 th West 11 th Setting 6 7 8 9 10 11 Setting Path Access path in menu is Main Menu Settings Device Setup Comm Settings ...

Page 367: ... 2 1 Overview 8 6 8 2 2 Measurement 8 9 8 2 3 Status 8 10 8 2 4 Records 8 10 8 2 5 Settings 8 11 8 2 6 Print 8 12 8 2 7 Local Cmd 8 14 8 2 8 Information 8 14 8 2 9 Test 8 14 8 2 10 Clock 8 15 8 2 11 Language 8 15 8 3 Understand the LCD Display 8 15 8 3 1 Overview 8 15 8 3 2 Display during Normal Operation 8 15 8 3 3 Display When Tripping 8 16 8 3 4 Display under Abnormal Condition 8 18 8 3 5 Displ...

Page 368: ...ure 8 1 1 Front panel of PCS 978 8 1 Figure 8 1 2 Keypad mounted on the front panel 8 2 Figure 8 1 3 the figure shows the LED indications 8 3 Figure 8 1 4 Corresponding cable of the RJ45 port in the front panel 8 4 Figure 8 1 5 Rear view and terminal definition of NR1102C 8 5 Figure 8 2 1 Tree diagram of total command menu 8 8 Figure 8 3 1 LCD display of single line diagram 8 16 Figure 8 3 2 LCD d...

Page 369: ... 8 29 Figure 8 4 6 Display of deleting report 8 30 Figure 8 4 7 Display of modifying clock 8 31 Figure 8 4 8 Display of communication test 8 32 Figure 8 4 9 Display of selecting language 8 33 List of Tables Table 8 1 1 Definition of the 8 core cable 8 4 Table 8 3 1 Tripping report messages 8 17 Table 8 3 2 Contact inputs list 8 20 Table 8 3 3 Contact outputs list 8 21 Table 8 3 4 User Operating ev...

Page 370: ...8 Human Machine Interface PCS 978 Transformer Relay 8 d Date 2013 01 16 ...

Page 371: ...ettable parameter value through keypad are also described in details NOTE About three measurements in menu Measurements please refer to the following description Measurement1 is use to display measured values from protection calculation DSP displayed in secondary value Measurement2 is used to display measured values from fault detector DSP displayed in secondary value Measurement3 is used to displ...

Page 372: ... keys for full access to device 4 Communication port a multiplex RJ45 port for local communication with a PC 5 Logo Type and designation and manufacturer of device 8 1 1 Keypad Operation ENT G R P E S C Figure 8 1 2 Keypad mounted on the front panel 1 ESC Cancel the operation Quit the current menu 2 ENT Execute the operation Confirm the interface 3 GRP Activate the switching interface of setting g...

Page 373: ...of service or any hardware error is detected during self check Green Lit when the equipment is in service and ready for operation ALARM Off When equipment in normal operating condition Yellow Lit when VT circuit failure CT circuit failure or other abnormal alarm is issued TRIP Off when the equipment is in normal operating condition Red Lit when any protection element trips NOTE The HEALTHY LED can...

Page 374: ... following figure a customized cable is applied for debugging via this multiplex RJ45 port Figure 8 1 4 Corresponding cable of the RJ45 port in the front panel In the above figure and the following table P1 To connect the multiplex RJ45 port An 8 core cable is applied here P2 To connect the twisted pair Ethernet port of the computer P3 To connect the RS 232 serial port of the computer The definiti...

Page 375: ...rnet interface in the menu Settings Device Setup Communication Settings it should be ensured that the protection device and PC are in the same network segment For example setting the IP address and subnet mask of network A using network A to connect with PC PC IP address is set as 198 87 96 102 subnet mask is set as 255 255 255 0 The IP address and subnet mask of protection device should be IP_LAN...

Page 376: ...uick menu after its first execution Five latest menu commands can be recorded in the quick menu When the five menu commands are recorded the latest menu command will cover the earliest one adopting the first in first out principle It is arranged from top to bottom and in accordance with the execution order of command menus Press to enter the main menu with the interface as shown in the following d...

Page 377: ...8 Human Machine Interface PCS 978 Transformer Relay 8 7 Date 2013 01 16 Test Local Cmd Print Settings Records Measurements Status Information Clock Language ...

Page 378: ...t Settings HVS REF Prot Settings MVS REF Prot Settings LVS REF Prot Settings Overexcitation Prot Settings Mechanical Prot Settings HVS Backup Prot Settings MVS Backup Prot Settings Prot Settings System Settings Latest Modified All Settings GOOSE Links Logic Links Device Setup Device Settings Communication Settings Label Settings Language Settings Diff Prot Settings HVS REF Prot Settings MVS REF Pr...

Page 379: ...values on protection DSP module 2 Measurement 2 Display sampled and calculated values on fault detector DSP module 3 Measurement 3 Display measured values and other calculated quantities 8 2 2 1 Measurements1 The menu Measurement1 has following submenus No Item Description 1 HVS Measurements Display measured values and corresponding phase angels of HV side on protection DSP module 2 MVS Measuremen...

Page 380: ...flects the running environment of the protection device As long as the displayed values consist with the actual running situation basically the protection device can work normally This menu is set to greatly facilitate the debugging and maintenance of people on site The menu Status has following submenus No Item Description 1 Inputs Display all input signal states 2 Outputs Display all output sign...

Page 381: ...Prot Settings The submenu Prot Settings includes the following command menus No Item Function description 1 Diff Prot Settings Display and modify the settings of current differential protection 2 HVS REF Prot Settings Display and modify the settings of REF protection of HV side 3 MVS REF Prot Settings Display and modify the settings of REF protection of MV side 4 LVS REF Prot Settings Display and ...

Page 382: ...rmation of protective device including software version 2 Settings Print settings including communication parameter protection setting logic links and device setup It can print by different classifications as well as printing all settings of the device Besides it can also print out the latest modified setting item 3 Disturb Records Print trip reports 4 Superv Events Print status change of binary s...

Page 383: ...ot Settings Print the settings of temperature protection 8 Frequency Prot Settings Print the settings of frequency protection 9 HVS Backup Prot Settings Print the settings of backup protection of HV side 10 MVS Backup Prot Settings Print the settings of backup protection of MV side 11 LVS Backup Prot Settings Pint the settings of backup protection of LV side 12 Trip Logic Settings Print the progra...

Page 384: ... creating time of software CRC codes and management sequence number Besides hardware board information can also be viewed This menu includes the following command menus No Item Function description 1 Version Info Display software version information of the equipment 2 Board Info Monitor the current working state of each board of the equipment 8 2 9 Test This menu is mainly used for developers to d...

Page 385: ... same time to switch the display among trip reports alarm reports and the SLD display Binary change reports will be displayed for 5s and then it ll return to the previous display interface automatically Control reports will not pop up and can only be viewed by navigating the corresponding menu 8 3 2 Display during Normal Operation After the protection device is powered and turns into the initiatin...

Page 386: ...eaker names of each side Figure 8 3 1 LCD display of single line diagram breaker open breaker closed The displayed content of the interface contains the current date and time of the protection device with a format of yy mm dd hh mm ss the currently valid setting group number the three phase current and voltage sampled values of each side differential current residual differential current frequency...

Page 387: ...sted in Chapter Operation Theory and please refer to each protection element for details Operation reports of fault detector and the reports related to oscillography function are showed in the following table Table 8 3 1 Tripping report messages No Message Description 1 ManTrigDFR Oscillography function is triggered manually 2 RmtTrigDFR Oscillography function is triggered remotely 3 TrigDFR Fault...

Page 388: ...element and tripping element and its position suggests the position of the currently displayed line in the total lines The scroll bar of protection element and tripping element will roll up at the speed of one line per time When it rolls to the last three lines it ll roll from the earliest protection element and tripping element again The displayed content of the lower half part is similar to that...

Page 389: ... and hour minute second millisecond Alm_Maintenance 0 1 shows the content of abnormality alarm All the alarm elements have been listed in Chapter Supervision 8 3 5 Display When Binary State Changes When a binary input is energized or de energized output contacts operate the corresponding IO event report will be automatically displayed on LCD as follows This protective equipment can store 1024 even...

Page 390: ...ption 1 BI_TimeSyn Binary input of time synchronization pulse 2 BI_Print Binary input of triggering printing 3 BI_Maintenance Binary input of indicating the protection device is under maintenance state 4 BI_RstTarg Binary input of resetting signal of protective equipment 5 Bxx BI_01 Binary input 01 of binary input module at slot xx position 6 Bxx BI_02 Binary input 02 of binary input module at slo...

Page 391: ...o Binary input Description 1 TrpOut01 The 1 st group of tripping outputs contacts 2 TrpOut02 The 2 nd group of tripping outputs contacts 3 TrpOut03 The 3 rd group of tripping outputs contacts 4 TrpOut04 The 4 th group of tripping outputs contacts 5 TrpOut05 The 5 th group of tripping outputs contacts 6 TrpOut06 The 6 th group of tripping outputs contacts 7 TrpOut07 The 7 th group of tripping outpu...

Page 392: ...ser Operating event list No Message Description 1 Device_Reboot The protective equipment has been rebooted 2 Settings_Chgd The settings of protective equipment have been changed 3 ActiveGrp_Chgd Active setting group has been changed 4 Report_Cleared All reports have been deleted Device log events can not be deleted 5 Waveform_Cleared All waveforms have been deleted 6 SubProcess_Exit A subprocess h...

Page 393: ...annot be displayed in one display screen one screen can display 14 lines of information at most 5 Press the key or to select pervious or next command menu 6 Press the key ENT or ESC to exit this menu returning to the Status menu 8 4 3 View Device Records The operation is as follows 1 Press the key to enter the main menu 2 Press the key or to move the cursor to the Records menu and then press the k...

Page 394: ...g the Settings Logic Links press the key ENT or to enter the next level of menu 6 After entering the submenu Settings press the key or to move the cursor and then press the key ENT to print the corresponding default value If selecting any item to printing Press the key or to select the setting group to be printed After pressing the key ENT the LCD will display Start Printing and then automatically...

Page 395: ...or to move the cursor to any command menu and then press the key ENT to enter the menu 4 Press the key or to move the cursor 5 Press the key or to page up down 6 Press the key or to select pervious or next command menu 7 Press the key ESC to exit this menu returning to the menu Settings 8 If selecting the command menu Device Settings or Communication Settings move the cursor to the setting item to...

Page 396: ...layed interface of the command menu Device Settings If the password is correct LCD will display Save Settings and then exit this menu returning to the displayed interface of the command menu Device Settings with all modified setting items as modified values NOTE For different setting items their displayed interfaces are different but their modification methods are the same NOTE After modifying the...

Page 397: ... and press ENT to enter If the setting 87 I_Biased is selected to modify then press the ENT to enter and the LCD will display the following interface is shown the or to modify the value and then press the ENT to enter 87 I_Biased Modified Value Current Value Min Value 0 22 0 05 Max Value 5 00 0 22 Figure 8 4 3 Display 2 of modifying settings 10 If selecting the other menus move the cursor to the s...

Page 398: ...y will be shown on LCD Copy Settings Active Group 01 Copy To Group 02 Figure 8 4 4 Display of copy settings Press the key or to modify the value Press the key ESC and return to the menu Settings Press the ENT the LCD will display the interface for password input if the password is incorrect continue inputting it press the key ESC to exit the password input interface and return to the menu Settings...

Page 399: ...inputting it and then press the key ESC to exit the password input interface and return to its original state If the password is correct the HEALTHY indicator of the protection device will go out and the protection device will re check the protection setting If the check doesn t pass the protection device will be blocked If the check is successful the LCD will return to its original state 8 4 9 De...

Page 400: ...e including disturbance records supervision events and binary events but the user operation reports i e equipment logs can not be deleted Furthermore all deleted records are irrecoverable after deletion so the function shall be used with great cautious 8 4 10 Modify Device Clock The operation is as follows 1 Press the key to enter the main menu 2 Press the key or to move the cursor to the Clock me...

Page 401: ... follows 1 Press the key to enter the main menu 2 Press the key or to move the cursor to the Information menu and then press the ENT to enter the menu 3 Press the key or to move the cursor to the command menu Version Info and then press the key ENT to display the software version 4 Press the key ESC to return to the main menu 8 4 12 View Module Information The operation is as follows 1 Press the k...

Page 402: ...n Eelment Select Test All Test Figure 8 4 8 Display of communication test 4 Press the key or to move the cursor to select the corresponding command menu All Test or Select Test If selecting the All Test press the ENT and the device will successively carry out all operation element message test one by one 5 If selecting the Select Test users will go to an interface then select the or to page up dow...

Page 403: ... language 3 Press the key or to move the cursor to the language user preferred and press the key ENT to execute language switching After language switching is finished LCD will return to the menu Language and the display language is changed Otherwise press the key ESC to cancel language switching and return to the menu Language NOTE The LCD interface provided in this chapter is only a reference an...

Page 404: ...8 Human Machine Interface PCS 978 Transformer Relay 8 34 Date 2013 01 16 ...

Page 405: ...software 9 1 9 3 Signal List 9 2 9 3 1 Input Signals 9 2 9 3 2 Output Signals 9 7 9 3 1 Signals of Intermediate Variable Element 9 10 9 4 Configurable LED Indicators 9 11 List of Tables Table 9 3 1 Configurable input signals 9 2 Table 9 3 2 Configurable output signals 9 7 Table 9 3 3 Configurable signals of intermediate variable element 9 11 Table 9 4 1 Configuralbe LED indicator list 9 11 ...

Page 406: ...9 Configurable Function PCS 978 Transformer Relay 9 b Date 2013 01 16 ...

Page 407: ...figuration files through Ethernet net off line mode off line setting configuration In addition it also supports programmable logic to meet customer s demand After function configuration is finished disabled protection function will be hidden in the device and in setting configuration list of PCS Explorer Software The user can select to show or hide some setting by this way and modify the setting v...

Page 408: ...ata input 1 for reactor differential protection 12 87R I3P2 Three phase current data input 2 for reactor differential protection 13 87R En1 Input signal 1 of enabling reactor differential protection 14 87R En2 Input signal 2 of enabling reactor differential protection 15 87R Blk Input signal of blocking reactor differential protection 16 64REF I3P1 Three phase current data input 1 for restricted e...

Page 409: ...frequency data input for underfrequency protection 48 81U En1 Input signal 1 of enabling underfrequency protection 49 81U En2 Input signal 2 of enabling underfrequency protection 50 81U Blk Input signal of blocking underfrequency protection 51 MR Input1 Mechanical relay MR signal input 1 52 MR Input2 Mechanical relay MR signal input 2 53 MR Input3 Mechanical relay MR signal input 3 54 MR Input4 Me...

Page 410: ...51P1 En2 Input signal 2 of enabling phase overcurrent protection stage 1 of x side 82 x 50 51P2 En2 Input signal 2 of enabling phase overcurrent protection stage 2 of x side 83 x 50 51P3 En2 Input signal 2 of enabling phase overcurrent protection stage 3 of x side 84 x 50 51P4 En2 Input signal 2 of enabling phase overcurrent protection stage 4 of x side 85 x 50 51P1 Blk Input signal of blocking ph...

Page 411: ...cluding calculated residual current 111 x 50 51Q1 En1 Input signal 1 of enabling negative sequence overcurrent protection stage 1 of x side 112 x 50 51Q2 En1 Input signal 1 of enabling negative sequence overcurrent protection stage 2 of x side 113 x 50 51Q1 En2 Input signal 2 of enabling negative sequence overcurrent protection stage 1 of x side 114 x 50 51Q2 En2 Input signal 2 of enabling negativ...

Page 412: ...of enabling thermal overload protection of x side 143 x 49 Blk Input signal of blocking thermal overload protection of x side 144 x 50BF I3P Three phase current data input for breaker failure protection of x side including calculated residual current 145 x 50BF Init Input signal of initiating breaker failure protection of x side 146 x 50BF En1 Input signal 1 of enabling break failure protection of...

Page 413: ...age of x side 177 x Volt3P uc Sampled value of Phase C voltage of x side 178 x Volt3P 52b Binary input of auxiliary normally closed contact of a circuit breaker of x side 179 x Volt3P In_VT Input signal of indicating VT in service of x side 180 x Volt3P OnLoad A flag indicating sampled current valid of three phase voltage element of x side 181 x Curr1P 3i0 Measured residual current of x side 182 x...

Page 414: ...arm stage of overexcitation protection starts 26 24T2 Alm Alarm stage of overexcitation protection operates 27 24IDMT St Inverse time overexcitation protection starts 28 24IDMT Op Inverse time overexcitation protection operates 29 24IDMT Alm Inverse time overexcitation protection issues alarm signal 30 81O St Overfrequency protection starts 31 81O OF1 Op Overfrequency protection stage 1 operates 3...

Page 415: ...3 St Ground overcurrent protection stage 3 of x side starts 70 x 50 51G4 St Ground overcurrent protection stage 4 of x side starts 71 x 50 51G1 Op Ground overcurrent protection stage 1 of x side operates 72 x 50 51G2 Op Ground overcurrent protection stage 2 of x side operates 73 x 50 51G3 Op Ground overcurrent protection stage 3 of x side operates 74 x 50 51G4 Op Ground overcurrent protection stag...

Page 416: ...ates to issue alarm command 105 x 50PAlm1 St Phase overcurrent alarm stage 1 of x side starts 106 x 50PAlm2 St Phase overcurrent alarm stage 2 of x side starts 107 x 59GAlm Alm Residual overvoltage alarm element of x side operates to issue alarm command 108 x 59GAlm St Residual overvoltage alarm element of x side starts 109 x Curr3P I3P A three phase current data set of x side 110 x Curr3P Ang Ia ...

Page 417: ... of intermediate variable 11 for logic programming 12 Sig_Spare12 Signal of intermediate variable 12 for logic programming 13 Sig_Spare13 Signal of intermediate variable 13 for logic programming 14 Sig_Spare14 Signal of intermediate variable 14 for logic programming 15 Sig_Spare15 Signal of intermediate variable 15 for logic programming 16 Sig_Spare16 Signal of intermediate variable 16 for logic p...

Page 418: ...grammable LED indicator 13 in13 The No 13 programmable LED indicator 14 in14 The No 14 programmable LED indicator 15 in15 The No 15 programmable LED indicator 16 in16 The No 16 programmable LED indicator 17 in17 The No 17 programmable LED indicator 18 in18 The No 18 programmable LED indicator 19 in19 The No 19 programmable LED indicator 20 in20 The No 20 programmable LED indicator NOTE The No 3 LE...

Page 419: ...10 3 3 Time Synchronization 10 5 10 3 4 Spontaneous Events 10 5 10 3 5 General Interrogation 10 6 10 3 6 General Functions 10 6 10 3 7 Disturbance Records 10 6 10 4 IEC60870 5 103 Interface over Ethernet 10 6 10 5 Messages Description for IEC61850 Protocol 10 6 10 5 1 Overview 10 6 10 5 2 Communication Profiles 10 7 10 5 3 MMS Communication Network Deployment 10 8 10 5 4 Server Data Organization 1...

Page 420: ...A RS 485 bus connection arrangements 10 2 Figure 10 2 2 Ethernet communication cable 10 3 Figure 10 2 3 Ethernet communication structure 10 4 Figure 10 5 1 Dual net full duplex mode sharing the RCB block instance 10 9 Figure 10 5 2 Dual net hot standby mode sharing the same RCB instance 10 10 Figure 10 5 3 Dual net full duplex mode with 2 independent RCB instances 10 11 ...

Page 421: ...orts and each port has three terminals in the 12 terminal screw connector located on the back of the relay and each port has a ground terminal for the earth shield of the communication cable Please refer to the section of Communication Interface module for details of the connection terminals The rear ports provide RS 485 serial data communication and are intended for use with a permanently wired c...

Page 422: ...d to the bus At no stage must the signal ground be connected to the cables screen or to the product s chassis This is for both safety and noise reasons 10 2 1 4 Biasing It may also be necessary to bias the signal wires to prevent jabber Jabber occurs when the signal level has an indeterminate state because the bus is not being actively driven This can occur when all the slaves are in receive mode ...

Page 423: ... 10 2 2 Ethernet Interface This protective device can provide four rear Ethernet interfaces optional and they are unattached each other Parameters of each Ethernet port can be configured in the submenu Communication Settings 10 2 2 1 Ethernet Standardized Communication Cable It is recommended to use twisted screened eight core cable as the communication cable A picture is shown bellow Figure 10 2 ...

Page 424: ...on the relevant settings of the protective device must be configured To do this use the keypad and LCD user interface In the submenu Communication Settings set the parameters Protocol_RS485A Protocol_RS485B Baud_RS485A and Baud_RS485B For using the Ethernet port with IEC60870 5 103 communication the IP address and submask of each Ethernet port can be set in the same submenu Please refer to the cor...

Page 425: ...chronization feature of the IEC60870 5 103 protocol The protective device will correct for the transmission delay as specified in IEC60870 5 103 If the time synchronization message is sent as a send confirm message then the protective device will respond with a confirmation Whether the time synchronization message is sent as a send confirmation or a broadcast send no reply message a time synchroni...

Page 426: ...e device store the disturbance records The disturbance records are stored in uncompressed format and can be extracted by using the standard mechanisms described in IEC60870 5 103 10 4 IEC60870 5 103 Interface over Ethernet The IEC60870 5 103 interface over Ethernet is a master slave interface with the relay as the slave device It is properly developed by NR too All the service of this relay is bas...

Page 427: ...ese documents can be obtained from the IEC http www iec ch It is strongly recommended that all those involved with any IEC 61850 implementation obtain this document set 10 5 2 Communication Profiles The PCS 978 series relays supports IEC 61850 server services over TCP IP communication protocol stacks The TCP IP profile requires the PCS 978 series relays to have an IP address to establish communica...

Page 428: ...D file is the combination of the individual ICD files and the SSD file Moreover add communication system parameters MMS GOOSE control block SV control block and the connection relationship of GOOSE and SV to SCD file 10 5 3 MMS Communication Network Deployment To enhance the stability and reliability of SAS dual MMS Ethernet is widely adopted This section is applied to introduce the details of dua...

Page 429: ...ag of the RCB instance will automatically change to false In normal operation status of mode 1 IED provides the same MMS service for Net A and Net B If one net is physically disconnected i e Abnormal operation status in above figure the working mode will switch to single net mode seamlessly and immediately Network communication supervision is unnecessary here and Buffered Report Control Block abbr...

Page 430: ...alse Meanwhile the client will detect the failure by heartbeat message or keep alive it will automatically enable the RCB instance by setting RptEna back to true through standby MMS link By the buffer function of BRCB the IED can provide uninterrupted MMS service on the standby net However the differences of BRCB standards among different manufacturers may cause data loss Moreover if duration of n...

Page 431: ...lation is required for the client Moreover accurate clock synchronization of the IED is required to distinguish whether 2 reports are the same report according to the timestamps Clock synchronization error of the IED may lead to report loss redundancy As a conclusion In mode 2 it s difficult to realize seamless switchover between dual nets In mode 3 the IED may be unable to provide enough report i...

Page 432: ...ate changes All needed status data objects are transmitted to HMI clients via buffered reporting and the corresponding buffered reporting control block BRCB is defined in LLN0 10 5 4 2 Analog Values Most of analog measured values are available through the MMXU logical nodes and metering values in MMTR the others in MMXN MSQI and so on Each MMXU logical node provides data from an IED current voltag...

Page 433: ...from related module for the corresponding element Similar to digital status values the protection trip information is reported via BRCB and it also locates in LLN0 10 5 4 4 LLN0 and Other Logical Nodes Logical node LLN0 is essential for an IEC61850 based IED This LN shall be used to address common issues for Logical Devices Most of the public services the common settings control values and some de...

Page 434: ...ll enabled channels are included in the recording independently of the trigger mode 10 5 5 Server Features and Configuration 10 5 5 1 Buffered unbuffered Reporting IEC61850 buffered and unbuffered reporting control blocks locate in LLN0 they can be configured to transmit information of protection trip information in the Protection logical nodes binary status values in GGIO and analog measured calc...

Page 435: ...OSE services provide virtual LAN VLAN support Ethernet priority tagging and Ether type Application ID configuration The support for VLANs and priority tagging allows for the optimization of Ethernet network traffic GOOSE messages can be given a higher priority than standard Ethernet traffic and they can be separated onto specific VLANs Devices that transmit GOOSE messages also function as servers ...

Page 436: ...Y B24 SCSM other N N N Generic Substation Event Model GSE B31 Publisher side O Y B32 Subscriber side O Y Transmission Of Sampled Value Model SVC B41 Publisher side O N B42 Subscriber side O N Where C1 Shall be M if support for LOGICAL DEVICE model has been declared O Optional M Mandatory Y Supported by PCS 978 relay N Currently not supported by PCS 978 relay 10 5 6 2 ACSI Models Conformance Statem...

Page 437: ...nce number Y Y Y M8 2 report time stamp Y Y Y M8 3 reason for inclusion Y Y Y M8 4 data set name Y Y Y M8 5 data reference Y Y Y M8 6 BufTm N N N M8 7 IntgPd N Y Y Logging M9 Log control O O N M9 1 IntgPd N N N M10 Log O O N GSE M12 GOOSE O O Y M13 GSSE O O N M14 Multicast SVC O O N M15 Unicast SVC O O N M16 Time M M Y M17 File transfer O O Y Where C2 Shall be M if support for LOGICAL NODE model h...

Page 438: ...sociation S2 Associate M Y S3 Abort M Y S4 Release M Y Logical device S5 LogicalDeviceDirectory M Y Logical node S6 LogicalNodeDirectory M Y S7 GetAllDataValues M Y Data S8 GetDataValues M Y S9 SetDataValues M Y S10 GetDataDirectory M Y S11 GetDataDefinition M Y Data set S12 GetDataSetValues M Y S13 SetDataSetValues O S14 CreateDataSet O S15 DeleteDataSet O S16 GetDataSetDirectory M Y Substitution...

Page 439: ...Unbuffered report control block S27 Report M Y S27 1 data change M Y S27 2 qchg change M Y S27 3 data update M Y S28 GetURCBValues M Y S29 SetURCBValues M Y Logging Log control block S30 GetLCBValues O S31 SetLCBValues O Log S32 QueryLogByTime O S33 QueryLogAfter O S34 GetLogStatusValues O Generic substation event model GSE GOOSE control block S35 SendGOOSEMessage M Y S36 GetGoReference O S37 GetG...

Page 440: ...ing table Note that the actual instantiation of each logical node is determined by the product order code Nodes PCS 978 L System Logical Nodes LPHD Physical device information YES LLN0 Logical node zero YES P Logical Nodes For Protection Functions PDIF Differential YES PDIR Direction comparison PDIS Distance YES PDOP Directional overpower PDUP Directional underpower PFRC Rate of change of frequenc...

Page 441: ...ed R Logical Nodes For Protection Related Functions RDRE Disturbance recorder function YES RADR Disturbance recorder channel analogue RBDR Disturbance recorder channel binary RDRS Disturbance record handling RBRF Breaker failure YES RDIR Directional element YES RFLO Fault locator RPSB Power swing detection blocking YES RREC Autoreclosing RSYN Synchronism check or synchronizing C Logical Nodes For ...

Page 442: ...n phase related harmonics or interharmonic MMTR Metering MMXN Non phase related measurement MMXU Measurement YES MSQI Sequence and imbalance MSTA Metering statistics S Logical Nodes For Sensors And Monitoring SARC Monitoring and diagnostics for arcs SIMG Insulation medium supervision gas SIML Insulation medium supervision liquid SPDC Monitoring and diagnostics for partial discharges X Logical Node...

Page 443: ...he DNP3 0 implementation This manual only specifies which objects variations and qualifiers are supported in this relay and also specifies what data is available from this relay via DNP3 0 The relay operates as a DNP3 0 slave and supports subset level 2 of the protocol plus some of the features from level 3 The DNP3 0 communication uses the Ethernet ports at the rear of this relay 10 6 2 Link Laye...

Page 444: ...orted Reading Functions 1 Supported qualifiers Master Qualifier 0x00 0x01 0x06 0x07 0x08 Slave Qualifier 0x00 0x01 0x01 0x07 0x08 2 Supported objects and variations Object 1 Binary inputs Master Variation 0x00 0x01 0x02 Slave Variation 0x02 0x01 0x02 The protection operation signals alarm signals and binary input state change signals are transported respectively according to the variation sequence...

Page 445: ...st and the variation is 0x01 The slave responds with the above mentioned Object 1 Object 30 and Object 40 see Supported objects and variations in Section 10 6 4 3 4 Class 1 data request The master adopts the Object 60 for the Class 1 data request and the variation is 0x02 The slave responds with the above mentioned Object 2 see Supported objects and variations in Section 10 6 4 3 5 Multiple object...

Page 446: ...10 Communication PCS 978 Transformer Relay 10 26 Date 2013 01 16 ...

Page 447: ...Grounding 11 4 11 7 3 Ground Connection on the Device 11 5 11 7 4 Grounding Strips and their Installation 11 6 11 7 5 Guidelines for Wiring 11 6 11 7 6 Wiring for Electrical Cables 11 7 Table of Figures Figure 11 6 1 Dimensions of PCS 978 11 3 Figure 11 6 2 Panel cut out dimensions of PCS 978 11 3 Figure 11 6 3 Demonstration of plugging a board into its corresponding slot 11 4 Figure 11 7 1 Cubicl...

Page 448: ...11 Installation PCS 978 Transformer Relay 11 b Date 2012 10 09 ...

Page 449: ...gineering configuration after replacement It is therefore assumed that the personnel who replace modules and units are familiar with the use of the operator program on the service PC DANGER Only insert or withdraw the PWR module while the power supply is switched off To this end disconnect the power supply cable that connects with the PWR module WARNING Only insert or withdraw other modules while ...

Page 450: ...notify the nearest NR Company or agent If the equipment is not going to be installed immediately store all the parts in their original packing in a clean dry place at a moderate temperature The humidity at a maximum temperature and the permissible storage temperature range in dry air are listed in Section 2 1 3 11 4 Material and Tools Required The necessary mounting kits will be provided including...

Page 451: ...RNING Excessively high temperature can appreciably reduce the operating life of this relay 11 6 Mechanical Installation This relay is made of a single layer 4U height 19 chassis with 8 connectors on its rear panel Following two figures show the dimensions of this relay for reference in mounting 291 482 6 465 0 101 6 177 0 Figure 11 6 1 Dimensions of PCS 978 465 0 450 0 179 0 101 6 4 Ф6 8 Figure 11...

Page 452: ... in electrical installations that can induce spurious currents in the devices themselves or the leads connected to them All these influences can influence the operation of electronic apparatus On the other hand electronic apparatus can transmit interference that can disrupt the operation of other apparatus In order to minimize these influences as far as possible certain standards have to be observ...

Page 453: ... the voltage difference of both materials according to the electrochemical code The cubicle ground rail must be effectively connected to the station ground rail by a grounding strip braided copper Door or hinged equipment frame Cubicle ground rail close to floor Station ground Braided copper strip Conducting connection Figure 11 7 1 Cubicle grounding system 11 7 3 Ground Connection on the Device T...

Page 454: ...items to be connected The surfaces to which the grounding strips are bolted must be electrically conducting and non corroding The following figure shows the ground strip and termination Braided copper strip Press pinch fit cable terminal Terminal bolt Contact surface Figure 11 7 3 Ground strip and termination 11 7 5 Guidelines for Wiring There are several types of cables that are used in the conne...

Page 455: ...ther details about the pin defines of these connectors The following figure shows the glancing demo about the wiring for the electrical cables 01 02 03 04 05 06 07 09 10 11 12 13 14 15 16 24 23 22 21 20 19 18 17 08 01 Tighten Figure 11 7 4 Glancing demo about the wiring for electrical cables DANGER Never allow the current transformer CT secondary circuit connected to this equipment to be opened wh...

Page 456: ...11 Installation PCS 978 Transformer Relay 11 8 Date 2012 10 09 ...

Page 457: ...ble of Contents 12 1 General 12 1 12 2 Safety Instructions 12 1 12 3 Commission Tools 12 2 12 4 Setting Familiarization 12 2 12 5 Product Checks 12 3 12 5 1 With the Relay De energized 12 3 12 5 2 With the Relay Energized 12 5 12 5 3 Print Fault Report 12 8 12 5 4 On load Checks 12 9 ...

Page 458: ...12 Commissioning PCS 978 Transformer Relay 12 b Date 2012 12 07 ...

Page 459: ...pment during operation Non observance of the safety rules can result in severe personal injury or property damage WARNING Only the qualified personnel shall work on and around this equipment after becoming thoroughly familiar with all warnings and safety notices of this manual as well as with the applicable safety regulations Particular attention must be drawn to the following The earthing screw o...

Page 460: ...ic or brushless insulation tester with a DC output not exceeding 500V for insulation resistance test when required A portable PC with appropriate software this enables the rear communications port to be tested if this is to be used and will also save considerable time during commissioning EIA RS 485 to EIA RS 232 converter if EIA RS 485 IEC60870 5 103 port is being tested PCS 978 serials dedicated...

Page 461: ... later This could be done by extracting the settings from the relay itself via printer or manually creating a setting record 12 5 1 With the Relay De energized This relay is fully numerical and the hardware is continuously monitored Commissioning tests can be kept to a minimum and need only include hardware tests and conjunctive tests The function tests are carried out according to user s correlat...

Page 462: ...no connection failure exists Label Check all the isolator binary inputs terminal blocks indicators switches and push buttons to make sure that their labels meet the requirements of this project Equipment plug in modules Check each plug in module of the equipment on the panel to make sure that they are well installed into the equipment without any screw loosened Earthing cable Check whether the ear...

Page 463: ...th the customer s normal practice 12 5 1 4 Auxiliary Power Supply The relay only can be operated under the auxiliary power supply depending on the relay s nominal power supply rating The incoming voltage must be within the operating range specified in Section 2 1 2 before energizing the relay measure the auxiliary supply to ensure it within the operating range Other requirements to the auxiliary p...

Page 464: ...cators may also illuminate when the auxiliary supply is applied If any of these LEDs are on then they should be reset before proceeding with further testing If the LED successfully reset the LED goes out There is no testing required for that that LED because it is known to be operational It is likely that alarms related to voltage transformer supervision will not reset at this stage 12 5 2 4 Testi...

Page 465: ...t 3I0 12 5 2 7 Testing the AC Voltage Inputs This test verified that the accuracy of voltage measurement is within the acceptable tolerances Apply rated voltage to each voltage transformer input in turn checking its magnitude by using a multimeter test set readout The corresponding reading can then be checked in the relays menu The measurement accuracy of the relay is 2 5 or 0 1V However an additi...

Page 466: ...a de energized input Binary inputs testing checkout Terminal No Signal Name BI Status on LCD Correct Test method To unplug all the terminals sockets of this protective device and do the Insulation resistance test for each circuit above with an electronic or brushless insulation tester On completion of the insulation resistance tests ensure all external wiring is correctly reconnected to the protec...

Page 467: ...m the protection in order to perform any of the foregoing tests it should be ensured that all connections are replaced in accordance with the relevant external connection or scheme diagram Confirm current and voltage transformer wiring 12 5 4 1 Final Checks After the above tests are completed remove all test or temporary shorting leads etc If it has been necessary to disconnect any of the external...

Page 468: ...12 Commissioning PCS 978 Transformer Relay 12 10 Date 2012 12 07 ...

Page 469: ...e PCS 978 Transformer Relay 13 a Date 2012 10 09 13 Maintenance Table of Contents 13 1 Appearance Check 13 1 13 2 Failure Tracing and Repair 13 1 13 3 Replace Failed Modules 13 1 13 4 Cleaning 13 3 13 5 Storage 13 3 ...

Page 470: ...13 Maintenance PCS 978 Transformer Relay 13 b Date 2012 10 09 ...

Page 471: ...ood condition The keys on the front panel with very good feeling can be operated flexibly It is only allowed to plug or withdraw relay board when the supply is reliably switched off Never allow the CT secondary circuit connected to this equipment to be opened while the primary system is live when withdrawing an AC module Never try to insert or withdraw the relay board when it is unnecessary Check ...

Page 472: ...and placing modules on an earthed conductive mat Otherwise many of the electronic components could suffer damage After replacing the MON or DSP module check the settings 1 Replacing a module Switch off the power supply Disconnect the trip outputs Short circuit all AC current inputs and disconnect all AC voltage inputs Unscrew the module WARNING Hazardous voltage can be present in the DC circuit ju...

Page 473: ...le check the settings DANGER After replacing modules be sure to check that the same configuration is set as before the replacement If this is not the case there is a danger of the unintended operation of switchgear taking place or of protections not functioning correctly Persons may also be put in danger 13 4 Cleaning Before cleaning the relay ensure that all AC DC supplies current transformer con...

Page 474: ...13 Maintenance PCS 978 Transformer Relay 13 4 Date 2012 10 09 ...

Page 475: ...osal PCS 978 Transformer Relay 14 a Date 2012 10 09 14 Decommissioning and Disposal Table of Contents 14 1 Decommissioning 14 1 14 1 1 Switching off 14 1 14 1 2 Disconnecting Cables 14 1 14 1 3 Dismantling 14 1 14 2 Disposal 14 1 ...

Page 476: ...14 Decommissioning and Disposal PCS 978 Transformer Relay 14 b Date 2012 10 09 ...

Page 477: ...ker of the power supply is switched off DANGER Before disconnecting the cables that are used to connect analog input module with the primary CTs and VTs make sure that the primary CTs and VTs aren t in service 14 1 3 Dismantling The PCS 978 rack may now be removed from the system cubicle after which the cubicles may also be removed DANGER When the station is in operation make sure that there is an...

Page 478: ...14 Decommissioning and Disposal PCS 978 Transformer Relay 14 2 Date 2012 10 09 ...

Page 479: ... leaf format 2 00 2 01 R1 10 2011 08 18 1 Add breaker failure protection 2 Add pole disagreement protection 2 01 2 02 R1 11 2011 11 21 1 Mechanical IO module NR1533 is replaced by NR1536 2 Add description of inrush current blocking 2 02 2 03 R1 11 2012 10 09 1 Hardware module changes module NR1301A is replaced by module NR1301T Module NR1520D is replaced by NR1502M and add NR1521C module 2 Add a t...

Page 480: ...15 Manual Version History PCS 978 Transformer Relay 15 2 Date 2013 01 16 ...

Search results

Summary of Contents for PCS-978

Reviews:

Related manuals for PCS-978

Brands by name

Popular brands

NR Electric PCS-978, Instruction Manual

Search results

Summary of Contents for PCS-978

Reviews:

Related manuals for PCS-978

Brands by name

Popular brands