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Instruction BookPart 1 of 2

M-3425AGenerator Protection

Generator ProtectionM-3425A

Integrated Protection System® for Generators of All Sizes

Unit shown with optional M-3925A Target Module and M-3931 HMI (Human-Machine Interface) Module.

PROTECTION

• Exceeds IEEE C37.102 and Standard 242 requirements for generatorprotection

• Protects generators of any prime mover, grounding and connection type• Provides all major protective functions for generator protection including

Out-of-Step (78), Split-Phase Differential (50DT), Under Frequency TimeAccumulation (81A), Inadvertent Energizing (50/27) and Turn-to-Turn Fault(59X)

• Expanded IPScom® Communications Software provides simple and logicalsetting and programming, including logic schemes

• Simple application with Base and Comprehensive protection packages

• Load encroachment blinders and power swing blocking for systembackup protection (21) to enchance security during system abnormalconditions

• Options: Ethernet Connection, Field Ground/Brush Lift-OffProtection (64F/B), Sync Check (25), 100% Stator GroundFault Protection by low frequency injection (64S) andExpanded I/O (15 additional Output Contacts and 8 additionalControl/Status Inputs)

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M-3425A Generator Protection Relay

Optional Protective Functions• Sync Check with Phase Angle, ΔV and ΔF

with dead line/dead bus options (25)• Field Ground (64F) and Brush Lift Off (64B)

(Includes M-3921 Field Ground Coupler)• 100% Stator Ground protection by low fre-

quency injection (64S). The following equip-ment is supplied with the 64S option:– 20 Hz signal generator (430-00426)– Band-pass Filter (430-00429)

– 400/5 A 20 Hz CT (430-00428)

Standard Features• Eight programmable outputs and six pro-

grammable inputs• Oscillographic recording with COMTRADE

or BECO format• Time-stamped target storage for 32 events• Metering of all measured parameters and

calculated values• Three communications ports (two RS-232

and one RS-485)• M-3820D IPScom® Communications Soft-

ware• Includes MODBUS and BECO 2200

protocols• Standard 19" rack-mount design (vertical

mounting available)• Removable printed circuit board and power

supply• 50 and 60 Hz models available• Both 1A and 5 A rated CT inputs available• Additional trip inputs for externally connected

devices• IRIG-B time synchronization• Operating Temperature: –20° C to +70° C• Sequence of Events Log• Trip Circuit Monitoring• Breaker Monitoring• Four Setpoint Groups

Optional Features• Redundant power supply• M-3925A Target Module• M-3931 Human-Machine Interface (HMI)

Module• RJ45 Ethernet port utilizing MODBUS over TCP/

IP and BECO2200 over TCP/IP protocols• RJ45 Ethernet port utilizing IEC 61850 Protocol• M-3801D IPSplot® PLUS Oscillograph Analy-

sis Software• Expanded I/O (15 additional outputs and 8

additional inputs)

Protective FunctionsBase Package

• Overexcitation (V/Hz) (24)• Phase Undervoltage (27)• Directional power sensitive triple-setpoint Re-

verse Power, Low Forward Power or Over-power detection, one of which can be used forsequential tripping (32)

• Dual-zone, offset-mho Loss of Field (40), whichmay be applied with undervoltage controlledaccelerated tripping

• Sensitive Negative Sequence Overcurrent pro-tection and alarm (46)

• Instantaneous Phase Overcurrent (50)• Inadvertent Energizing (50/27)• Generator Breaker Failure (50BF)• Instantaneous Neutral Overcurrent (50N)• Inverse Time Neutral Overcurrent (51N)• Three-phase Inverse Time Overcurrent

(51V) with voltage control and voltage restraint.• Phase Overvoltage (59)• Neutral Overvoltage (59N)• Multi-purpose Overvoltage (59X)• VT Fuse-Loss Detection and blocking

(60FL)• Residual Directional Overcurrent (67N)• Four-step Over/Underfrequency (81)• Phase Differential Current (87)• Ground (zero sequence) Differential Cur-

rent (87GD)• IPSlogic takes the contact input status and

function status and generates outputs byemploying (OR, AND, and NOT) booleanlogic and a timer.

Protective FunctionsComprehensive PackageThe Comprehensive Package includes all BasePackage functions, as well as the following:

• Three-zone Phase Distance protection forphase fault backup protection (21). Zone threecan be used for Out-of-Step Blocking. Loadencroachment blinders can be applied.

• 100% Stator Ground Fault protection using ThirdHarmonic Neutral Undervoltage (27TN) or (59D)Third Harmonic Voltage Differential (ratio)

• Stator Overload (49) (Positive SequenceOvercurrent)

• Definite Time Overcurrent (50DT) can be usedfor split phase differential

• Out-of-Step (78)• UnderFrequency Accumulation (81A)• Rate of Change of Frequency (81R)

–3–


PROTECTIVE FUNCTIONSDevice SetpointNumber Function Ranges Increment Accuracy†

Phase Distance (three-zone mho characteristic)

Circle Diameter #1,#2,#3 0.1 to 100.0 Ω 0.1 Ω 0.1 Ω or 5%(0.5 to 500.0 Ω) ( 0.5 Ω or 5%)

Offset #1,#2,#3 –100.0 to 100.0 Ω 0.1 Ω 0.1 Ω or 5%(–500.0 to 500.0 Ω) ( 0.5 Ω or 5%)

Impedance Angle #1,#2,#3 0° to 90° 1° 1°

Load Encroachment Blinder #1,#2,#3Angle 1° to 90° 1° 1°R Reach 0.1 to 100 Ω

Time Delay #1,#2,#3 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Out-of-Step Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Overcurrent Supervision 0.1 to 20 A 0.1 A 0.1 A or 2%(0.02 to 4 A) 0.01 A 0.02 A or 2%

When out-of-step blocking on Zone 1 or Zone 2 is enabled, Zone 3 will not trip and it will be used to detect theout-of-step condition for blocking Function 21 #1 and/or 21 #2.

Volts / Hz

Definite TimePickup #1, #2 100 to 200% 1% 1%

Time Delay #1, #2 30 to 8160 Cycles 1 Cycle 25 Cycles

Inverse Time

Pickup 100 to 200% 1% 1%Characteristic Curves Inverse Time #1–#4 — —

Time Dial: Curve #1 1 to 100 1Time Dial: Curves #2–#4 0.0 to 9.0 0.1

Reset Rate 1 to 999 Sec. 1 Sec. .02 Sec. or 1%(from threshold of trip)

The percent pickup is based on nominal VT secondary voltage and nominal system frequency settings. Thepickup accuracy stated is only applicable from 10 to 80 Hz, 0 to 180 V, 100 to 150% V/Hz and a nominal voltagesetting of 120 V.

Phase Undervoltage

Pickup #1, #2, #3 5 to 180 V 1 V 0.5 V or 0.5%0.8 V or 0.75%*

Time Delay #1, #2, #3 1 to 8160 Cycles 1 Cycle 1 Cycle or 0.5%**

* When both RMS and Line-Ground to Line-Line VT connection is selected.

**When RMS (total waveform) is selected, timing accuracy is O20 cycles or 1%.

†Select the greater of these accuracy values. Values in parentheses apply to 1 A CT secondary rating.

21

24

27

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PROTECTIVE FUNCTIONS (cont.)Device SetpointNumber Function Ranges Increment Accuracy†

Third-Harmonic Undervoltage, Neutral

Pickup #1, #2 0.10 to 14.00 V 0.01 V 0.1 V or 1%

Positive SequenceVoltage Block 5 to 180 V 1 V 0.5 V or 0.5%

Forward Under Power Block 0.01 to 1.00 PU 0.01 PU 0.01 PU or 2%

Reverse Under Power Block –1.00 to –0.01 PU 0.01 PU 0.01 PU or 2%

Lead Under var Block –1.00 to –0.01 PU 0.01 PU 0.01 PU or 2%

Lag Under var Block 0.01 to 1.00 PU 0.01 PU 0.01 PU or 2%

Lead Power Factor Block 0.01 to 1.00 0.01 0.03 PU or 3%

Lag Power Factor Block 0.01 to 1.00 0.01 0.03 PU or 3%

High Band ForwardPower Block 0.01 to 1.00 PU 0.01 PU 0.01 PU or 2%

Low Band ForwardPower Block 0.01 to 1.00 PU 0.01 PU 0.01 PU or 2%

Time Delay #1, #2 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Directional Power

Pickup #1, #2, #3 –3.000 to +3.000 PU 0.001 PU 0.002 PU or 2%

Time Delay #1, #2, #3 1 to 8160 Cycles 1 Cycle +16 Cycles or 1%

The minimum Pickup limits are –.002 and +.002 respectively.

The per-unit pickup is based on nominal VT secondary voltage and nominal CT secondary current settings. Thisfunction can be selected as either overpower or underpower in the forward direction (positive setting) or reversedirection (negative setting). Element #3 can be set as real power or reactive power. This function includes aprogrammable target LED that may be disabled.

Loss of Field (dual-zone offset-mho characteristic)

Circle Diameter #1, #2 0.1 to 100.0 Ω 0.1 Ω 0.1 Ω or 5%(0.5 to 500.0 Ω) ( 0.5 Ω or 5%)

Offset #1, #2 –50.0 to 50.0 Ω 0.1 Ω 0.1 Ω or 5%(–250.0 to 250.0 Ω) ( 0.5 Ω or 5%)


Time Delay withVoltage Control #1, #2 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Voltage Control 5 to 180 V 1 V 0.5 V or 0.5%(positive sequence)

Directional Element 0° to 20° 1° —

Time delay with voltage control for each zone can be individually enabled.


40

32

27TN

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Negative Sequence Overcurrent

Definite TimePickup 3 to 100% 1% 0.5% of 5 A

( 0.5% of 1 A)

Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Inverse TimePickup 3 to 100% 1% 0.5 % of 5 A

( 0.5% of 1 A)

Time Dial Setting 1 to 95 1 3 Cycles or 3%(K= I2

2t)

Definite MaximumTime to Trip 600 to 65,500 Cycles 1 Cycle 1 Cycle or 1%

Definite Minimum Time 12 Cycles — fixed

Reset Time (Linear) 1 to 600 Seconds 1 Second —(from threshold of trip)

Pickup is based on the generator nominal current setting.

Stator Overload Protection

Time Constant #1, #2 1.0 to 999.9 minutes 0.1 minutes

Maximum Overload Current 1.00 to 10.00 A 0.01 A 0.1 A or 2%(0.20 to 2.00 A)

Instantaneous Phase Overcurrent

Pickup #1, #2 0.1 to 240.0 A 0.1 A 0.1 A or 3%(0.1 to 48.0 A) ( 0.02 A or 3%)


When frequency f is < (fnom –5 ) Hz add an additional time of (1.5/f + 0.033) sec to the time delay accuracy.

Breaker Failure

PickupPhase Current 0.10 to 10.00 A 0.01 A 0.1 A or 2%

(0.02 to 2.00 A) ( 0.02 A or 2%)

Neutral Current 0.10 to 10.00 A 0.01 A 0.1 A or 2%(0.02 to 2.00 A) ( 0.02 A or 2%)


50BF can be initiated from designated M-3425A output contacts or programmable control/status inputs.

Definite Time Overcurrent

Pickup Phase A #1, #2 0.20 A to 240.00 A 0.01 A 0.1 A or 3%(0.04 A to 48.00 A) ( 0.02 A or 3%)

Pickup Phase B #1, #2 (same as above)

Pickup Phase C #1, #2 (same as above)


This function uses generator line-side currents.

When 50DT function is used for split-phase differential protection, 50BF, 87, and 87GD functions should not beused, and the IA, IB and IC inputs must be connected to the split phase differential currents.†Select the greater of these accuracy values. Values in parentheses apply to 1 A CT secondary rating.

50DT

50

50BF

50BF-Ph

50BF-N

46

49

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Instantaneous Neutral Overcurrent

Pickup 0.1 to 240.0 A 0.1 A 0.1 A or 3%(0.1 to 48.0 A) ( 0.02 A or 3%)


When the frequency f is < (fnom –5) Hz add an additional time of (1.5/f + 0.033) sec to the time delay accuracy.

Inadvertent Energizing

OvercurrentPickup 0.5 to 15.00 A 0.01 A 0.1 A or 2%

(0.1 to 3.00 A) ( 0.02 A or 2%)

UndervoltagePickup 5 to 130 V 1 V 0.5 V

Pick-up Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Drop-out Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Inverse Time Neutral Overcurrent


Characteristic Curve Definite Time/Inverse/Very Inverse/Extremely Inverse/IEC CurvesModerately Inverse/Very Inverse/Extremely Inverse/IEEE Curves

Time Dial 0.5 to 11.0 0.1 3 Cycles or 3%*0.05 to 1.10 (IEC curves) 0.01

0.85 to 1.15 (IEEE curves) 0.01

* For IEC Curves the timing accuracy is 5%.

When the frequency f is < (fnom –5 )Hz add an additional time of (1.5/f + 0.033) sec to the time delay accuracy.

Inverse Time Phase Overcurrent, with Voltage Control or Voltage Restraint



Time Dial 0.5 to 11.0 0.1 3 Cycles or 3%*0.05 to 1.10 (IEC curves) 0.01

0.85 to 1.15 (IEEE curves) 0.01

Voltage Control (VC) 5 to 180 V 1 V 0.5 V or 0.5% or

Voltage Restraint (VR) Linear Restraint — —

* For IEC Curves the timing accuracy is 5%.

51V

51N

50N

50/27

50

27


–7–



Phase Overvoltage

Pickup #1, #2, #3 5 to 180 V 1 V 0.5 V or 0.5%0.8 V or 0.75%*

Time Delay #1, #2, #3 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%**

Input Voltage Select Phase, Positive or Negative Sequence***

* When both RMS and Line-Ground to Line-Line is selected.

** When RMS (total waveform) is selected, timing accuracy is +20 cycles or 1%.

*** When positive or negative sequence voltage is selected, the 59 Function uses the discrete Fourier transform(DFT) for magnitude calculation, irrespective of the RMS/DFT selection, and timing accuracy is 1 Cycle or 1%.Positive and negative sequence voltages are calculated in terms of line-to-line voltage when Line to Line isselected for V.T. Configuration.

Third-Harmonic Voltage Differential Ratio

Ratio (Vx/VN) 0.1 to 5.0 0.1


Positive Seq Voltage Block 5 to 180 V 1 V 0.5 V or 0.5%

Line Side Voltage VX or 3V0 (calculated)

The 59D function with VX cannot be enabled if the 25 function is enabled. The line side voltage can be selectedas the third harmonic of 3V0 (equivalent to VA + VB + VC) or VX.

3V0 selection for line side voltage can only be used with line-ground VT configuration.

Neutral Overvoltage

Pickup #1, #2, #3 5.0 to 180.0 V 0.1 V 0.5 V or 0.5%

Time Delay #1, #2, #3 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

When 64S is purchased, the 59N Time Delay Accuracy is –1 to +5 cycles.

Multi-purpose Overvoltage

Pickup #1, #2 5.0 to 180.0 V 0.1 V 0.5 V or 0.5%


Multi-purpose input that may be used for turn-to-turn stator ground protection, bus ground protection, or as anextra Phase-Phase, or Phase-Ground voltage input.

VT Fuse-Loss Detection

A VT fuse-loss condition is detected by using the positive and negative sequence componentsof the voltages and currents. VT fuse-loss output can be initiated from internally generatedlogic, and/or from input contacts.

Alarm Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Three Phase VTFuse Loss Detection Enable/Disable

59

59N

60FL

59X

59D


–8–



Residual Directional Overcurrent

Definite Time*Pickup 0.5 to 240.0 A 0.1 A 0.1 A or 3%

(0.1 to 48.0 A) ( 0.02 A or 3%)

Time Delay 1 to 8160 Cycles 1 Cycle –1 to +3 Cycles or 1%

Inverse Time*Pickup 0.25 to 12.00 A 0.01 A 0.1 A or 3%

(0.05 to 2.40 A) ( 0.02 A or 3%)


Time Dial 0.5 to 11.0 0.1 3 Cycles or 5%0.05 to 1.10 (IEC Curves) 0.010.5 to 11 (IEEE curves) 0.01

Directional ElementMax Sensitivity Angle (MSA) 0 to 359° 1°

Polarizing Quantity 3Vo (calculated), VN or VX

*Directional control for 67NDT or 67NIT may be disabled.VX polarization cannot be used if 25 function is enabled.3Vo polarization can only be used with line-ground VT configuration.Operating current for 67N can be selected as 3Io (calculated) or IN (Residual CT).

If 87GD is enabled, 67N with IN (Residual CT) operating current will not be available.

Out of Step (mho characteristic)

Circle Diameter 0.1 to 100.0 Ω 0.1 Ω 0.1 Ω or 5%(0.5 to 500.0 Ω) ( 0.5 Ω or 5%)

Offset –100.0 to 100.0 Ω 0.1 Ω 0.1 Ω or 5%(–500.0 to 500.0 Ω) ( 0.5 Ω or 5%)

Impedance Angle 0° to 90° 1° 1°

Blinder 0.1 to 50.0 Ω 0.1 Ω 0.1 Ω or 5%(0.5 to 250.0 Ω) ( 0.5 Ω or 5%)


Trip on mho Exit Enable/Disable

Pole Slip Counter 1 to 20 1

Pole Slip Reset 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Frequency

Pickup #1,#2,#3,#4 50.00 to 67.00 Hz 0.01 Hz 0.02 Hz40.00 to 57.00 Hz*

Time Delay #1–#4 3 to 65,500 Cycles 1 Cycle 2 Cycles or 1%

The pickup accuracy applies to 60 Hz models at a range of 57 to 63 Hz, and to 50 Hz models at a range of 47 to53 Hz. Beyond these ranges, the accuracy is 0.1 Hz.

* This range applies to 50 Hz nominal frequency models.


81

78

67N

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Frequency Accumulation

Bands #1, #2, #3, #4, #5, #6High Band #1 50.00 to 67.00 Hz 0.01 Hz 0.02 Hz

40.00 to 57.00 Hz*

Low Band #1–#6 50.00 to 67.00 Hz 0.01 Hz 0.02 Hz40.00 to 57.00 Hz*

Delay #1–#6 3 to 360,000 Cycles 1 Cycle 2 Cycles or 1%

When using multiple frequency bands, the lower limit of the previous band becomes the upper limit for the next band,i.e., Low Band #2 is the upper limit for Band #3, and so forth. Frequency bands must be used in sequential order, 1 to6. Band #1 must be enabled to use Bands #2–#6. If any band is disabled, all following bands are disabled.

When frequency is within an enabled band limit, accumulation time starts (there is an internal ten cycle delay prior toaccumulation) and allows the underfrequency blade resonance to be established to avoid unnecessary accumulationof time. When duration is greater than set delay, the alarm asserts and a target log entry is made.

The pickup accuracy applies to 60 Hz models at a range of 57 to 63 Hz, and 50 Hz models at a range of 47 to 53 Hz.Beyond these ranges, the accuracy is 0.1 Hz.

* This range applies to 50 Hz nominal frequency models.

Rate of Change of Frequency

Pickup #1, #2 0.10 to 20.00 Hz/Sec. 0.01 Hz/Sec. 0.05 Hz/Sec. or 5%

Time Delay #1, #2 3 to 8160 Cycles 1 Cycle + 20 Cycles

Negative SequenceVoltage Inhibit 0 to 99% 1% 0.5%

Phase Differential Current

Pickup #1, #2 0.20 A to 3.00 A 0.01 A 0.1 A or 5%(0.04 to 0.60 A) ( 0.02 A or 5%)

Percent Slope #1, #2 1 to 100% 1% 2%

Time Delay* #1, #2 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

CT Correction** 0.50 to 2.00 0.01 +1 to -2 Cycles or 1%

*When a time delay of 1 cycle is selected, the response time is less than 1–1/2 cycles.

**The CT Correction factor is multiplied by IA,IB,IC.

Ground (zero sequence) Differential Current


Time Delay 1 to 8160 Cycles* 1 Cycle +1 to -2 Cycles or 1%

CT Ratio Correction (RC) 0.10 to 7.99 0.01

*The Time Delay Setting should not be less than 2 Cycles.

The 87GD function is provided primarily for low-impedance grounded generator applications. This functionoperates as a directional differential. If 3I0 or In is extremely small (less than 0.2 secondary Amps), the elementbecomes non-directional.

If 67N function with IN (Residual) operating current is enabled, 87GD will not be available. Also, if 50DT is usedfor split-phase differential, 87GD function will not be available.


87

87GD

81R

81A

–10–



IPSlogicTM

IPSlogic uses element pickups, element trip commands, control/status input state changes,output contact close signals to develop 6 programmable logic schemes.

Time Delay #1–#6 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Breaker Monitoring

Pickup 0 to 50,000 kA Cycles 1 kA Cycles 1 kACyclesor kA2 Cycles or kA2 Cycles or kA2 Cycles

Time Delay 0.1 to 4095.9 Cycles 0.1 Cycles 1 Cycle or 1%

Timing Method IT or I2T

Preset Accumulators 0 to 50,000 kA Cycles 1 kA CyclePhase A, B, C

The Breaker Monitor feature calculates an estimate of the per-phase wear on the breaker contacts by measuring andintegrating the current (or current squared) through the breaker contacts as an arc.

The per-phase values are added to an accumulated total for each phase, and then compared to a user-programmedthreshhold value. When the threshhold is exceeded in any phase, the relay can set a programmable output contact.

The accumulated value for each phase can be displayed.

The Breaker Monitoring feature requires an initiating contact to begin accumulation, and the accumulation beginsafter the set time delay.

Trip Circuit Monitoring


The AUX input is provided for monitoring the integrity of the trip circuit. This input can be used for nominal tripcoil voltages of 24 V dc, 48 V dc, 125 V dc and 250 V dc.

Nominal Settings

Nominal Voltage 50.0 to 140.0 V 0.1 V —

Nominal Current 0.50 to 6.00 A 0.01 A —

VT Configuration Line-Line/Line-Ground/Line-Ground to Line-Line*

Delta/Wye UnitTransformer Disable/Delta AB/Delta AC

Seal-In Delay 2 to 8160 Cycles 1 Cycle 1 Cycle or 1%

*When Line-Ground to Line-Line is selected, the relay internally calculates the line-line voltages from the line-groundvoltages for all voltage-sensitive functions. This Line-Ground to Line-Line selection should only be used for a VTconnected Line-Ground with a secondary voltage of 69 V (not 120 V).


IPS

BM

TC

–11–


64F

64B

25

25S

25D

64S

OPTIONAL PROTECTIVE FUNCTIONSDevice SetpointNumber Function Ranges Increment Accuracy†

Sync Check

Dead CheckDead Voltage Limit 0 to 60 V 1 V 0.5 V or ±0.5%

Dead Time Delay 1 to 8160 Cycles 1 Cycle –1 to +3 Cycles or 1%

Sync CheckPhase Angle Window 0° to 90° 1° 1°

Upper Voltage Limit 60 to 140 V 1 V 0.5 V or ±0.5%

Lower Voltage Limit 40 to 120 V 1 V 0.5 V or ±0.5%

Delta Voltage Limit 1.0 to 50.0 V 0.1 V 0.5 V or ±0.5%

Delta Frequency Limit 0.001 to 0.500 Hz 0.001 Hz 0.0007 Hz or ±5%

Sync Check Time Delay 1 to 8160 Cycles 1 Cycle –1 to +3 Cycles or ±1%

Various combinations of input supervised hot/dead closing schemes may be selected. The 25 function cannot beenabled if the 59D function with VX or 67N function with VX is enabled.

Field Ground Protection

Pickup #1, #2 5 to 100 KΩ 1 KΩ 10% or ±1KΩTime Delay #1, #2 1 to 8160 Cycles 1 Cycle ( 2

IF +1) Sec.

Injection Frequency (IF) 0.10 to 1.00 Hz 0.01 Hz

Brush Lift-Off Detection (measuring control circuit)Pickup 0 to 5000 mV 1 mV

Time Delay 1 to 8160 Cycles 1 Cycle ( 2IF +1) Sec.

When 64F is purchased, an external Coupler Module (M-3921) is provided for isolation from dc field voltages.

Figure 10, Field Ground Protection Block Diagram, illustrates a typical connection utilizing the M-3921 FieldGround Coupler. Hardware dimensional and mounting information is shown in Figure 11, M-3921 Field GroundCoupler Mounting Dimensions.

100% Stator Ground Protection by low frequency injection

Total Current Pickup 2 to 75 mA 0.1 mA 2 mA or 10%Real Component ofTotal Current Pickup 2 to 75 mA 0.1 mA 2 mA or 10%Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle* or 1%

An external Low Frequency Generator, Band Pass Filter and Current Transformer are required for this function.Figure 12, 64S Function Component Connection Diagram, illustrates a typical 100% Stator Ground Protection byLow Frequency Injection application. Hardware dimensional and mounting information is illustrated in Figures13, 14 and 15.

59D and 27TN function should be disabled when the 64S function is enabled. 59N may be applied when thisfunction is enabled.

* Time Delay accuracy in cycles is based on 20 Hz frequency.


–12–


DescriptionThe M-3425A Generator Protection Relay is suitable for all generator ratings and prime movers. Typicalconnection diagrams are illustrated in Figure 4, M-3425A One-Line Functional Diagram (configured for phasedifferential), and Figure 5, One-Line Functional Diagram (configured for split-phase differential).

Configuration OptionsThe M-3425A Generator Protection Relay is available in either a Base or Comprehensive package ofprotective functions. This provides the user with flexibility in selecting a protective system to best suit theapplication. Additional Optional Protective Functions may be added at the time of purchase at per-functionpricing.

The Human-Machine Interface (HMI) Module, Target Module, or redundant power supply can be selected attime of purchase.

When the Field Ground (64F) Premium Protective Function is purchased, an external coupler module(M-3921) is provided for isolation from the dc field voltages.

When 100% Stator Ground (64S) protection using low-frequency injection is purchased, an external bandpass filter and frequency generator is provided.

Multiple Setpoint Profiles (Groups)The relay supports four setpoint profiles. This feature allows multiple setpoint profiles to be defined for differentpower system configurations or generator operating modes. Profiles can be switched either manually usingthe Human-Machine Interface (HMI), by communications, programmable logic or by control/status inputs.

■■■■■ NOTE: During profile switching, relay operation is disabled for approximately 1 second.

MeteringThe relay provides metering of voltages (phase, neutral and sequence quantities), currents (phase, neutraland sequence quantities), real power, reactive power, power factor and impedance measurements.

Metering accuracies are:

Voltage: 0.5 V or 0.5%, whichever is greater0.8 V or 0.75%, whichever is greater (when both RMS and Line-Ground to Line-Line are

selected)

Current: 5 A rating, 0.1 A or 3%, whichever is greater1 A rating, 0.02 A or 3%, whichever is greater

Power: 0.01 PU or 2% of VA applied, whichever is greater

Frequency: 0.02 Hz (from 57 to 63 Hz for 60 Hz models; from 47 to 53 Hz for 50 Hz models)0.1 Hz beyond 63 Hz for 60 Hz models, and beyond 53 Hz for 50 Hz models

Volts/Hz: 1%

Oscillographic RecorderThe oscillographic recorder provides comprehensive data recording of all monitored waveforms, storing up to416 cycles of data. The total record length is user-configurable from 1 to 16 partitions. The sampling rate is 16times the power system nominal frequency (50 or 60 Hz). The recorder may be triggered using either thedesignated control/status inputs, trip outputs, or using serial communications. When untriggered, the recordercontinuously stores waveform data, thereby keeping the most recent data in memory. When triggered, therecorder stores pre-trigger data, then continues to store data in memory for a user-defined, post-trigger delayperiod. The data records can be stored in either Beckwith Electric format or COMTRADE format.

Target StorageInformation associated with the last 32 trips is stored. The information includes the function(s) operated, thefunctions picked up, input/output status, time stamp, and phase and neutral currents at the time of trip.

–13–


Sequence of Events LogThe Sequence of Events Log records relay element status, I/O status, measured values and calculated valuestime stamped with 1 ms resolution at user-defined events. The Sequence of Events Log includes 512 of themost recently recorded relay events. The events and the associated data is available for viewing utilizing theM-3820D IPScom Communications Software.

CalculationsCurrent and Voltage RMS Values: Uses Discrete Fourier Transform algorithm on sampled voltage and currentsignals to extract fundamental frequency phasors for relay calculations. RMS calculation for the 50, 51N, 59and 27 functions, and the 24 function are obtained using the time domain approach to obtain accuracy over awide frequency band. When the RMS option is selected, the magnitude calculation for 59 and 27 functions isaccurate over a wide frequency range (10 to 80 Hz). When the DFT option is selected, the magnitudecalculation is accurate near nominal frequency (50 Hz/60 Hz) but will degrade outside the nominal frequency.For 50 and 51N functions the DFT is used when the frequency is 55 Hz to 65 Hz for 60 Hz (nominal) and 45 Hzto 55Hz for 50 Hz (nominal), outside of this range RMS calculation is used.

Power Input OptionsNominal 110/120/230/240 V ac, 50/60 Hz, or nominal 110/125/220/250 V dc. Operates properly from 85 V acto 265 V ac and from 80 V dc to 312.5 V dc. Withstands 300 V ac or 315 V dc for 1 second. Nominal burden 40VA at 120 V ac/125 V dc.

Nominal 24/48 V dc, operates properly from 18 V dc to 56 V dc, withstands 65 V dc for 1 second. Burden 25 VAat 24 V dc and 30 VA at 48 V dc.

An optional redundant power supply is available for units that are purchased without the expanded I/O.

For those units purchased with the expanded I/O, the unit includes two power supplies which are required topower the relay. Burden (nominal) 46 VA @120 V ac.

Sensing InputsFive Voltage Inputs: Rated for a nominal voltage of 50 V ac to 140 V ac at 60 Hz or 50 Hz. Will withstand 240 Vcontinuous voltage and 360 V for 10 seconds. Source voltages may be line-to-ground or line-to-line connected.Phase sequence ABC or ACB is software selectable. Voltage transformer burden less than 0.2 VA at 120 V ac.

Seven Current Inputs: Rated nominal current (IR) of 5.0 A or 1.0 A at 60 Hz or 50 Hz. Will withstand 3I

Rcontinuous current and 100IR for 1 second. Current transformer burden is less than 0.5 VA at 5 A, or 0.3 VAat 1 A.

Control/Status InputsThe control/status inputs, INPUT1 through INPUT6, can be programmed to block any relay protective function,to trigger the oscillograph recorder, to operate one or more outputs or can be an input into IPSlogic. To providebreaker status LED indication on the front panel, the INPUT1 control/status input contact must be connected tothe 52b breaker status contact.

The optional expanded I/O includes an additional 8 programmable control/status inputs (INPUT7 throughINPUT14).

▲ CAUTION: The control/status inputs should be connected to dry contacts only, and are internally connected(wetted) with a 24 V dc power supply.

Output ContactsAny of the functions can be individually programmed to activate any one or more of the eight programmableoutput contacts OUTPUT1 through OUTPUT8. Any output contact can also be selected as pulsed or latched.IPSlogic can also be used to activate an output contact.

The optional expanded I/O includes an additional 15 programmable output contacts (OUTPUT9 throughOUTPUT23). These contacts are configurable only using IPScom software.

The eight output contacts (six form ‘a’ and two form ‘c’), the power supply alarm output contact (form ‘b’), the self-test alarm output contact (form ‘c’) and the optional 15 expanded I/O output contacts (form 'a') are all rated perANSI/IEEE C37.90-1989 for tripping. Make 30 A for 0.2 seconds, carry 8 A, break 6 A at 120 V ac, break 0.5 A at48 V dc; 0.3 A, 125 V dc; 0.2 A, 250 V dc with L/R=40 mSec.

–14–


IPSlogicThis feature can be programmed utilizing the IPScom® Communications Software. IPSlogic takes the contactinput status and function status, and by employing (OR, AND, and NOT) boolean logic and a timer, canactivate an output or change setting profiles.

Target/Status Indicators and ControlsThe RELAY OK LED reveals proper cycling of the microcomputer. The BRKR CLOSED LED will illuminatewhen the breaker is closed (when the 52b contact input is open). The OSC TRIG LED indicates thatoscillographic data has been recorded in the unit's memory. The TARGET LED will illuminate when any of therelay functions operate. Pressing and releasing the TARGET RESET buttonresets the target LED if theconditions causing the operation have been removed. Holding the TARGET RESET push button displays thepresent pickup status of the relay functions. The PS1 and PS2 LEDs will remain illuminated as long as poweris applied to the unit and the power supply is operating properly. TIME SYNC LED illuminates when validIRIG-B signal is applied and time synchronization has been established.

CommunicationCommunications ports include rear panel RS-232 and RS-485 ports, a front panel RS-232 port, a rear-panelIRIG-B port and an Ethernet port (optional). The communications protocol implements serial, byte-oriented,asynchronous communication, providing the following functions when used with the Windows™-compatibleM-3820D IPScom® Communications Software. MODBUS and BECO 2200 protocols are supported providing:

• Interrogation and modification of setpoints

• Time-stamped information for the 32 most recent trips

• Real-time metering of all quantities measured

• Downloading of recorded oscillographic data and Sequence of Events Recorder data.

The optional Ethernet port can be purchased with MODBUS over TCP/IP and BECO2200 over TCP/IPprotocols or with the IEC 61850 protocol.

IRIG-BThe M-3425A Generator Protection Relay can accept either modulated or demodulated IRIG-B time clocksynchronization signal. The IRIG-B time synchronization information is used to correct the hour, minutes,seconds, and milliseconds information.

HMI Module (optional)Local access to the relay is provided through an optional M-3931 HMI (Human-Machine Interface) Module,allowing for easy-to-use, menu-driven access to all functions utilizing six pushbuttons and a 2-line by 24character alphanumeric vacuum florescent display. Features of the HMI Module include :

• User-definable access codes that allow three levels of security


• Time-stamped information for the 32 most recent trips

• Real-time metering of all quantities measured

Target Module (optional)An optional M-3925A Target Module provides 24 target and 8 output LEDs. Appropriate target LEDs willilluminate when the corresponding function operates. The targets can be reset with the TARGET RESETpushbutton. The OUTPUT LEDs indicate the status of the programmable output relays.

–15–


Temperature Controller MonitoringAny Temperature Controller equipped with a contact output may be connected to the M-3425A and controlledby the relay's programmable IPSlogic function. Figure 1 is an example of a typical Temperature ControllerMonitoring application. The Omron E5C2 Temperature Controller is a DIN rail mounted RTD interface to theM-3425A Generator Protection relay. The E5C2 accepts type J or K thermocouples, platinum RTDs orthermistors as its input. Supply voltage for the E5C2 accepts 110/120 V ac, 50/60 Hz, or 220/240 V ac 50/60Hz or 24 V dc.

TemperatureController

Omron E5C2P.D. 750

or equivalent

IN X

IN RTN

M-3425A

IPSlogic

Alarm/TripR1

C

R2

Figure 1 Typical Temperature Controller Monitoring Application

I/O Expansion (optional)Optional I/O Expansion provides an additional 15 form 'a' output contacts and an additional 8 control/statusinputs. Output LEDs indicate the status of the output relays.

Tests and StandardsThe relay complies with the following type tests and standards:

Voltage Withstand

Dielectric WithstandIEC 60255-5 3,500 V dc for 1 minute applied to each independent circuit to earth

3,500 V dc for 1 minute applied between each independent circuit1,500 V dc for 1 minute applied to IRIG-B circuit to earth1,500 V dc for 1 minute applied between IRIG-B to each independent circuit1,500 V dc for 1 minute applied between RS-485 to each independent circuit

Impulse VoltageIEC 60255-5 5,000 V pk, +/- polarity applied to each independent circuit to earth

5,000 V pk, +/- polarity applied between each independent circuit1.2 by 50 μs, 500 ohms impedance, three surges at 1 every 5 seconds

Insulation ResistanceIEC 60255-5 > 100 Megaohms

–16–


Electrical Environment

Electrostatic Discharge TestEN 60255-22-2 Class 4 (8 kV)—point contact discharge

EN 60255-22-2 Class 4 (15kV)–air discharge

Fast Transient Disturbance TestEN 60255-22-4 Class A (4 kV, 2.5 kHz)

Surge Withstand CapabilityANSI/IEEE 2,500 V pk-pk oscillatory applied to each independent circuit to earthC37.90.1- 2,500 V pk-pk oscillatory applied between each independent circuit1989 5,000 V pk Fast Transient applied to each independent circuit to earth

5,000 V pk Fast Transient applied between each independent circuit

ANSI/IEEE 2,500 V pk-pk oscillatory applied to each independent circuit to earthC37.90.1- 2,500 V pk-pk oscillatory applied between each independent circuit 2002 4,000 V pk Fast Transient burst applied to each independent circuit to earth

4,000 V pk Fast Transient burst applied between each independent circuit

■ NOTE: The signal is applied to the digital data circuits (RS-232, RS-485, IRIG-B, Ethernet communicationport and field ground coupling port) through capacitive coupling clamp.

Radiated SusceptibilityANSI/IEEE 25-1000 Mhz @ 35 V/mC37.90.2

Output ContactsANSI/IEEE Make 30 A for 0.2 seconds, off for 15 seconds for 2,000 operations, per Section 6.7.1,TrippingC37.90.0 Output Performance Requirements

Atmospheric Environment

TemperatureIEC 60068-2-1 Cold, –20° CIEC 60068-2-2 Dry Heat, +70° CIEC 60068-2-3 Damp Heat, +40° C @ 93% RH

Mechanical Environment

VibrationIEC 60255-21-1 Vibration response Class 1, 0.5 g

Vibration endurance Class 1, 1.0 g

IEC 60255-21-2 Shock Response Class 1, 5.0 gShock Withstand Class 1, 15.0 gBump Endurance Class 1, 10.0 g

–17–


ComplianceUL-Listed per 508 – Industrial Control Equipment

UL-Listed Component per 508A Table SA1.1 Industrial Control Panels

CSA-Certified per C22.2 No. 14-95 – Industrial Control Equipment

CE Safety Directive – EN61010-1:2001, CAT II, Pollution Degree 2

PhysicalWithout Optional Expanded I/O

Size: 19.00" wide x 5.21" high x 10.20" deep (48.3 cm x 13.2 cm x 25.9 cm)

Mounting: The unit is a standard 19", semiflush, three-unit high, rack-mount panel design, conforming toANSI/EIA RS-310C and DIN 41494 Part 5 specifications. Vertical or horizontal panel-mount options areavailable.

Approximate Weight: 17 lbs (7.7 kg)

Approximate Shipping Weight: 25 lbs (11.3 kg)

With Optional Expanded I/O

Size: 19.00" wide x 6.96" high x 10.2" deep (48.3 cm x 17.7 cm x 25.9 cm)

Mounting: The unit is a standard 19", semiflush, four-unit high, rack-mount panel design, conforming to ANSI/EIA RS-310C and DIN 41494 Part 5 specifications. Vertical or horizontal panel-mount options are available.

Approximate Weight: 19 lbs (8.6 kg)

Approximate Shipping Weight: 26 lbs (11.8 kg)

Recommended Storage Parameters

Temperature: 5° C to 40° C

Humidity: Maximum relative humidity 80% for temperatures up to 31° C, decreasing to 31° Clinearly to 50% relative humidity at 40° C.

Environment: Storage area to be free of dust, corrosive gases, flammable materials, dew, perco-lating water, rain and solar radiation.

See M-3425A Instruction Book, Appendix E, Layup and Storage for additional information.

Patent & WarrantyThe M-3425A Generator Protection Relay is covered by U.S. Patents 5,592,393 and 5,224,011.

The M-3425A Generator Protection Relay is covered by a five year warranty from date of shipment.

Specification subject to change without notice.

External ConnectionsM-3425A external connection points are illustrated in Figures 2 and 3.

–18–


Figure 2

External C

onnections (Without O

ptional Expanded I/O

)

■■ ■■■N

OT

ES

:

1.S

ee M-3425A

Instruction Book S

ection 2.3, Setpoints and T

ime S

ettings, subsection for 64B/F

Field G

round Protection.

2.B

efore making connections to the T

rip Circuit M

onitoring input, see M-3425A

Instruction Book S

ection 5.5, Circuit B

oard Sw

itc hes andJum

pers, for the information regarding setting T

rip Circuit M

onitoring input voltage. Connecting a voltage other than the volta ge that the unit is

configured to may result in m

is-operation or permanent dam

age to the unit.

3.88 888

WA

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: ON

LY

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ON

TA

CT

S m

ust b

e con

nected

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pu

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se these co

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pp

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ts may resu

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ook

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–20–


50DT

Utility System

52Unit

52Gen

50BFPh

87

492132 504078 60FL 51V 50/27

27

81R 81 27 59 24

64F 64B

M-3921+

-

CT

VT

M-3425A

87GD 50N50

BFN 51N

R

64S27TN

27

32R

High-impedance Grounding with ThirdHarmonic 100% Ground Fault Protection

Low-impedance Grounding with Ground Differentialand Overcurrent Stator Ground Fault Protection

These functions are available inthe Comprehensive Package. Asubset of these functions are alsoavailable in a Base Package.

This function is available as aoptional protective function.

This function provides control forthe function to which it points.

M-3425A TypicalConnection Diagram

25

59D

VT (Note 1)

Targets(Optional)

Integral HMI(Optional)

Metering

Waveform Capture

IRIG-B

Front RS232Communication

Multiple SettingGroups

Programmable I/O

Self Diagnostics

Dual Power Supply(Optional)

Rear Ethernet Port (Optional)

Rear RS-485Communication

BreakerMonitoring

Trip CircuitMonitoring

67N67N Polarization(Software Select)

81A

50N50BFN 51N

46

59X

59N

3VO (Calculated)VX

VN

3IO

IN

67N Operating Current(Software Select)

VT (Note 1)

(Note 3)

(Note 5)

CT (Residual)(Note 4)

59D Line SideVoltage

(Software Select)

VX3VO (Calculated)

CT (Neutral)(Notes 2 & 5)

CTM

(Metering)

M

(Metering)

Rear RS232Communication

Event Log

■ NOTES:1. When 25 function is enabled, 59X, 59D with V

X and 67N with V

X are not available, and vice versa.

2. When 67N function with IN (Residual) operating current is enabled, 87GD is not available, and vice

versa.3. When VT source is used as a turn-to-turn fault protection device (See M-3425A Instruction Book,

Chapter 2, Application, for additional 59X applications.)4. The current input I

N can be connected either from neutral current or residual current.

5. The 50BFN, 50N, 51N, 59D, 67N (with IN or V

N) and 87GD functions are unavailable when the 64S

function has been purchased. See the M-3425A Instruction Book for connection details.

Figure 4 One-Line Functional Diagram (Configured with Phase Differential)

–21–


Utility System

52Unit

52Gen

81R 81 59 27 24

M-3921+

-

VT

CT

M-3425A

50N 51N

R

CT

27

32R


Low-impedance Grounding withOvercurrent Stator Ground Fault Protection




M-3425A TypicalConnection Diagram(Configured for Split-Phase Differential)

25

59D

50DT

67N

Targets(Optional)


Metering

Waveform Capture

IRIG-B



Programmable I/O

Self Diagnostics


Rear EthernetPort (Optional)


BreakerMonitoring


27TN

81A

46492132 504078 60FL 51V 50/27

2764F 64B

59X

64S 59N


VT (Note 1)

VT (Note 1)

67N Polarization(Software Select)

3VO (Calculated)

VX

VN

(Note 2)

CT (Note 3)

(Note 4)


(Software Select)

VX 3VO (Calculated)

CT (Neutral)(Note 5)

M

(Metering)

M

(Metering)


Event Log

■ NOTES:

1. When 25 function is enabled, 59X, 59D with VX and 67N with V


2. When used as a turn-turn fault protection device.

3. CTs are connected for split-phase differential current.

4. 67N operating current can only be selected to IN

(Residual) for this configuration.

5. The current input (IN) can be connected either from neutral current or residual current.




Figure 5 One-Line Functional Diagram (configured for split-phase diffential)

–22–


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Figure 6 Horizontal Mounting Dimensions (Without Expanded I/O)

■ NOTE: Panels for vertical mounting are available (See Figure 8).

–23–


Figure 7 Horizontal Mounting Dimensions (With Expanded I/O)

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–24–


17.31[43.97]Actual

17.5[44.45]

1.67[4.24]

19.00[48.26]

18.34[46.58]

2.25[5.72]

0.40 [1.02] X0.27 [0.68]

Slot (4X)

Front View

NOTE: Dimensions in bracketsare in centimeters.

Rear ViewRECOMMENDED CUTOUT WHEN RELAY ISNOT USED AS STANDARD RACK MOUNTAND IS PANEL CUT OUT MOUNTED

Optional Vertical Mount Chassis

5.59[14.20]Actual

5.65[14.40]

■ NOTES:1. When mounted vertically, the target module will be located at the top and all front-panel text will be

horizontally aligned. Consult Beckwith Electric Co. for details.

2. Expanded I/O not avilable on vertical mount chassis model.

Figure 8 Vertical Mounting Dimensions (Without Expanded I/O)

–25–


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Figure 9 M-3425A Panel Mount Cutout Dimensions

–26–


M-3921 Field Ground Coupler

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Figure 10 Field Ground Protection Block Diagram

NOTES:1. The above circuit measures insulation resistance (R

f) between rotor field winding and ground (64F).

2. Relay injects 15 V squarewave (Vout

) and measures return signal (Vf) to calculate R

f.

3. The injection frequency can be set (0.1 to 1.0 Hz) based on the rotor capacitance, in order toimprove accuracy.

4. The signal rise time is analyzed to determine if shaft brushes are lifting or open (64B).

5. May also be applied on generators with brushless excitation with a grounding brush and pilotground fault detection brush.

Function SpecificationField/Exciter Supply Voltage Rating (Terminal (3) to (2)):

• 60 to 1200 V dc, continuous

• 1500 V dc, 1 minute

Operating Temperature: –20° to +70°, Centigrade

Patent & WarrantyThe M-3921 Field Ground Coupler is covered by a five-year warranty from date of shipment.

Tests and StandardsM-3921 Field Ground Coupler complies with the following tests and standards:

–27–


Voltage Withstand

Isolation4 kV ac for 1 minute, all terminals to case

Impulse VoltageIEC 60255–5, 5,000 V pk, 1.2 by 50 μs, 0.5 J, 3 positive and 3 negative impulses at 5 second

intervals per minute

Electrical InterferenceElectrostatic Discharge TestIEC 61000-4-2 Class 4 (8 kV)—point contact discharge

Fast Transient Disturbance TestsIEC 61000-4-4 Class 4 (4 kV, 2.5 kHz)

Surge Withstand CapabilityANSI/IEEE 2,500 V pk-pk oscillatory applied to each independent circuit to earthC37.90.1- 2,500 V pk-pk applied between each independent circuit1989 5,000 V pk Fast Transient applied to each independent circuit to earth

5,000 V pk Fast Transient applied between each independent circuit

■ NOTE: See also M-3425A Surge Withstand Capability test standards, ANSI/IEEE C37.90.2-2002.

Radiated SusceptibilityANSI/IEEE 25-1000 Mhz @ 20 V/mC37.90.2

Atmospheric EnvironmentIEC 60068–2–1 Cold, –20° CIEC 60068–2–2 Dry Heat, +70° CIEC 60068–2–3 Damp Heat, +40° C @ 93% RH

Enclosure ProtectionNEMA 1, IEC IPC-65

–28–


.18 DIA [0.46] 4 HOLES

MOUNTING PATTERNWITHOUT TABS

Field GroundCoupler4.72 [11.99]

7.87 [19.99] 2.96 REF [7.52]

3.54 [9.0]

�NOTE: Dimensions in brackets are in centimeters.

7.40[18.79]

9.06 [23.01]

3.54 [9.0]

.18 DIA [0.46] 4 X

��

��%&��'

�/672892��

M-3921

Figure 11 M-3921 Field Ground Coupler Mounting Dimensions

–29–


64S 100% Stator Ground Protection by Low Frequency Signal Injection■ NOTE: The Stator Ground Protection function (64S) must be selected when the M-3425A is initially

ordered.

The 100% stator ground fault protection is provided by injecting an external 20 Hz signal into the neutral of thegenerator. The protection is provided when the machine is on-line as well as off-line (provided that the 20 Hzgenerator and relay are powered on.) This scheme requires the following external components in addition toM-3425A protection system:

• 20 Hz Signal-generator (BECO Part No. 430-00426) (Siemens 7XT33)

• Band-pass filter. (BECO Part No. 430-00427) (Siemens 7XT34)

• 20 Hz Measuring Current Transformer, 400/5 A CT (BECO Part No. 430-00428)(ITI-CTW3-60-T50-401)

The voltage signal generated by the 20 Hz signal-generator is injected into the secondary of the generatorneutral grounding transformer through a band-pass filter. The band-pass filter passes the 20 Hz signal andrejects out-of-band signals. The output of the 20 Hz band-pass filter is connected to the V

N input of the

M-3425A relay through a suitable voltage divider, that limits the M-3425A to OOOOO 200 V ac (the voltage generatormay be bypassed if the expected 50/60 Hz voltage during a phase-to-ground fault of the generator is OOOOO 200 V.)The 20Hz current is also connected to the I

N input of the M-3425A, through the 20Hz current transformer.

When the generator is operating normally (no ground fault) only a small amount of 20 Hz current will flow as aresult of the stator capacitance to ground. When a ground fault occurs anywhere on the generator statorwindings the 20 Hz current will increase. The 64S function will issue a trip signal after a set time delay when themeasured 20 Hz current exceeds the pickup current.

For cases where the Load Resistor (RN) is small, the Undervoltage Inhibit should not be enabled, as the

voltage will be small.

The 59N function (90 to 95%) should also be used in conjunction with 64S protection to provide backup.

RN

1B1

1A1

1B4

1A3 1A4

20 HzBand Pass

Filter

20 HzGenerator

4A1

1A1

1A2

1A3

2A3

2A1

3A2

3A14A3

Bl

3A3

Supply VoltageDC AC+VAux VA(L1)

-VAux VB(L2)

VC(L3)

ExternalBlock

DeviceOperative

44 45

M-3425A

52 53

400A5A

L K

l k

Max. 200 V

V N

I N

NeutralGrounding

Transformer

WiringShielded

20 Hz CT

400/5 A

59N

High *Voltage

LowVoltage

* For applications with a transformer secondary rating that will result in 50/60 Hz phaseground fault voltages >200 V ac, use the "High Voltage" connection for the 59N Function.

Figure 12 64S Function Component Connection Diagram

–30–


20 Hz Signal Generator Function Specifications

Auxillary VoltageRated auxiliary voltage U

H ac 3x (100/110 V ac), 50/60 Hz 1x (110 to 230 V ac), 50/60 Hz

Permissible variations ac 80 to 130 V ac 80 to 265 V ac

OR

Rated auxiliary voltage UH dc 110 to 220 V dc

Permissible Variations dc 88 to 253 V dc

Permissible comsumption at 8 W impendance OOOOO110 VA

20 Hz Output VoltageConnections (4A1-4A3)

Output Voltage approx. 25 V rectangular; 20 Hz 0.2 Hz

Load Capability, continuous 75 VA

■ NOTE: If the input voltage is slowly increased, appearance of the output voltage may last up to 1 minute.

Binary Input for BlockingConnections (2A1-2A3)

Permissible voltage, continuous 300 V dc

Alarm RelayConnections (3A1-3A3)

Switching capacity MAKE/BREAK 20W/VA

Switching voltage for OOOOO30 s 250 V dc

Permissible current MAKE 5A

Permissible current BREAK 1A

Test Voltage2.8 kV dc

Permissible Ambient Temperatureswith R

L <<<<<5 W burden OOOOO400 C or OOOOO1040 F

with RL >>>>>5 W burden OOOOO550 C or OOOOO1310 F

■ NOTE: The device may produce up to 20 W power losses during service. In order to prevent heat pockets,the dissipation of the losses must not be restricted. The minimum clearance above and below thedevice to other units or walls is 100 mm or 4 inches. In cubicles, the device shall be installed in thebottom area.

–31–


■ NOTE: Detailed Mounting information is contained in the M-3425A Instruction Book Chapter 5, InstallationSection 5.6.

Figure 13 20Hz Signal Generator Dimensions

Dimensions in mm

–32–


Band-pass Filter Specifications

Load Capacity of the 20 Hz Band-pass FilterConnections (1B1-1B4)

Permissible voltage, continuous 55 V ac

Permissible voltage for OOOOO30 s 550 V ac

Frequency of superimposed ac voltage PPPPP 45 Hz

Overload capability, continuous 3.25 A ac

Test Voltage 2.8 kV dc

Load Capability of the Voltage Divider CircuitConnections (1A1-1A4):

Permissible voltage, continuous 55 V ac

Permissible voltage for OOOOO30 s 50 V ac

Test Voltage 2.8 kV dc

Permissible Ambient Temperatureswith R

L <<<<<5 Ω burden OOOOO400 C or OOOOO 1040 F

with RL >>>>>5 Ω burden OOOOO550 C or OOOOO 1310 F

■ NOTE: The device may produce up to 75 W power losses during service. In order to prevent heat pockets,the dissipation of the losses must not be restricted. The minimum clearance above and below thedevice to other units or walls is 100 mm or 4 inches. In cubicles, the device shall be installed in thebottom area.

–33–


■ NOTE: Detailed Mounting information is contained in the M-3425A Instruction Book Chapter 5, InstallationSection 5.

Figure 14 Band-pass Filter Dimensions

–34–


Figure 15 20 Hz Measuring Current Transformer 400-5 A CT

–35–


�� !��!��"�!#��!��!�� $��!��!%�� &��'%��(��$�!�%��)��#�!��) �� '��!��"�� &��%��(�*�)�+�!�� !��+��+��!��!��!�� +�� $��!'��!%��(

DANGER! HIGH VOLTAGE

– This sign warns that the area is connected to a dangerous high voltage, and youmust never touch it.

PERSONNEL SAFETY PRECAUTIONSThe following general rules and other specific warnings throughout the manual must be followed during application,test or repair of this equipment. Failure to do so will violate standards for safety in the design, manufacture, and intendeduse of the product. Qualified personnel should be the only ones who operate and maintain this equipment. BeckwithElectric Co., Inc. assumes no liability for the customer’s failure to comply with these requirements.

– This sign means that you should refer to the corresponding section of the operation

manual for important information before proceeding.

Always Ground the Equipment

To avoid possible shock hazard, the chassis must be connected to an electrical ground. When servicingequipment in a test area, the Protective Earth Terminal must be attached to a separate ground securelyby use of a tool, since it is not grounded by external connectors.

Do NOT operate in an explosive environmentDo not operate this equipment in the presence of flammable or explosive gases or fumes. To do so wouldrisk a possible fire or explosion.

Keep away from live circuitsOperating personnel must not remove the cover or expose the printed circuit board while power is ap-plied. In no case may components be replaced with power applied. In some instances, dangerous volt-ages may exist even when power is disconnected. To avoid electrical shock, always disconnect power anddischarge circuits before working on the unit.

Exercise care during installation, operation, & maintenance proceduresThe equipment described in this manual contains voltages high enough to cause serious injury or death.Only qualified personnel should install, operate, test, and maintain this equipment. Be sure that all per-sonnel safety procedures are carefully followed. Exercise due care when operating or servicing alone.

Do not modify equipmentDo not perform any unauthorized modifications on this instrument. Return of the unit to a BeckwithElectric repair facility is preferred. If authorized modifications are to be attempted, be sure to followreplacement procedures carefully to assure that safety features are maintained.

PRODUCT CAUTIONSBefore attempting any test, calibration, or maintenance procedure, personnel must be completely familiarwith the particular circuitry of this unit, and have an adequate understanding of field effect devices. If acomponent is found to be defective, always follow replacement procedures carefully to that assure safetyfeatures are maintained. Always replace components with those of equal or better quality as shown in theParts List of the Instruction Book.

Avoid static chargeThis unit contains MOS circuitry, which can be damaged by improper test or rework procedures. Careshould be taken to avoid static charge on work surfaces and service personnel.

Use caution when measuring resistancesAny attempt to measure resistances between points on the printed circuit board, unless otherwise notedin the Instruction Book, is likely to cause damage to the unit.

NOTE

The following features, described in this Instruction Book, are only available for firmware versionD-0150-V01.00.34 and later:

59N 20 Hz Injection Mode (Page 2-58)

IEEE curves for 51N, 51V, and 67N functions (Appendix D)

Sequence of Events Recorder (Page 4-18)

Dropout/Reset Time Delay added to IPSlogic (Page 2-91)

Response Time Delay for Communications (Page 4-3)

25 Function (does not produce a target) (Page 2-21)

This Page Left Intentionally Blank

i

Table of Contents

Chapters - Part 1 of 2 Page

Chapter 1 Introduction

1.1 Instruction Book Contents ................................................................. 1–1

1.2 M-3425A Generator Protection Relay ................................................ 1–2

1.3 Accessories ........................................................................................ 1–4

Chapter 2 Application

2.1 Configuration ....................................................................................... 2–2Profiles ................................................................................................ 2–3Functions ............................................................................................ 2–3Special Considerations ........................................................................ 2–3Relay System Setup .......................................................................... 2–3

2.2 System Diagrams ............................................................................... 2–8

2.3 Setpoints and Time Settings ........................................................... 2–1421 Phase Distance ........................................................................... 2–1424 Overexcitation Volts/Hz .............................................................. 2–1825 Sync Check ................................................................................. 2–2127 Phase Undervoltage .................................................................... 2–2527TN Third Harmonic Undervoltage, Neutral .................................. 2–2632 Directional Power ........................................................................ 2–2940 Loss of Field ............................................................................... 2–3346 Negative Sequence Overcurrent ................................................. 2–3749 Stator Overload Protection ......................................................... 2–3950/50N Instantaneous Overcurrent,Phase & Neutral Circuits ........ 2–4250BF Generator Breaker Failure/HV Breaker Flashover ................. 2–4450DT Definite Time Overcurrent (for split-phase differential) ........ 2–4650/27 Inadvertant Energizing ........................................................... 2–4751N Inverse Time Neutral Overcurrent ............................................ 2–4951V Inverse Time Phase Overcurrent withVoltage Control/Restraint ................................................................. 2–5059 Phase Overvoltage...................................................................... 2–5259D Third Harmonic Voltage Differential ......................................... 2–5359N Overvoltage, Neutral Circuit or Zero Sequence ...................... 2–5559X Multipurpose Overvoltage (Turn-to-Turn Stator Faultor Bus Ground Protection) ............................................................... 2–5660FL VT Fuse Loss ......................................................................... 2–5864B/F Field Ground Protection ........................................................ 2–6164F Field Ground Protection ............................................................ 2–6164B Brush Lift-Off Detection ........................................................... 2–6364S 100% Stator Ground Protection by Low FrequencySignal Injection ................................................................................. 2–64

TABLE OF CONTENTSM-3425A Generator Protection

Instruction Book

ii

M-3425A Instruction Book

Chapters - Part 1 of 2 (cont'd) Page

Chapter 2 Application (cont'd)

67N Residual Directional Overcurrent ............................................. 2–6778 Out of Step .................................................................................. 2–7081 Frequency .................................................................................... 2–7381A Frequency Accumulators ............................................................2–7581R Rate of Change of Frequency ......................................................2–7787 Phase Differential ..........................................................................2–7887GD Ground (Zero Sequence) Differential .........................................2–80Breaker Monitoring ..............................................................................2–81Trip Circuit Monitoring .........................................................................2–82IPSlogic ..............................................................................................2–83Settings and Logic ..............................................................................2–85DO/RST (Droput/Reset) Timer Feature ...............................................2–87Dropout Delay Timer ...........................................................................2–87Reset Delay Timer ..............................................................................2–87

Chapter 3 Operation

3.1 Front Panel Controls ............................................................................ 3–1Alphanumeric Display .......................................................................... 3–1Screen Blanking .................................................................................. 3–1Arrow Pushbuttons .............................................................................. 3–1Exit Pushbutton ................................................................................... 3–1Enter Pushbutton ................................................................................. 3–1Target & Status Indicators and Controls .............................................. 3–1Power Supply #1 (#2) LED ................................................................... 3–2Relay OK LED ..................................................................................... 3–2Oscillograph Recorded LED................................................................. 3–2Breaker Closed LED ............................................................................ 3–2Target Indicators and Target Reset ..................................................... 3–2Time Sync LED ................................................................................... 3–2Diagnostic LED.................................................................................... 3–2Accessing Screens ............................................................................. 3–2Default Message Screens .................................................................. 3–2

3.2 Initial Setup Procedure/Settings ........................................................ 3–5

3.3 Setup Unit Data ................................................................................... 3–5Setup Unit Data Entry .......................................................................... 3–5Setup Unit Features That Do Not Require Data Entry .......................... 3–6

3.4 Setup System Data ............................................................................. 3–6Configure Relay Data ........................................................................... 3–7Setpoints and Time Settings ............................................................... 3–7Oscillograph Recorder Data ................................................................. 3–8Communications Settings .................................................................... 3–8

3.5 Status/Metering ................................................................................... 3–9

3.6 Target History .....................................................................................3–10

iii

Table of Contents


Chapter 4 Remote Operation

4.1 Remote Operation ............................................................................... 4–1Serial Ports (RS-232) ......................................................................... 4–1Serial Port (RS-485) ............................................................................. 4–1Optional Ethernet Port ......................................................................... 4–1Direct Connection ................................................................................ 4–2Setting up the M-3425A Generator ProtectionRelay for Communication ..................................................................... 4–3Serial Communication Settings............................................................ 4–3Ethernet Communication Settings ....................................................... 4–3DHCP Protocol .................................................................................... 4–3Ethernet Protocols ............................................................................... 4–3Ethernet Port Setup ............................................................................. 4–4HMI Ethernet Port Setup ..................................................................... 4–4Manual Configuration of Ethernet Board .............................................. 4–5IPSutil™ Ethernet Port Setup with DHCP ............................................ 4–5IPSutil Ethernet Port Setup without DHCP .......................................... 4–5Installing the Modems ........................................................................ 4–7

4.2 Installation and Setup (IPScom®) ........................................................ 4–8

4.3 Operation ............................................................................................ 4–8Activating Communications ................................................................ 4–8Overview ............................................................................................. 4–9File Menu ............................................................................................ 4–9Comm Menu ....................................................................................... 4–9Relay Menu ....................................................................................... 4–10Window Menu/Help Menu ................................................................. 4–21

4.4 Checkout Status/Metering ................................................................ 4–22

4.5 Cautions ............................................................................................ 4–27

4.6 Keyboard Shortcuts .......................................................................... 4–28

4.7 IPSutil Communications Software ......................................................4–29M-3890 IPSutil ...................................................................................4–29Installation and Setup .........................................................................4–29Installation ..........................................................................................4–30System Setup ....................................................................................4–30Overview.............................................................................................4–30Comm Menu .......................................................................................4–30Relay Comm Command ......................................................................4–30Ethernet Command .............................................................................4–30Clock Command .................................................................................4–30Security Menu ....................................................................................4–31Miscellaneous Menu ...........................................................................4–31Help Menu ..........................................................................................4–32

iv


Figures - Part 1 of 2 Page

Chapter 11-1 M-3925A Target Module ..................................................................... 1–4

1-2 M-3931 Human-Machine Interface (HMI) Module............................. 1–4

Chapter 22-1 Setup System Dialog Box ................................................................. 2–6

2-2 Selection Screen for Expanded Input ............................................... 2–7

2-3 Pulse Relay Expanded Output Screen .............................................. 2–7

2-4 Latch Relay Expanded Output Screen .............................................. 2–7

2-5 One-Line Functional Diagram............................................................. 2–8

2-6 Alternative One-Line Functional Diagram(configured for split-phase differential) .............................................. 2–9

2-7 Three-Line Connection Diagram ....................................................... 2–10

2-8 Function 25 Sync Check Three-Line Connection Diagram............. 2–11

2-9 Function 59X Turn-to-Turn Fault Protection Three-LineConnection Diagram ......................................................................... 2–12

2-10 Function 67N, 59D, 59X (Bus Ground) Three-LineConnection Diagram ......................................................................... 2–13

2-11 Selection Screen for Expanded I/O Initiate .................................... 2–14

2-12 Phase Distance (21) Coverage ........................................................ 2–16

2-13 Phase Distance (21) Function Applied for System Backup ........... 2–16

2-14 Phase Distance (21) Setpoint Ranges ............................................ 2–17

2-15 Example of Capability and Protection Curves (24) ......................... 2–19

2-16 Volts-per-Hertz (24) Setpoint Ranges .............................................. 2–20

2-17 Sync Check Logic Diagrams ........................................................... 2–23

2-18 Sync Check (25) Setpoint Ranges .................................................. 2–24

2-19 Phase Undervoltage (27) Setpoint Ranges ..................................... 2–25

2-20 Third-Harmonic Undervoltage (27TN) Protection Characteristics ... 2–26

2-21 27TN Blocking Regions .................................................................... 2–27

2-22 Third Harmonic Undervoltage, Neutral Circuit (27TN)Setpoint Ranges ............................................................................... 2–27

2-23 Tripping on Reverse Power Flow(Over Power with Negative Pickup) ................................................. 2–29

2-24 Tripping on Low Foward Power(Under Power with Positive Pickup) ................................................ 2–31

2-25 Tripping on Overpower (Over Power with Positive Pickup) ........... 2–31

v

Table of Contents


Chapter 2 (cont'd)2-26 Tripping on Over Reactive Power with Element #3

(Over Power, Positive Pickup and Directional Power SensingSet to Reactive) ............................................................................... 2–32

2-27 Directional Power, 3-Phase (32) Setpoint Ranges .......................... 2–32

2-28 Loss of Field (40) Protective Approach 1 ....................................... 2–35

2-29 Loss of Field (40) Protective Approach 2 ....................................... 2–35

2-30 Loss of Field (40) Setpoint Ranges ................................................ 2–36

2-31 Negative Sequence Overcurrent Inverse Time Curves .................. 2–38

2-32 Negative Sequence Overcurrent (46) Setpoint Ranges .................. 2–38

2-33 Time Constant, Function 49 ............................................................ 2–39

2-34 49 Function Overload Curves .......................................................... 2–40

2-35 Stator Thermal Protection (49) Setpoint Ranges ............................ 2–41

2-36 Instantaneous Overcurrent (50) Setpoint Ranges ........................... 2–43

2-37 Instantaneous Neutral Overcurrent (50N) Setpoint Ranges ........... 2–43

2-38 Breaker Failure Logic Diagram ........................................................ 2–44

2-39 Breaker Failure (50BF) Setpoint Ranges ........................................ 2–45

2-40 Definite Time Overcurrent (50DT) Setpoint Ranges ....................... 2–46

2-41 Inadvertent Energizing Function Logic Diagram ............................. 2–48

2-42 Inadvertent Energizing (50/27) Setpoint Ranges ............................ 2–48

2-43 Inverse Time Neutral Overcurrent (51N) Setpoint Ranges ............. 2–49

2-44 Voltage Restraint (51VR) Characteristic ......................................... 2–51

2-45 Inverse Time Overcurrent with Voltage Control/VoltageRestraint (51VC/VR) Setpoint Ranges ............................................ 2–51

2-46 Phase Overvoltage (59) Setpoint Ranges ....................................... 2–52

2-47 Third Harmonic Overvoltage Scheme for GeneratorGround-Fault Protection ................................................................... 2–54

2-48 Third Harmonic Voltage Differential (59D) Setpoint Ranges .......... 2–54

2-49 Overvoltage, Neutral Circuit or Zero Sequence (59N)Setpoint Ranges ............................................................................... 2–55

2-50 Turn-to-Turn Stator Winding Fault Protection ................................. 2–57

2-51 Multipurpose Overvoltage (59X) Setpoint Ranges .......................... 2–57

2-52 Fuse Loss (60FL) Function Logic .................................................... 2–59

2-53 Fuse Loss (60FL) Setpoint Ranges ................................................. 2–60

2-54 M-3921 Field Ground Coupler .......................................................... 2–62

2-55 Field Ground Protection (64B/F) Setpoint Ranges ......................... 2–63

vi


Figures - Part 1 of 2 (cont'd) Page

Chapter 2 (cont'd)2-56 64S Function Component Connection Diagram .............................. 2–66

2-57 64S Function Time Delay Pickup Current Correlation .................... 2–67

2-58 100% Stator Ground Protection (64S) Setpoint Ranges ................ 2–67

2-59 Residual Directional Overcurrent (67N) Trip Characteristics .......... 2–68

2-60 Residual Directional Overcurrent (67N) Setpoint Ranges ............... 2–70

2-61 Out-of-Step Relay Characteristics ................................................... 2–72

2-62 Out-of-Step Protection Settings ....................................................... 2–72

2-63 Out-of-Step (78) Setpoint Ranges ................................................... 2–73

2-64 Example of Frequency (81) Trip Characteristics ............................ 2–75

2-65 Frequency (81) Setpoint Ranges ..................................................... 2–75

2-66 Frequency Accumulator (81A) Example Bands .............................. 2–77

2-67 Frequency Accumulator (81A) Setpoint Ranges ............................. 2–77

2-68 Rate of Change of Frequency (81R) Setpoint Ranges ................... 2–78

2-69 Differential Relay (87) Operating Characteristics ............................ 2–80

2-70 Phase Differential (87) Setpoint Ranges ......................................... 2–80

2-71 Ground Differential (87GD) Setpoint Ranges .................................. 2–81

2-72 Breaker Monitor (BM) Setpoint Ranges........................................... 2–82

2-73 Trip Circuit Monitoring Input ............................................................ 2–83

2-74 Trip Circuit Monitor (TC) Setpoint Ranges ...................................... 2–83

2-75 IPSlogic™ Function Setup ............................................................... 2–85

2-76 IPSlogic Function Programming .........................................................2–86

2-77 Selection Screen for Initiating Function Timeout ................................2–87

2-78 Selection Screen for Initiating Function Pickup ..................................2–87

2-79 Dropout Delay Timer Logic Diagram ...................................................2–88

2-80 Reset Delay Timer Logic Diagram ......................................................2–88

Chapter 33-1 M-3425A Front Panel ......................................................................... 3–3

3-2 Screen Message Menu Flow ............................................................. 3–3

3-3 Main Menu Flow ................................................................................. 3–4

vii

Table of Contents


Chapter 44-1 Multiple System Addressing Using

Communications Line Splitter ............................................................ 4–2

4-2 IPScom® Menu Selections ................................................................ 4–6

4-3 IPScom Program Icon ........................................................................ 4–8

4-4 New Device Profile Dialog Box .......................................................... 4–9

4-5 Communication Dialog Box .............................................................. 4–10

4-6 Setup System Dialog Box ............................................................... 4–11

4-7 Expanded Input Active State ........................................................... 4–12

4-8 Pulse Relay Expanded Output Screen ............................................ 4–12

4-9 Latch Relay Expanded Output Screen ............................................ 4–12

4-10 Relay Setpoints Dialog Box ............................................................. 4–13

4-11 Typical Setpoint Dialog Box ............................................................ 4–13

4-12 Expanded I/O Initiate ....................................................................... 4–13

4-13 All Setpoints Table Dialog Box (Partial) ......................................... 4–14

4-14 Configure Dialog Box (Partial) ......................................................... 4–15

4-15 Configure Dialog Box Partial(shown with Expanded Input/Outputs) ............................................. 4–16

4-16 Unit Date/Time Dialog Box .............................................................. 4–17

4-17 Target Dialog Box ............................................................................. 4–18

4-18 Trigger Events Screen with Expanded I/O ..................................... 4–19

4-19 Event Log Viewer ............................................................................. 4–19

4-20 Event Download Screen ................................................................... 4–20

4-21 Setup Oscillograph Recorder ........................................................... 4–20

4-22 Retrieve Oscillograph Record Dialog ............................................... 4–20

4-23 Profile Switching Method Dialog ...................................................... 4–20

4-24 Select Active Profile ........................................................................ 4–21

4-25 Copy Active Profile .......................................................................... 4–21

4-26 About IPScom® Dialog Box ............................................................. 4–21

4-27 Primary Status Dialog Box .............................................................. 4–22

4-28 Secondary Status Dialog Box.......................................................... 4–22

4-29 Accumulator Status Screen ............................................................. 4–23

4–30 Phase Distance Dialog Box ............................................................. 4–23

4-31 Loss of Field Dialog Box ................................................................. 4–24

4-32 Out of Step Dialog Box ................................................................... 4–24

viii



Chapter 4 (cont.)4-33 Phasor Dialog Box ........................................................................... 4–25

4-34 Sync Scope Screen ......................................................................... 4–25

4-35 Function Status Screen ................................................................... 4–26

4-36 IPSutil™ Main Menu Flow ............................................................... 4–29

4-37 Warning Message ............................................................................. 4–30

4-38 IPSutility Reset Relay Message ..................................................... 4–30

4-39 Monitor Status Screen ..................................................................... 4–31

4-40 Calibration Dialog Box ...................................................................... 4–31

4-41 Communication Dialog Box .............................................................. 4–32

4-42 Relay Comm Port Settings .............................................................. 4–32

4-43 Ethernet Settings .............................................................................. 4–32

4-44 Unit Date/Time Dialog Box .............................................................. 4–32

4-45 Change Communication Access Code Dialog Box ......................... 4–33

4-46 Change User Access Code Dialog Box .......................................... 4–33

4-47 Setup Dialog Box ................................................................................4–33

Tables - Part 1 of 2 Page

Chapter 11-1 M-3425A Device Functions .................................................................. 1–3

Chapter 22-1 Input Activated Profile ....................................................................... 2–3

2-2 Impedance Calculation ..................................................................... 2–17

2-3 Voltage Control Time Settings ......................................................... 2–34

2-4 Delta/Wye Transformer Voltage-Current Pairs ................................ 2–51

2-5 Typical Frequency Settings ............................................................. 2–63

2-6 Typical Brush Lift-Off Settings ........................................................ 2–64

2-7 Low Frequency Signal Injection Equipment Part NumberCross Reference .................................................................................2–66

Chapter 33-1 Recorder Partitions .............................................................................. 3–8

Chapter 44-1 Dead-Sync Time .................................................................................. 4–3

4-2 Protective System Firmware Association ............................................ 4–9

4-3 Microsoft Windows Keyboard Shortcuts .............................................4–28

ix

Table of Contents

Chapters - Part 2 of 2 Page

Chapter 5 Installation

5.1 General Information ............................................................................ 5–1

5.2 Mechanical/Physical Dimensions ...................................................... 5–2

5.3 External Connections ....................................................................... 5–10

5.4 Commissioning Checkout ................................................................ 5–16

5.5 Circuit Board Switches and Jumpers .............................................. 5–21

5.6 Low Frequency Signal Injection Equipment .................................... 5–25

Chapter 6 Testing

6.1 Equipment/Test Setup........................................................................ 6–2

6.2 Functional Test Procedures ............................................................... 6–6Power On Self Tests ......................................................................... 6–721 Phase Distance .............................................................................. 6–824 Volts per Hertz, Definite Time......................................................... 6–924 Volts per Hertz, Inverse Time ........................................................6–1025D Dead Check ................................................................................6–1225S Sync Check ................................................................................6–1427 Phase Undervoltage.......................................................................6–1627TN Third-Harmonic Undervoltage, Neutral .......................................6–1732 Directional Power, 3-Phase ............................................................6–2140 Loss of Field ..................................................................................6–2446 Negative Sequence Overcurrent Definite Time ..............................6–2646 Negative Sequence Overcurrent Inverse Time ..............................6–2749 Stator Overload Protection ......................................................... 6–2850 Instantaneous Phase Overcurrent .............................................. 6–3050BF/50BF-N Breaker Failure .......................................................... 6–3150/27 Inadvertant Energizing ........................................................... 6–3350DT Definite Time Overcurrent for Split-Phase Differential ......... 6–3450N Instantaneous Neutral Overcurrent ......................................... 6–3551N Inverse Time Neutral Overcurrent .......................................... 6–3651V Inverse Time Phase Overcurrent withVoltage Control/Restraint ................................................................. 6–3759 RMS Overvoltage, 3-Phase ........................................................ 6–3959D Third-Harmonic Voltage Differential ......................................... 6–4059N Overvoltage, Neutral Circuit or Zero Sequence ...................... 6–4159X Multipurpose Overvoltage ............................................................6–4260FL VT Fuse Loss Detection ............................................................6–4364F Field Ground Protection ...............................................................6–4464B Brush Lift Off Detection ...............................................................6–4664S 100% Stator Ground Protection by Injection ...............................6–4767N Residual Directional Overcurrent, Definite Time ..........................6–4967N Residual Directional Overcurrent, Inverse Time ..........................6–5178 Out of Step ....................................................................................6–5381 Frequency ......................................................................................6–5581A Frequency Accumulator ..............................................................6–5681R Rate of Change of Frequency .................................................. 6–57

x



Chapter 6 Testing (cont'd)

87 Phase Differential ..........................................................................6–5987GD Ground Differential ...................................................................6–61BM Breaker Monitoring .......................................................................6–63Trip Circuit Monitoring .........................................................................6–65IPSlogic™ ..........................................................................................6–66

6.3 Diagnostic Test Procedures ...............................................................6–67Overview.............................................................................................6–67Entering Relay Diagnostic Mode .........................................................6–67Output Relay Test (Output Relays 1–23 and 25) ................................6–68Output Relay Test (Power Supply Relay 24) ......................................6–69Input Test (Control/Status) .................................................................6–69Status LED Test .................................................................................6–70Target LED Test .................................................................................6–71Expanded Input/Output Test ...............................................................6–71Button Test .........................................................................................6–71Display Test .......................................................................................6–72COM1/COM2 Loopback Test ..............................................................6–72COM3 Test (2-wire) ............................................................................6–73Clock ON/OFF ....................................................................................6–74Relay OK LED Flash/Illuminated ........................................................6–75Auto Calibration ..................................................................................6–75Factory Use Only ...............................................................................6–75

6.4 Auto Calibration ..................................................................................6–76Phase and Neutral Fundamental Calibration .......................................6–76Third Harmonic Calibration .................................................................6–7764S 100% Stator Ground by Low Frequency Injection Calibration ......6–77Field Ground Calibration .....................................................................6–78

Appendices

Appendix A: Configuration Record Forms .........................................A–1

Appendix B: Communications............................................................B–1

Appendix C: Self-Test Error Codes ...................................................C–1

Appendix D: Inverse Time Curves ....................................................D–1

Appendix E: Layup and Storage ........................................................E–1

Appendix F: Declaration of Conformity ............................................. F–1

xi

Table of Contents


Chapter 55-1 M-3425A Mounting Dimensions – Horizontal Chassis ..................... 5–2

5-2 M-3425A Mounting Dimensions – HorizontalChassis (Expanded I/O) ..................................................................... 5–3

5-3 M-3425A Panel Mount Cutout Dimensions .......................................... 5–4

5-4 M-3425A Mounting Dimensions – Vertical Chassis ........................ 5–5

5-5 (H2) Mounting Dimensions ................................................................. 5–6

5-6 (H3) Mounting Dimensions for GE L-2 Cabinet ................................ 5–7



5-9 Optional Dual Power Supply ............................................................ 5–10

5-10 Expanded I/O Power Supply ............................................................ 5–10

5-11 External Connections ....................................................................... 5–11

5-12 Three-Line Connection Diagram ....................................................... 5–12

5-13 Function 25 Sync Check Three-Line Connection Diagram............. 5–13

5-14 Function 59X Turn-to-Turn Fault Protection Three-LineConnection Diagram ......................................................................... 5–14

5-15 Function 67N, 59D, 59X (Bus Ground), Three-LineConnection Diagram ......................................................................... 5–15

5-16 M-3425A Circuit Board ........................................................................5–23

5-17 M-3425A Circuit Board (Expanded I/O) ........................................... 5–24

5-18 Low Frequency Signal Injection Equipment Typical Connections ....5–25

5-19 20 Hz Frequency Generator Housing Panel Surface Mount .......... 5–26

5-20 20 Hz Frequency Generator Housing Panel Flush Mount ...............5–27

5-21 20 Hz Band Pass Filter Housing Panel Surface Mount ................. 5–28

5-22 20 Hz Band Pass Filter Housing Panel Flush Mount ......................5–29

5-23 20 Hz Measuring Current Transformer 400-5 A CT ........................ 5–30

Chapter 66-1 Voltage Inputs: Configuration V1 ......................................................... 6–3

6-2 Voltage Inputs: Configuration V2 ......................................................... 6–3

6-3 Current Inputs: Configuration C1 .......................................................... 6–4

6-4 Current Inputs: Configuration C2 .......................................................... 6–4

6-5 Current Configuration C3 ...................................................................... 6–5

6-6 64S Test Configuration ........................................................................ 6–5

6-7 Field Ground Coupler ..........................................................................6–45

6-8 Status LED Panel ...............................................................................6–70

6-9 M-3925A Target Module Panel ...........................................................6–71

xii


Figures (cont'd) Page

Chapter 6 (cont'd)

6-10 M-3931 Human/Machine Interface (HMI) Module ................................6–71

6-11 COM1/COM2 Loopback Plug ..............................................................6–72

6-12 RS-485 2-Wire Testing ........................................................................6–74

6-13 Current Input Configuration .................................................................6–79

6-14 Voltage Input Configuration ................................................................6–79



Appendix AA-1 Human-Machine Interface (HMI) Module ...........................................A–6

A-2 Communication Data & Unit Setup Record Form .............................A–7

A-3 Functional Configuration Record Form ............................................ A–10

A-4 Setpoint & Timing Record Form ...................................................... A–28

Appendix BB-1 Null Modem Cable: M-0423................................................................B–2

B-2 RS-232 Fiber Optic Network ..............................................................B–3

B-3 RS-485 Network ................................................................................... B–4

B-4 COM2 Pinout for Demodulated TTL Level Signal .............................B–4

Appendix DD-1 Volts/Hz (24) Inverse Time Curve Family #1 (Inverse Square) .......D–2

D-2 Volts/Hz (24) Inverse Time Family Curve #2 ...................................D–3

D-3 Volts/Hz (24IT) Inverse Time Curve Family #3 ................................D–4

D-4 Volts/Hz (24IT) Inverse Time Curve Family #4 ................................D–5

D-5 BECO Definite Time Overcurrent Curve ...........................................D–8

D-6 BECO Inverse Time Overcurrent Curve ............................................D–9

D-7 BECO Very Inverse Time Overcurrent Curve ................................. D–10

D-8 BECO Extremely Inverse Time Overcurrent Curve ........................ D–11

D-9 IEC Curve #1 – Inverse .................................................................. D–12

D-10 IEC Curve #2 – Very Inverse ......................................................... D–13

D-11 IEC Curve #3 – Extremely Inverse ................................................ D–14

D-12 IEC Curve #4 – Long Time Inverse .................................................. D–15

D-13 IEEE Inverse Time Overcurrent Curves ............................................ D–16

D-14 IEEE Very Inverse Time Overcurrent Curves .................................... D–17

D-15 IEEE Extremely Inverse Time Overcurrent Curves ........................... D–18

xiii

Table of Contents

Tables - Part 2 of 2 Page

Chapter 55-1 Jumpers ............................................................................................ 5–21

5-2 Dip Switch SW-1 .............................................................................. 5–22

5-3 Trip Circuit Monitor Input Voltage Select Jumper Configuration .... 5–22

Chapter 66-1 Output Contacts ............................................................................... 6–68

6-2 Input Contacts .................................................................................. 6–69

Appendix AA-1 Relay Configuration Table ..................................................................A–2

Appendix BB-1 Communication Port Signals .............................................................B–2

Appendix CC-1 Self-Test Error Codes ........................................................................C–1

C-2 IPScom® Error Messages .................................................................C–2

Appendix D

D-1A M-3425A Inverse Time Overcurrent Relay Characteristic Curves ...D–6

800-3425A-IB-04MC2 07/08©1998 Beckwith Electric Co.Printed in U.S.A. (9.21.01)

xiv



Introduction – 1

1–1

1Introduction

1.1 Instruction Book Contents ......................................................... 1–1

1.2 M-3425A Generator Protection Relay ........................................ 1–2

1.3 Accessories ................................................................................ 1–4

1.1 Instruction Book Contents

This instruction book includes six chapters and fiveAppendices.

Chapter 1: IntroductionChapter One summarizes relay capabilities,introduces the instruction book contents, anddescribes accessories.

Chapter 2: ApplicationChapter Two is designed for the person or groupresponsible for the application of the M-3425AGenerator Protection Relay. It includes functionaland connection diagrams for a typical application ofthe relay; and describes the configuration processfor the unit (choosing active functions), output contactassignment and input blocking designation. It alsoillustrates the definition of system quantities andequipment characteristics required by the protectiverelay, and describes the individual function settings.

Chapter 3: OperationChapter Three is designed for the person(s)responsible for the operation, direct setting, andconfiguration of the relay. Chapter Three providesinformation regarding the operation and interpretationof the unit's front panel controls and indicators,including operation of the optional M-3931, HumanMachine Interface (HMI) and M-3925A TargetModules. It further describes the procedures forentering all required data to the relay. Included in thischapter is a description of the process necessary forreview of setpoints and timing, monitoring functionstatus and metering quantities, viewing the targethistory, and setup of the oscillograph recorder.

Chapter 4: Remote OperationChapter 4 is designed for the person or groupresponsible for the remote operation and setting ofthe relay using the M-3820D IPScom®

Communications Software or other means.

Chapter 5: InstallationThe person or group responsible for the installationof the relay will find herein all mechanical informationrequired for physical installation, equipment ratings,and all external connections in this chapter. Forreference, the Three-Line Connection Diagram isrepeated from Chapter 2, Application. Further, acommissioning checkout procedure is outlined usingthe HMI option to check the external CT and VTconnections. Additional tests which may be desirableat the time of installation are described in Chapter6, Testing.

Chapter 6: TestingThis chapter provides step-by-step test proceduresfor each function, as well as diagnostic mode andautocalibration procedures for HMI-equipped units.

Appendix A: Configuration Record FormsThis Appendix supplies a set of forms to record anddocument the settings required for the properoperation of the relay.

Appendix B: CommunicationsThis Appendix describes port signals, protocols,and various topologies, and equipment required forremote communication.


1–2

Appendix C: Self-Test Error CodesThis Appendix lists all the error codes and theirdefinitions.

Appendix D: Inverse Time CurvesThis Appendix contains a graph of the four familiesof Inverse Time Curves for V/Hz applications, theInverse Time Overcurrent Curves, and the IECcurves.

Appendix E: Layup and StorageThis Appendix includes the recommended storageparameters, periodic surveillance activities and layupconfiguration for the M-3425A Generator ProtectionRelay.

Appendix F: Declaration of ConformityThis Appendix contains the Beckwith Electric Co.’sDeclaration of Conformity required by ISO/IEC17050–1:2004.

1.2 M-3425A GeneratorProtection Relay

The M-3425A Generator Protection Relay is amicroprocessor-based unit that uses digital signalprocessing technology to provide up to thirty-fourprotective relaying functions for generator protection.The relay can protect a generator from internalwinding faults, system faults, and other abnormalconditions.

The available internal functions of the relay arelisted in Table 1-1. The nomenclature follows thestandards of ANSI/IEEE Std. C37.2, StandardElectric Power Systems Device Function Numbers.

The control/status inputs can be programmed toblock any relay function and/or to trigger theoscillograph recorder. Any of the functions or thecontrol/status inputs can be individually programmedto activate any one or more of the programmableoutputs, each with a contact.

With the optional M-3931 HMI Module, all functionscan be set or examined using a local, menu-driven,2 line by 24 character alphanumeric display. OUT9–23 and IN 7–14 for units purchased with expandedI/O can only be set utilizing M-3820D IPScom®

Communications Software. The module allows localmetering of various quantities, including phase,neutral, and sequence voltages and currents, realand reactive power, power factor, and positivesequence impedance measurements.

The relay stores time-tagged target information forthe thirty-two most recent trips. For units equippedwith the optional M-3925A Target Module, LEDs areused to provide a detailed visual indication offunction operation for the most recent event.

The unit retains up to 472 cycles of oscillographwaveform data. This data can be downloaded andanalyzed using the M-3801D IPSplot® PLUSOscillograph Analysis Software.

The unit is powered from a wide input range switchmode power supply. An optional redundant powersupply is available for units without the ExpandedI/O. When expanded I/O option is selected, the unitincludes the second power supply.

The relay includes self-test, auto calibration, anddiagnostic capabilities, in addition to IRIG-B time-sync capability for accurate time-tagging of events.

Introduction – 1

1–3

Communication PortsThere are three physical communication portsprovided on the M-3425A. If the optional RJ45Ethernet port is purchased, then the relay includesfour physical communication ports:

• COM1, located on the relay front panel, isa standard 9-pin RS-232 DTE-configuredport. COM1 is used to locally set andinterrogate the relay using a portablecomputer.

• COM2, located on the rear of the relay, isa standard 9-pin RS-232 DTE-configuredport. When the optional RJ45 EthernetPort is enabled, COM2 port is disabled forcommunications. The demodulatedIRIG-B may still be used via the COM2Port when ethernet is enabled.

The RJ45 Ethernet port uses a 10Base-Ttype connection that accepts an RJ45connector using CAT5 twisted pair cable.The Ethernet port supports MODBUS overTCP/IP, BECO2200 over TCP/IP. The IPaddress can be obtained automaticallywhen using the DHCP protocol if enabled,or a static IP address can be manuallyentered, using the HMI.

• COM3, located on the rear terminal blockof the relay, is an RS-485 communicationsport.

The relay may be remotely set and interrogatedutilizing either a hard-wired RS-232 serial connectionor modem (COM2 when activated as RS-232, orCOM3), or when purchased, the ethernet connection(RJ45 activated).

M-3820D IPScom® Communications SoftwareIPScom is shipped standard with every relay. Thissoftware runs on a PC-compatible computer operatingunder Microsoft Windows® 95 or later. When properlyconnected using either a direct serial connection,modem or ethernet network connection. IPScomcan provide the following functions:

• Setpoint interrogation and modification

• Line status real-time monitoring

• Recorded oscillograph data downloading

NOITCNUF NOITPIRCSED

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V15 egatloVhtiw,tnerrucrevOemiTesrevnItniartseRrolortnoC

95 egatlovrevOesahP

D95 laitnereffiDegatloVcinomraH-drihT

N95 egatlovrevOlartueN

X95 egatlovrevOesoprup-itluM

LF06 noitceteDssoL-esuFTV

N76 tnerrucrevOlanoitceriDlaudiseR

87 )citsiretcarahcohm(petSfotuO

18 ycneuqerF

A18 noitalumuccAycneuqerF

R18 ycneuqerFfoegnahCfoetaR

78 tnerruClaitnereffiDesahP

DG78 laitnereffiD)ecneuqesorez(dnuorG

SPI cigolSPI

MB rotinoMrekaerB

CT gnirotinoMtiucriCpirT

snoitcnuFevitcetorPlanoitpO

52 kcehCcnyS

B46/F46 /noitcetorPdnuorGdleiFnoitceteDffO-tfiLhsurB

S46 ybnoitcetorPdnuorGrotatS%001noitcejnI

Table 1-1 M-3425A Device Functions


1–4

1.3 Accessories

M-3925A Target ModuleThe optional target module, shown below, includes 24individually labelled TARGET LEDs to indicateoperation of the functions on the front panel. Eightindividually labelled OUTPUT LEDs will be lit as longas the corresponding output contact is picked up.

TARGETS

OUTPUTSOUT 1

OUT 2

OUT 3

OUT 4

OUT 5

OUT 6

OUT 7

OUT 8

24 VOLTS/Hz

27 PHASE UNDERVOLTAGE

59 PHASE OVERVOLTAGE

27TN/59D/64S STATOR GND

59N/59X NEUT/GND OVERVOLT

32 DIRECTIONAL POWER

21 PHASE DISTANCE

40 LOSS OF FIELD

78 OUT OF STEP

50BF BREAKER FAILURE

50/27INADVERTENT ENRGNG

60FL V.T. FUSE LOSS

PHASE OVERCURRENT 50

PHASE OVERCURRENT 51V

NEUTRAL O/C 50N/51N

SPLIT PHASE DIFF 50DT

STATOR OVERLOAD 49

NEG SEQ OVERCURRENT46

FIELD GND/BRUSH LIFT64F/B

FREQUENCY 81/81R/81A

PHASE DIFF CURRENT 87

GND DIFF/DIR O/C 87GD/67N

TRIP CIRCUIT MONITOR TC

IPS LOGIC LOGIC

Figure 1-1 M-3925A Target Module

M-3933/M-0423 Serial Communication CablesThe M-3933 cable is a 10-foot RS-232 cable for usebetween the relay’s rear panel (COM2) port and amodem. This cable has a DB25 (25-pin) connector(modem) and a DB9 (9-pin) at the relay end.

The M-0423 cable is a 10-foot null-modem RS-232cable for direct connection between a PC and therelay’s front panel COM1 port, or the rear COM2port. This cable has a DB9 (9-pin) connector ateach end.

M-3931 HMI (Human-Machine Interface) ModuleThe optional HMI module provides the means tointerrogate the relay and to input settings, accessdata, etc. directly from the front of the relay. Itsoperation is described in detail in Section 3.1, FrontPanel Controls.

��

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Figure 1-2 M-3931 Human-MachineInterface (HMI) Module

M-3801D IPSplot® PLUS Oscillograph AnalysisSoftware PackageThe IPSplot PLUS Oscillograph Analysis Softwareruns in conjunction with the IPScom®

Communications Software on any IBMPC-compatible computer, enabling the plotting,printing, and analysis of waveform data downloadedfrom the M-3425A Generator Protection Relay.

Application – 2

2–1

2 Application

2.1 Configuration ............................................................................... 2–2

2.2 System Diagrams ....................................................................... 2–8

2.3 Setpoints and Time Settings ................................................... 2–14

Menu screens in the following examples are as theywould appear on units equipped with the M-3931Human Machine Interface (HMI) Module. The samesetting may be entered remotely using M-3820DIPScom® Communications Software (see Chapter4, Remote Operation).

Chapter Two is designed for the person or groupresponsible for the application of the M-3425AGenerator Protection Relay. It includes functionaland connection diagrams for a typical application ofthe relay; and describes the configuration processfor the unit (enabling functions), output contactassignment and input blocking designation. It alsoillustrates the definition of system quantities andequipment characteristics required by the protectiverelay, and describes the individual function settings.


2–2

2.1 Configuration

Configuration of the relay consists of enabling thefunctions for use in a particular application,designating the output contacts each function willoperate, and which control/status inputs will blockthe function. The choices include eight programmableoutput contacts (OUT1–OUT8) and six control/statusinputs (IN1–IN6), or OUT9–23 and IN7–14 for unitspurchased with expanded I/O, plus a block choicefor fuse loss logic operation (see Section 2.3,Setpoint and Time Settings, 60FL Fuse Losssubsection for details).

The blocking control/status inputs and output contactassignments must be chosen before entering thesettings for the individual functions. Both may berecorded on the Relay Configuration Table inAppendix A, Configuration Record Forms.

Control/status input IN1 is preassigned to be the52b breaker status contact. If a multiple breakerscheme is used, the control/status input IN1 mustbe the series combination of the “52b” breakercontacts. Additional user-chosen control/statusinputs may initiate actions such as breaker failure,initiate external fuse loss detection, or trigger theoscillograph recorder.

The relay allows the user to designate up to sixlogic functions which perform similarly to internalrelay functions, using IPSlogicTM. These externalfunctions may be enabled or disabled, and outputcontacts and blocking control/status inputs arechosen the same as for the internal functions. Theexternal functions are described in further detail inSection 2.3, Setpoint and Time Settings, IPSlogicsubsection.

27#1 PHASE UNDERVOLTAGEdisable ENABLE

27#1 BLOCK INPUTfl i6 i5 i4 i3 i2 I1

27#1 RELAY OUTPUTo8 o7 o6 o5 o4 o3 o2 O1

■ NOTE: Uppercase text indicates selection.

This menu designation is required for each relay function. Afterenabling the function, the user is presented with the two followingscreens:

This submenu item assigns the blocking designations (up to six, plusfuse-loss logic) for the enabled function. “OR” logic is used if more thanone input is selected.

This submenu item assigns the output contacts (up to eight) for theparticular relay function. If no output contacts are assigned, the functionwill not generate any output or targets even though the function is enabled.

■ NOTE: Units with expanded I/O can only set OUT9–OUT23 and IN7–IN14 using IPScom®.

Application – 2

2–3

ProfilesUp to four setpoint profiles may be used. Eachprofile contains a complete set of functionconfiguration and settings. One of the four profilesmay be designated as the Active Profile, which willcontain the settings that the relay will actively use.

The Active Profile may be chosen manually or bycontact input. When the profile Switching Method isset to Manual, the HMI, remote communications orone of the IPSlogic elements will select the ActiveProfile. When the Switching Method is set to InputContact, the profile is selected by the input contacts.When Input Contact is selected, only the inputcontacts can switch the relay’s profile, and none ofthe Manual methods will switch the profile.

A Copy Profile feature is available. This featurecopies an image of the Active Profile to any one ofthe other three profiles. This feature can speed upthe configuration process. Consider, for example, asituation where a breaker will be removed fromservice. Two profiles will be used: an “In Service”profile (Profile 1), and an “Out of Service” profile(Profile 2).

Profile 2 will be identical to the “In Service” profile,with the exception of the overcurrent settings.

Profile 1 is set to be the Active Profile, and allsetpoints entered. An image of Profile 1 will then becopied to Profile 2 with the Copy Active Profilecommand. Profile 2 is then selected as the ActiveProfile, and the overcurrent setpoints modified.

▲ CAUTION: During profile switching, relay operationis disabled for approximately 1 second.

FunctionsConfiguration of the relay consists of enabling thefunctions for use in a particular application,designating the output contacts each function willoperate, and which control/status inputs will blockthe function. The choices include eight programmableoutput contacts (OUT1–OUT8) and six control/statusinputs (IN1–IN6)/(OUT1–OUT23 and IN1–IN14 forexpanded I/O units) plus a block choice for fuseloss logic operation (see Section 2.3, Setpoint andTime Settings, 60FL Fuse Loss subsection fordetails.)

Control/status inputs may also initiate actions, suchas Breaker Failure Initiate, Trigger OscillographRecorder, Switch Setpoint Profile, or initiate anIPSlogic function. The control/status inputs andoutput contacts need to be chosen before configuringthe individual functions. Both can be recorded onthe Relay Configuration Table in Appendix A, Forms.

Special ConsiderationsControl/status input IN1 is preassigned to be the52b breaker contact. IN5 and IN6 may be used toselect setpoint profiles.

Outputs 1–6 and 9–23 are form “a” contacts (normallyopen), and outputs 7 and 8 are form “c” contacts(center tapped “a” and “b” normally closed) contacts.Output contacts 1–4 contain special circuitry forhigh-speed operation and pick up 4 ms faster thanoutputs 5–8. Function 87 outputs are recommendedto be directed to OUT1 through OUT4 contacts.

Relay System SetupThe system setup consists of defining all pertinentinformation regarding the system quantities. Setupscreens shown here may be accessed through theSYSTEM SETUP menu. Regardless of the functionsthat are enabled or disabled, all System Setupvalues are required to be input. Several functionsrequire proper setting of these values for correctoperation. The Nominal Voltage and Nominal Currentsettings are needed for proper normalization of perunit quantities. CT and VT ratios are used only inmonitoring and displaying system primary quantities.

Input 5 Input 6 Selection

Open Open Profile 1

Closed Open Profile 2

Open Closed Profile 3

Closed Closed Profile 4

Table 2-1 Input Activated Profile


2–4

INPUT ACTIVATED PROFILESdisable enable

ACTIVE SETPOINT PROFILE________________

COPY ACTIVE PROFILETO_PROFILE_1

NOMINAL VOLTAGE_____________ Volts

NOMINAL CURRENT______________ Amps

VT CONFIGURATIONline-line line-ground

line-gnd_to_line-line

DELTA-Y TRANSFORMdis delta_ab delta_ac

PHASE ROTATIONa-c-b a-b-c

When Input Activated Profiles is disabled, the Active Profile can beselected using HMI or remote communication. When enabled, theActive Profile is selected by the state of Input 5 and 6 (see Table 2-1).

This screen sets the active setpoint profile.

This screen initiates a copy of the Active Profile to any one of theother profiles.

The secondary VT voltage when primary voltage is equal to therated generator voltage. Vnominal=( V gen rated I VT ratio) for L-LVT connections. Vnominal=(Vgen rated I (S3 VT ratio)) for L-G VTconnections.

The secondary CT current of the phase CT’s with rated generatorcurrent. I nom = (VA I (Vgen rated(S3) )(CT ratio) )

Indicates VT connection. (See Figure 2-7, Three-Line ConnectionDiagram.) When line-ground voltages are used, functions 24, 27, and59 may operate for line-ground faults. If this is not desired, the line-gnd-to-line-line selection should be used to prevent operation of thesefunctions for line-ground faults.When line-gnd-to-line-line is selected,the relay internally calculates line-line voltages from line-ground voltagesfor all voltage-sensitive functions. This line-gnd-to-line-line selectionshould be used only for a VT line-to-ground nominal secondary voltageof 69V (not for 120 V). For this selection, the nominal voltage settingentered should be line-line nominal voltage, which is S3 times line-groundnominal voltage, and voltage function pickup setpoints calculationshould be made using line-to-line voltage.

When the generator is connected through a Delta-Y (delta ab or deltaac) unit transformer, the relay will internally consider the 30° phaseshift for 51V and 21 functions.It defines the connection of the Deltawindings of the Delta /Y transformer. If the polarity of the A windingis connected to the non-polarity of the C winding, it is defined asDelta-AC and if the polarity of the A winding is connected to the non-polarity of the B winding, then it is defined as Delta-AB. In the ABCphase rotation, delta lags Y by 30 degrees in Delta-AC and deltaleads Y by 30 degrees in Delta-AB.

This screen allows the user to select the phase rotation of theM-3425A to match the generator.

Application – 2

2–5

This screen allows the selection of RMS or DFT for the 59 and 27functions. The magnitude can be selected as the RMS of the totalwaveform (including harmonics) or the RMS of the 60/50 Hz fundamentalcomponent of the waveform using the Discrete Fourier Transform(DFT). When the RMS option is selected, the magnitude calculationis accurate over a wide frequency range (10 to 80 Hz) and the accuracyof the time delay is +20 cycles. When the DFT option is selected, themagnitude calculation is accurate near 50 or 60 Hz and the timeraccuracy is K1 cycle. When a wider frequency response is needed,select RMS. For generator protection applications, it is recommendedto use the RMS selection. RMS is the default when shipped from thefactory. For 59 function when positive sequence voltage is selected,the calculation uses DFT irrespective of DFT/RMS selection.

If the 50DT function is to be used for split-phase differential protection,this selection should be enabled. If the 50DT function is to be usedas a definite time overcurrent function, or if 50DT is not enabled, thisselection should be disabled.

If pulse relay operation is selected, output will dropout after the seal-in delay expires, even if the condition which caused the relay to pickup is still out of band. When selected, latching outputs are notavailable.*

If any of the outputs are selected as latched, then after tripping, thisoutput will stay activated, even when the tripping condition is removed.The Latched Output can be reset using the TARGET RESETpushbutton. When selected, Pulse Relay is not available. *

Minimum time the output contact will remain picked up to ensureproper seal-in, regardless of the subsequent state of the initiatingfunction. Individual Seal-In settings are available for all outputs.*

This designates the “active” state for the individual status input.Programming uppercase (see I6) causes the “active” or “operated”condition to be initiated by the external contact opening. Otherwise,external contact closure will activate the input.*

*■■■■■ NOTE: Settings for expanded I/O must be made through IPScom®.

Ratio of the phase VTs. Example: 13,800 V : 120 V =13,800/120=115:1

Ratio of the neutral VT. Example: 13,800 V : 120 V =13,800/120=115:1

Ratio of auxiliary VT. Example: 13,800 V : 120 V =13,800/120=115:1

Ratio of phase CTs. Example: 3,000:5 = 3000/5=600:1

Ratio of neutral CT. Example: 3,000:5 = 3000/5=600:1

59/27 MAGNITUDE SELECTrms dft

50DT SPLIT-PHASE DIFFdisable enable

PULSE RELAYo8 o7 o6 o5 o4 o3 o2 o1

LATCHED OUTPUTSo8 o7 o6 o5 o4 o3 o2 o1

RELAY SEAL-IN TIME OUT1_____________ Cycles

ACTIVE INPUT OPEN/closeI6 i5 i4 i3 i2 i1

V.T. PHASE RATIO______________ : 1

V.T. NEUTRAL RATIO_______________ :1

V.T. VX RATIO_______________ :1

C.T. PHASE RATIO______________ : 1

C.T. NEUTRAL RATIO______________ : 1


2–6

SETUP SYSTEM

Note: Pulse/Latched Relay Outputs should be selected in 2 stepsi)Deselect Latched/Pulse Relay Outputs and Saveii) Select Pulse/Latched Outputs and Save

Nominal Frequency: 60 Hz C.T. Secondary Rating: 5A

Input Active State Expanded

Save Cancel

Nominal Voltage: 120

Nominal Current: 5.00

140.0 V50.0 V

6.00 A0.50 A

Delta-Y Transform

Disable Delta-AB Delta-AC

OpenClose

OpenClose

OpenClose

OpenClose

OpenClose

6 5 4 3 2 1OpenClose

Input Active State:

1 .0

1.0

1.0

10

10

V.T. Configuration:

59/27 Mag. Select:

Phase Rotation:

V.T. Phase Ratio:

V.T. Neutral Ratio:

V.T. VX Ratio

C.T. Phase Ratio:

C.T. Neutral Ratio:

Outputs: 1 2 3 4 5 6 7 8Pulse Relay

Injection Frequency for F64S: 20 Hz

L ine to Ground L ine to L ine L ine-Ground to L ine-L ine

RMS DFT

ABC ACB

50DTSplit PhaseDifferential:

Enable

Disable

Outputs: 1 2 3 4 5 6 7 8Latched Outputs

Pulse Relay Expanded Outputs

Latch Relay Expanded Outputs

Relay Seal-In Time

OUT 1:

2:

3:

4:

5:

6:

7:

8:

30

30

30

30

30

30

30

302cycles

8160cycles

8160cycles

OUT 9:

10:

11:

12:

13:

14:

15:

16:

30

30

30

30

30

30

30

302cycles

OUT 17

18

19

20

21

22

23

30

30

30

30

30

30

30

Relay Seal-In Time Expanded

SETUP

:1

:1

:1

:1

:1

1.0

1.0

1.0

1

1

6550.0

6550.0

6550.0

65500

65500

Figure 2-1 Setup System Dialog Box

Path: Relay menu / Setup submenu / Setup System command

COMMAND BUTTONS

Input Active When the unit is equipped with expanded I/O, this command opens the Expanded Input ActiveState State screen (Figure 2-2), to allow the selection of Expanded Inputs 7 through 14.Expanded

Pulse/Latch When the unit is equipped with expanded I/O, this command opens the Pulse/LatchRelay screen (Figures 2-3 and 2-4) to allow the selection of expanded outputs 9 through 23.ExpandedOutputs

Save When connected to a protection system, sends the currently displayed information to the unit.Otherwise, saves the currently displayed information.

Cancel Returns you to the IPScom® main window; any changes to the displayed information are lost.

■■■■■ NOTE: Checking the inputs for the Active Input Open parameter designates the “operated” state established byan opening rather than a closing external contact.

Application – 2

2–7

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Figure 2-2 Selection Screen for Expanded Input


? X

OUTPUT9

OUTPUT10

OUTPUT11

OUTPUT12

OUTPUT13

OUTPUT14

OUTPUT15

OUTPUT16

OUTPUT17

OUTPUT18

OUTPUT19

OUTPUT20

OUTPUT21

OUTPUT22

OUTPUT23

OK

Cancel

Figure 2-3 Pulse Relay Expanded Output Screen

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Figure 2-4 Latch Relay Expanded Output Screen


2–8

2.2 System Diagrams

50DT

Utility System

52Unit

52Gen

50BFPh

87

492132 504078 60FL 51V 50/27

27

81R 81 27 59 24

64F 64B

M-3921+

-

CT

VT

M-3425A

87GD 50N50

BFN 51N

R

64S27TN

27

32R


Low-impedance Grounding with Ground Differentialand Overcurrent Stator Ground Fault Protection




M-3425A TypicalConnection Diagram

25

59D

VT (Note 1)

Targets(Optional)


Metering

Waveform Capture

IRIG-B



Programmable I/O

Self Diagnostics


Rear Ethernet Port (Optional)


BreakerMonitoring


67N67N Polarization(Software Select)

81A

50N50BFN 51N

46

59X

59N

3VO (Calculated)VX

VN

3IO

IN

67N Operating Current(Software Select)

VT (Note 1)

(Note 3)

(Note 5)



(Software Select)

VX3VO (Calculated)

CT (Neutral)(Notes 2 & 5)

CTM

(Metering)

M

(Metering)


Event Log

■ NOTES:1. When 25 function is enabled, 59X, 59D with V

X and 67N with V


2. When 67N function with IN (Residual) operating current is enabled, 87GD is not available, and vice

versa.

3. The 50BFN, 50N, and 51N may utilize either the neutral current or the residual current.

4. When used as a turn-to-turn fault protection device.

5. The current input IN can be either from neutral current or residual current.




Figure 2-5 One-Line Functional Diagram

Application – 2

2–9

Utility System

52Unit

52Gen

81R 81 59 27 24

M-3921+

-

VT

CT

M-3425A

50N 51N

R

CT

27

32R


Low-impedance Grounding withOvercurrent Stator Ground Fault Protection




M-3425A TypicalConnection Diagram(Configured for Split-Phase Differential)

25

59D

50DT

67N

Targets(Optional)


Metering

Waveform Capture

IRIG-B



Programmable I/O

Self Diagnostics


Rear EthernetPort (Optional)


BreakerMonitoring


27TN

81A

46492132 504078 60FL 51V 50/27

2764F 64B

59X

64S 59N


VT (Note 1)

VT (Note 1)

67N Polarization(Software Select)

3VO (Calculated)

VX

VN

(Note 2)

CT (Note 3)

(Note 4)


(Software Select)

VX 3VO (Calculated)

CT (Neutral)(Note 5)

M

(Metering)

M

(Metering)


Event Log

■ NOTES:

1. When 25 function is enabled, 59, 59X, 59D with VX and 67N with V

X are not available, and vice

versa.

2. When used as a turn-to-turn fault protection device.

3. CTs are connected as split-phase differential current.

4. 67N operating current can only be selected to IN (Residual) for this configuration.

5. The current input (IN) can be either from neutral current or residual current.




Figure 2-6 Alternative One-Line Functional Diagram (configured for split-phase differential)


2–10

52Gen

A B C

Generator

58 59

56 57

54 55

OtherRelays

R45 44

M-3425A

M-3425A

WARNING: ONLY dry contact inputs must beconnected because these contact inputs areinternally wetted. Application of externalvoltage on these inputs may result indamage to the units.NOTE: M-3425A current terminal polarity marks( . ) indicate "entering" current direction whenprimary current is "from" the generator to thesystem. If CT connections differ from thoseshown, adjust input terminals.

M-3921Field Ground

Coupler Module

10

11

52b

M-3425A

43 41 3942 40 38

M-3425A

Two Vt Open-DeltaConnection

43 41 3942 40 38

M-3425A

Three VT Wye-WyeConnection

434139 424038

M-3425A

Three VT Wye-WyeAlternate Connection

A

B

C

A

B

C

55 54

57 56

59 58

M-3425A

55 54

57 56

59 58

M-3425AOther

RelaysOther

Relays

a b c

a b c a b c

OR OR

High Impedance Grounding

52 53

M-3425A

R Low Impedance Grounding

OR

50 51

48 49

46 47

M-3425AOther

Relays1

1

1

A B C

Example of Control/Output Connections

M-3425A

PowerSupply

52G

+

-

TRIPALARM

SELF-TEST

FAILUREALARM

POWEROK

STATUSALARM

VTFUSELOSS

EXTERNALINPUTS

ALARMOUTPUTS

CONTROLOUTPUTS

TRIPOUTPUT

BREAKERFAILUREINITIATE

52Ga

5

3 336

OSCILLOGRAPHRECORDER

INITIATE

60FL52b

2

60 6261 63 11 10

4

+

-

DC: 24V 48V

ORDC: 110V 125V 220V 250VAC: 110V 120V 230V 240V

16

15

12

13

4

5

6

Alarm output can be grouped to a single alarmat the discretion of user.Available control output to service other relaysfor VT Fuse Loss can be designated.Input contact number is designated by user.

2

3

1 Wire to split phase differential CTs foruse with 50DT split phase function.Required generator breaker status input(52b). Contact is closed when generatorbreaker is open. Use unit breakercontact if no generator breaker present.Output contact pairs designated byuser.

Figure 2-7 Three-Line Connection Diagram

Application – 2

2–11

52Gen

A B C

Generator

10

11

52b

M-3425A

VX

43

41

39

42

40

38

M-3425A

Three VT Wye-WyeConnection

A B C

OR

VX

64

65

M-3425A

64

65

M-3425A

VX

Two VT Open-DeltaConnection

43

41

39

42

40

38

M-3425A

OR

A B C

Used when GeneratorSide VTs are connected

Line-Ground.

Used when Generator Side VTsare connected Line-Line

Used for Sync Check (25)

■ NOTE: When VX is connected for Sync Check function (25), turn-to-turn fault protection (59X) is not

available.

Figure 2-8 Function 25 Sync Check Three-Line Connection Diagram


2–12

52Gen

A B C

Generator

10

11

52b

M-3425A

a b c

52 53

M-3425A


65

64

M-3425A

A B C

Line to NeutralVoltage Rated

Cable

R

R45 44

M-3425A


OR

VX used for turn-to-turnfault protection (59X)

VX

■ NOTE: When VX is connected for turn-to-turn fault protection, 59X and 25 functions are not available.

Figure 2-9 Function 59X Turn to Turn Fault Protection Three-Line Connection Diagram

Application – 2

2–13

52Gen

A B C

Generator

10

11

52b

M-3425A

a b c

52 53

M-3425A


A

B

C

I N input can be connectedeither at Neutral or as Residual.

I N input can be connectedeither at Neutral or as Residual.

OR

R45 44

M-3425A


65 64

M-3425A

R

59XBus Ground

65

64

M-3425A

A B C

R

67N, 59DConnection

53

52

M-3425A

67NConnection

Residual CT

Bus Section

VX

VX can be used for both 67N and59D if connected in this manner.

■ NOTE: When VX is connected for bus ground protection (59X, 67N, or 59D) , 25 function is not available.

Figure 2-10 Function 67N, 59D, 59X (Bus Ground) Three-Line Connection Diagram


2–14

If Zone 1 is not set to see the transmission system,out-of-step blocking is not recommended.

When Zone 3 is used for Out-of-step blocking, theout of step delay is used for the detection of thetransit time of the swing between Zone 3 and Zone2 impedances.

The load encroachment blinder function can be setwith a reach and an angle as shown in Figure 2-13.When enabled, this feature will block the 21 Functionfrom misoperating during high load conditions.

When the generator is connected to the system througha delta/wye transformer, proper voltages and currents(equivalent to the high side of the transformer) must beused in order for the relay to see correct impedancesfor system faults. By enabling the Delta-Y Transformfeature (see Section 2.1, Configuration, Relay SystemSetup), the relay can internally consider the 30° phaseshift (30° lead delta-ab or 30° lag delta-ac) through thedelta/wye transformer, saving auxiliary VTs. Impedancecalculations for various VT connections are shown inTable 2-2. All impedance settings are secondary relayquantities and can be derived from the following formula:

Z SEC

= ZPRI

x (RC ÷ R

V)

where ZSEC = secondary reflected impedance, ZPRI =primary impedance, R

C = current transformer ratio,

and RV = voltage transformer ratio.

The minimum current sensitivity depends on theprogrammed reach (diameter and offset). If thecurrent is below the minimum sensitivity current,the impedance calculated will saturate, and not beaccurate. This will not cause any relay misoperation.

An overcurrent supervision feature can be enabled,which will block the 21 function when all threephase currents are below the pickup value.

2.3 Setpoints and Time Settings

The individual protective functions, along with theirmagnitude and timing settings are described in thefollowing pages. Settings for disabled functions donot apply. Some menu and setting screens do notappear for functions that are disabled or notpurchased. Menu screens are as they would appearon units equipped with the M-3931 HMI Module.The same setting may be entered using M-3820DIPScom Communications Software.

For those units equipped with Expanded I/O, settingof Expanded Inputs and Outputs is accomplishedby selecting “Expanded I/O” from the individualfunction screen. IPScom® will display the ExpandedI/O Initiate dialog screen (Figure 2-11).

21 Phase DistanceThe Phase Distance function (21) is designed forsystem phase fault backup protection and isimplemented as a three-zone mho characteristic.

Three separate distance elements are used to detectAB, BC, and CA fault types. The ranges andincrements are shown in Figure 2-14. The diameter,offset, system impedance angle (relay characteristicangle), and definite time delay need to be selectedfor each zone for coordination with the systemrelaying in the specific application.

Zone 1, Zone 2 and Zone 3 may be used for backupprotection for unit transformer and transmissionfaults. Zone 3 in conjunction with Zone 2 can beused to detect an Out of Step condition and it canbe programmed to block Function 21 #1 and/or 21#2. If Zone 3 is being used for out-of-step blocking,it does not trip.

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Figure 2-11 Selection Screen for Expanded I/O Initiate

Application – 2

2–15

21 #1 DIAMETER______________ Ohms

21 #1 OFFSET______________ Ohms

21 #1 IMPEDANCE ANGLE____________ Degrees

21#1 LOAD ENCROACHMENTdisable ENABLE

21 #1 LOAD ENCR ANGLE____________ Degrees

21 #1 LOAD ENCR R REACH______________ Ohms

21 #1 OC SUPERVISIONdisable enable

21 #1 OC SUPERVISION______________ Amps

21 #1 OUT OF STEP BLOCKdisable enable

21 #1 DELAY_____________ Cycles

21 #3 OUT OF STEP DELAY_____________ Cycles

Typically the first zone of protection is set to an impedance valueenough in excess of the first external protective section (typicallythe unit transformer) to assure operation for faults within thatprotective zone. See Figure 2-12, Phase Distance (21) Coverage.

A negative or positive offset can be specified to offset the mhocircle from the origin. This offset is usually set at zero. See Figure2-13, Phase Distance (21) Function Applied For System Backup.

The impedance angle should be set as closely as possible to theactual impedance angle of the zone being protected.

When enabled the 21 Function is blocked when the impedancefalls within the zone but above the R Reach and below the LoadEncroachment angle.

■ NOTE: The 21 #2 and #3 zone settings can be set for an additionalexternal section of protection on the system (typically transmissionZone 1 distance relays) plus adequate overreach. #2 and #3 screensare identical to those in #1. Element #3 also includes out-of-steptime delay when out-of-step blocking is enabled for Zone #1 and/orZone #2.

When enabled, the overcurrent supervision blocks the 21 Func-tion when all three phase currents are below the pickup.

When enabled the 21 Function is blocked on the detection of anout-of-step condition.

The time delays are set to coordinate with the primary protectionof those overreached zones and, when applicable, with the breakerfailure schemes associated with those protective zones.

In Zone #3 when out-of-step blocking is enabled for Zone #1 or #2.


2–16

3

21

52

Protected Range Zone 1

+X

+R

–X

–R

M-3425A



52

Bus

52

Figure 2-12 Phase Distance (21) Coverage

■ NOTE: The reach settings of the distance elements (21) should not include generator impedance sincethe distance measurement starts at the VT location. However, since the neutral side CTs areused for this function, backup protection for generator Phase-to-Phase faults is also provided

+jX

+R

–jX

–R

R2

R1

δ 2 δ 1

Θ

Circle Diameters

Unit Transformer

Transmission Line

ZONE 1

ZONE 3

ZONE 2

Block

Block

R1 Zone 1 Load Encroachment Blinder R Reach

R2 Zone 2 Load Encroachment Blinder R Reach

δ1 Zone 1 Load Encroachment Blinder Angle

δ2 Zone 2 Load Encroachment Blinder Angle

Θ Impedance Angle Setting

■ NOTE: Zone #3 is used for power swing detection in this example.

Figure 2-13 Phase Distance (21) Function Applied for System Backup

Application – 2

2–17

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Table 2-2 Impedance Calculation

#1 #2 #3

@ : WARNING, You have not selected an output!

Out of Step Block Enable Out of Step Block Disable

100.0 Ohm(s)

100.0 Ohm(s)

90°

90°

100.0 Ohm(s)

8160 Cycles

Enable

Disable

0.1 Ohm

-100.0 Ohm(s)

0°

1°

0.1 Ohm

1 Cycle

0.1 A

Circle Diameter:

Offset:

Impedance Angle:

Load Encr. Angle:

Load Encr. R Reach:

Delay:

Overcurrent SV:

(21) PHASE DISTANCE

X?

20 A

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

CancelSave

Expanded I/O’s

Enable

Disable

Figure 2-14 Phase Distance (21) Setpoint Ranges


2–18

24 Overexcitation Volts/HzThe Volts-Per-Hertz function (24) providesoverexcitation protection for the generator and unit-connected transformers. This function incorporatestwo definite time elements which can be used torealize traditional two-step overexcitation protection.In addition, the relay includes an inverse timeelement that provides superior protection by closelyapproximating the combined generator/unittransformer overexcitation curve. Industry standardinverse time curves may be selected along with alinear reset rate which may be programmed tomatch specific machine cooling characteristics. Thepercent pickup is based on the Nominal Voltagesetting and the nominal frequency. The V/Hz functionprovides reliable measurements of V/Hz up to 200%for a frequency range of 2–80 Hz. The ranges andincrements are presented in Figure 2-16.

Setting this relay function involves determining thedesired protection levels and operating times. Thefirst step is to plot the combined generator andassociated unit transformer overexcitation capabilitylimits. This data is typically available from themanufacturer and should be plotted on the samevoltage base. Depending on the resultingcharacteristic, one of the four families of inversetime curves (as shown in Appendix D, InverseTime Curves) can be matched to provide theprotection. The two definite time elements can beused to further shape the protection curve or providean alarm.

Figure 2-15 illustrates a composite graph of generatorand transformer limits, a chosen inverse time curveand pickup, and a definite time pickup and delay.

24DT #1 PICKUP_______________ %

24DT #1 DELAY_____________ Cycles

24DT #2 PICKUP_______________ %

24DT #2 DELAY_____________ Cycles

24IT PICKUP_______________ %

24IT CURVEcrv#1 crv#2 crv#3 crv#4

24IT TIME DIAL________________

24IT RESET RATE____________ Seconds

Definite time setpoint #1 establishes the V/Hz level above which theprotection operating time will be fixed at the definite time delay #1.

Delay time #1 establishes the operation time of the protection forall V/Hz values above the level set by definite time setpoint #1.

Definite time setpoint #2 could be programmed to alarm, alerting theoperator to take proper control action to possibly avoid tripping.

Time to operation at any V/Hz value exceeding Definite time setting#2.

The pickup value is the V/Hz value at which the chosen inversecurve begins protective operation. Typical value is 105%.

Allows the user to designate the appropriate curve family for thisprotection application. These curves are shown in Appendix D,Inverse Time Curves.

The appropriate curve in the family is designated by the associated“K” value of the curve.

The value entered here should be the time needed for the unit tocool to normal operating temperature if the V/Hz excursion timewas just under the trip time.

Application – 2

2–19

M-3425A Firmware Versions D-0114VXX.XX.XXand Earlier■ NOTE: When the inverse time element is

enabled, the definite time element #1must be enabled which will providedefinite minimum time setting for theinverse time curve.

The following steps must be followed when settingthe inverse time element and definite time element#1:

1. The pickup of the inverse time elementmust be less than the pickup of thedefinite time element #1

2. The operating time of the inverse timeelement at the definite time element #1pickup should be greater than the definitetime element #1 time delay setting(A2>A1 in Figure 2-15).

3. When the inverse time element isenabled, definite time element #1 shouldnot be used for alarm. Only definite timeelement #2 can be used for alarm.

After any V/Hz excursion, cooling time must alsobe taken into account. If the unit should again besubjected to high V/Hz before it has cooled tonormal operating levels, damage could be causedbefore the V/Hz trip point is reached. For thisreason, a linear reset characteristic, adjustable totake into account the cooling rate of the unit, isprovided. If a subsequent V/Hz excursion occursbefore the reset characteristic has timed out, thetime delay will pick up from the equivalent point (asa %) on the curve. The Reset Rate setting enteredshould be time needed for the unit to cool to normaloperating temperature if the V/Hz excursion timewas just under the trip point.

M-3425A Firmware Version D-0150V 01.00.34The inverse time element has a definite minimumtime of 30 cycles. Definite Time Element #1 isindependent, and has no effect on inverse timeelements.

M-3425A Firmware Version D-0150V 01.04.00The inverse time element has a definite minimumtime of 60 cycles. Definite Time Element #1 isindependent, and has no effect on inverse timeelements.

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Figure 2-15 Example of Capability and Protection Curves (24)


2–20

(24) - VOLTS/HZ

F24

Pickup:

Delay:

100%

30 Cycles

200%

8160 Cycles

FL 6 5 4 3 2 1Blocking InputsOUTPUTS

8 7 6 5 4 3 2 1

@

Def. Time #1

Expanded I/O’s

Pickup:

Delay:

100%

30 Cycles

200%

8160 Cycles


8 7 6 5 4 3 2 1

@

Def. Time #2

Inv. TimePickup:

Time Dial:

Reset Rate:

100% 200%

Curves: #1 #2 #3 #4

1

1 Sec

100

999 Secs


8 7 6 5 4 3 2 1

@

Expanded I/O’s

Expanded I/O’s


Save Cancel

X?

Figure 2-16 Volts-Per-Hertz (24) Setpoint Ranges

Application – 2

2–21

25 Sync Check■ NOTE: The 25 function cannot be enabled under

any one of the following conditions:• 67N (Residual Directional Overcurrent)

is enabled and the polarizing quantityhas been set to V

X.

• 59D is enabled and the line side voltageis set to V

X.

• 59X is connected for turn-to-turn faultprotection or bus ground protection.

The Synchronism (Sync) Check function (25) isused to ensure that the voltage magnitude, phaseangle and frequency of the generator (V1) and theutility system (V

X) are within acceptable limits before

the generator is synchronized with the system.Generator voltage (V1) can be selected as A, B, orC (line-to-ground and line-ground to line-line) or AB,BC, or CA (line-to-line).

The sync check function includes phase angle,delta frequency, and delta voltage checks.

Phase Angle CheckThe phase angle is considered acceptable when theselected sync phase voltage (V1) and systemvoltage (V

X) are within the Upper Volt Limit and

Lower Volt Limit window and the measured phaseangle is within the phase angle window.

Phase angle window is defined as twice the PhaseAngle Limit setting. For example, if the PhaseAngle Limit is set at 10 degrees, a phase anglewindow of 20 degrees exists between –10 degreesand +10 degrees. The logic diagram of the phaseangle check is shown in Figure 2-17.

Delta Voltage and Delta Frequency CheckDelta Voltage and Delta Frequency elements maybe individually enabled or disabled, as desired. TheDelta Voltage check will compare the absolutedifference between the selected sync phase voltage(V1) and the measured system voltage (VX) with theDelta Voltage Limit setting. Likewise, the DeltaFrequency measures the frequency differencebetween V1 and V

X voltage signals. The Phase

Angle Check, Delta Voltage and Delta FrequencyCheck all combine through an appropriate timer withthe output directed to the programmed 25S outputcontact. A logic diagram representing this logic ispresented in Figure 2-17.

Dead Line/Dead Bus CheckThe Dead Volt Limit defines the Hot/Dead voltagelevel used in Deadline/Dead Bus closing schemes.When the measured V

X voltage is equal to or below

the Dead Volt Limit, VX is considered dead. When

the measured VX is above the Dead Volt Limit, V

X is

considered hot. The opposite side of the breakeruses the positive sequence voltage measurement(V1) for 3-phase consideration in determining hot/dead detection. Different combinations of hot line/dead bus closings may be selected, depending onhow the buses are referenced. A logic diagram ofthe Deadline/Dead Bus scheme is presented inFigure 2-17.

The Dead V1, Dead VX, and Dead V1 & V

X enable

are software switches used to enable the dead line/dead bus logic. Further conditioning can be performedon the dead detection logic by selecting one ormore input contacts (Dead Input Enable) to controlthe enabled dead detection element. For example,if INPUT2 (I2) is selected under the Dead InputEnable screen, and both the Dead V1 and Dead V

Xelements are enabled, the dead check timer willstart when INPUT2 is activated, and either V1dead/V

X hot or V1 hot/V

X dead. This allows for

external control of the desired dead closing scheme.Dead Input Enable selections are common to alldead detection elements. If no inputs are selectedunder the Dead Input Enable screen, and any deadelement is enabled, the dead check timer will startimmediately when the dead condition exists.

The 25S and 25D can be programmed to be sent totwo different contacts, if desired.

■ NOTE: The 25 function does not produce a targetor LED and is accompanied by the HMImessage “F25 Function Operated”.


2–22

If this function is enabled, the following settings are applicable:

25S PHASE LIMITDegrees

25S UPPER VOLT LIMITVolts

25S LOWER VOLT LIMITVolts

25S SYNC CHECK DELAYCycles

25S DELTA VOLTdisable ENABLE

25S DELTA VOLT LIMITVolts

25S DELTA FREQUENCYdisable ENABLE

25S DELTA FREQ LIMITHz

25S SYNC-CHECK PHASEa b c

25D DEAD VOLT LIMITVolts

25D DEAD V1 HOT VXdisable ENABLE

25D DEAD VX HOT V1disable ENABLE

25D DEAD V1 & VXDISABLE enable

25D DEAD INPUT ENABLEi6 i5 i4 I3 i2 i1

25D DEAD DELAYCycles

Phase angle setting.

Upper voltage limit for voltage acceptance.

Lower voltage limit for voltage acceptance.

Sync check time delay.

Delta voltage element.

Delta voltage setting.

Delta frequency element.

Delta frequency setting.

Selects the phase voltage on the generator side for Sync Check func-tions (A, B, or C for line-to-ground and line-ground to line-line, and AB,BC, CA for line-to-line)

Voltage less than this setting is defined as “DEAD”; above this set-ting as “HOT”.

Enables Dead V1/Hot VX setting.

Enables Hot V1/Dead VX setting.

Enables Dead V1/Dead VX closing.

Externally controlled dead closing. Inputs IN7–IN14 must be set us-ing IPScom.

Dead delay timer setting.

Application – 2

2–23

Phase Angle Check Logic

Dead Line/ Dead Bus Check Logic

Dead Line/ Dead Bus Check Input Initiate Logic

Dead Input Enable

AND

ORAND

ANDAND

AND

AND

AND

AND

OR

OR

AND

AND AND

AND

AND

|V1 - V X| < Delta V Limit

Delta V Is Enabled

Delta F Is Enabled

V1 Lower Voltage Limit>

V1 Upper Voltage Limit<

VX Lower Voltage Limit>

VX Upper Voltage Limit<

Phase Angle Phase Limit<

|F1 - F X | < Delta F Limit

Phase Angle OK

AND

AND

|V1- VX| < Delta V Limit

Delta V Is Enabled

Delta F Is Enabled

|F 1 - FX | < Delta F Limit

With Delta V OR Delta F Enabled

With Delta V AND Delta F Enabled

V1pos Dead Limit<

Dead V1 Hot V X Enabled

VX > Dead Limit

Dead V X Hot V1 Enabled

V1pos Dead Limit<

VX < Dead Limit

VX < Dead Limit

Dead V1 V X Enabled

V1pos Dead Limit<

VX > Dead LimitDead V1 Hot V X Enabled

V1pos Dead Limit>

V1pos Dead Limit>

VX < Dead Limit AND

Dead V X Hot V1 Enabled

Selected INPUT Is Activated

AND

User Software Setting

Measured Variable

Delta V and Delta F Check Logic

Delta V and Delta F Check Logic

Only one Delta V and Delta F Check Scheme may be active at a time.

Only one Delta V and Delta F Check Scheme may be active at a time.

Sync Check TimerOutput Seal-in Timer

25SOutputContact

OR

Dead Check TimerOutput Seal-in Timer

25DOutputContact

Figure 2-17 Sync Check Logic Diagrams


2–24

@ : WARNING, you have not selected an output!

(25) - SYNC CHECK

Save

Dead V1 Hot VX Hot V1 Dead VX Dead V1 Dead VX

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

25DDead Voltage Limit: 0 V 60 V

Phase Angle Window:

Upper Voltage Limit:

Lower Voltage Limit:

Sync Check Delay:

0o

60 V

40 V

1 Cycle

90o

140 V

120 V

8160 Cycles

Cancel

FL 6 5 4 3 2 1

Dead Input Enable

Blocking Inputs

6 5 4 3 2 1

OUTPUTS8 7 6 5 4 3 2 1

Expanded I/P Initiate

Expanded I/Os

Expanded I/Os

25S Sync Check Phase

Phase AB Phase BC

Delta Voltage:

Enable Disable

Delta Frequency: 0.001 Hz 0.500 Hz

Enable Disable

1.0 V 50.0 V

25S

Dead Time Delay: 1 Cycle 8160 Cycles

F25

X?

Phase CA

Figure 2-18 Sync Check (25) Setpoint Ranges

Application – 2

2–25

27 Phase UndervoltageThe Phase Undervoltage function (27) may be usedto detect any condition causing long- or short-termundervoltage. This is a true three-phase function inthat each phase has an independent timing element.The ranges and increments are presented in Figure2-19.

Magnitude measurement depends on the 59/27Magnitude Select setting. (See Section 2.1,Configuration, Relay System Setup.) When the RMScalculation is selected, the magnitude calculation isaccurate over a wide frequency range (10 to 80 Hz)and the accuracy of the time delay is +20 cycles. IfDFT calculation is selected, the magnitudecalculation is accurate near 50 or 60 Hz, and thetimer accuracy is K1 cycle.

@ : WARNING,You have not selected an output!

(27) - PHASE UNDERVOLTAGE

Save Cancel

#2

#3

Expanded I/Os

Expanded I/Os

#1

Expanded I/Os

Pickup:

Delay:

5 V

1 Cycle

180 V

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Pickup:

Delay:

5 V

1 Cycle

180 V

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Pickup:

Delay:

5 V

1 Cycle

180 V

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

F27

X?

Figure 2-19 Phase Undervoltage (27) Setpoint Ranges

27 #2 and 27 #3 Screens are identical to 27 #1.27 #1 PICKUP_____________ Volts

27 #1 DELAY_____________ Cycles


2–26

27TN Third Harmonic Undervoltage, NeutralFor ground faults near the stator neutral, the ThirdHarmonic (180/150 Hz) Neutral undervoltagefunction (27TN) provides stator ground-faultprotection for high-impedance-grounded generatorapplications (See Figure 2-20). When used inconjunction with the fundamental neutralovervoltage (60/50Hz) function (59N), 100% statorground-fault protection can be provided. This isillustrated in Figure 2-20.

The 27TN function can be supervised by thepositive-sequence undervoltage element.Undervoltage supervision can prevent tripping whenthe generator field is not energized or the unit isnot yet synchronized.

In some generators, the third harmonic voltagecan be very low, especially during light loadconditions. It is also observed in some generatorinstallations that the third harmonic voltage isconsiderably reduced for a specific range of poweroutput (band). To prevent mis-operation duringthese conditions, the 27TN function can beprogrammed to be supervised (blocked) by lowforward power, low reverse power, low Vars (leadand lag), low power factor (lead/lag), and whenthe forward power is inside a band.

To properly handle pump storage operations, theM-3425A forward power blocking algorithm is enablefrom “zero per unit” to the forward power setpoint.During plant startup, after the field is flashed and

before the unit synchronized, small currentmeasurement errors cause the measured powerto fluctuate (typically <0.2%.) This may result ina measured power value that is negative (i.e.,–0.001 pu.) If the reverse power blocking is notenabled, the 27TN may be momentarily unblocked,resulting in a relay operation and nuisance generatortrip. It is highly recommended that if the ForwardPower Blocking is used, both the Forward PowerBlocking and Reverse Power Blocking be enabledand set.

In the majority of the cases, these blockingfunctions will be disabled, except for those operatingcases where the third harmonic neutral voltagemagnitude is less than 0.5 V. The settings forthe blocking functions should be set based onfield measurements. Blocking regions are illustratedin Figure 2-21.

The 27TN setting depends on the actual third-harmonic neutral voltage level seen during normaloperation of the generator. The setting should beabout 50% of the minimum third-harmonic voltageobserved during various loading conditions. Thiscan be most conveniently measured duringcommissioning of the relay. Since the relaymeasures the third harmonic voltage levels andwill display those values directly, no additionalequipment is required. The undervoltage inhibitsetting should be about 80% to 90% of the nominalvoltage. The ranges and increments are presentedin Figure 2-22.

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Application – 2

2–27

-P +P

Lag var Block

Lead var Block

ReversePowerBlock

ForwardPowerBlock

Low Band ForwardPower Block

High BandForward

Power Block

Block Block

+Q

-QFigure 2-21 27TN Blocking Regions


(27TN) - THIRD HARMONIC UNDERVOLTAGE, NEUTRAL

Pickup:

Pos. Seq. Voltage Block:

Forward Power Block:

Reverse Power Block:

Lead var Block:

Lag var Block:

Lead Power Factor Block:

Lag Power Factor Block:

Hi Band Forward Power Block:

Lo Band Forward Power Block:

Delay:

0.1 V

5 V

0.01 PU

-1.00 PU

-1.00 PU

0.01 PU

0.01 Lead

0.01 Lag

0.01 PU

0.01 PU

1 Cycle

14.00 V

180 V

1.00 PU

-0.01 PU

-0.01 PU

1.00 PU

1.00 Lead

1.00 Lag

1.00 PU

1.00 PU

8160 Cycles

#1

FL 6 5 4 3 2 1Blocking Inputs

Enable Disable

Enable Disable

Enable Disable

Enable Disable

Enable Disable

Enable Disable

Enable Disable

Enable Disable

OUTPUTS8 7 6 5 4 3 2 1

@ Expanded I/O’s

#1 #2

CancelSave

Figure 2-22 Third Harmonic Undervoltage, Neutral Circuit (27TN) Setpoint Ranges


2–28

27TN #2 Screens are identical to 27TN #1.Relay volts are equal to the primary neutral volt-age divided by the grounding transformer ratio. Gen-erally set for approximately 50% of the minimumthird harmonic voltage observed during various load-ing conditions.

27TN #1 PICKUP_____________ Volts

27TN #1 POS SEQ VOLT BLKdisable ENABLE

27TN #1 POS SEQ VOLT BLKVolts

27TN #1 FWD POWER BLKdisable ENABLE

27TN #1 FWD POWER BLKPU

27TH #1 REV POWER BLKdisable ENABLE

27TN #1 REV POWER BLKPU

27TN #1 LEAD VAR BLKdisable ENABLE

27TN #1 LEAD VAR BLKPU

27TN #1 LAG VAR BLKdisable ENABLE

27TN #1 LAG VAR BLKPU

27TN #1 LEAD PF BLKdisable enable

27TN #1 LEAD PF BLKLEAD

27TN #1 LAG PF BLKdisable enable

27TN #1 LAG PF BLKLAG

27TN #1 BAND FWD PWR BLKdisable enable

27TN#1 LO B FWD PWR BLKPU

27TN#1 HI B FWD PWR BLKPU

27TN #1 DELAYCycles

Application – 2

2–29

32 Directional PowerThe Directional Power function (32) can provideprotection against both generator motoring andoverload. It provides three power setpoints, eachwith a magnitude setting and a time delay. TheForward Power direction (power flow to system) isautomatically chosen when the pickup setting ispositive and the Reverse Power direction (powerflow to generator) is automatically chosen when thepickup setting is negative. The range, as shown isfrom –3.000 PU to 3.000 PU where 1.0 PU is equalto the generator MVA rating. Normalized PU powerflow measurements are based on Nominal Voltageand Nominal Current setting, as shown in Section2.1, Configuration, Relay System Setup.

Protection from Generator MotoringProtection against motoring is provided by selectinga negative pickup with Over/Under power set toOver. The relay will operate when the measured realpower is greater (more negative) than the pickupsetting in the reverse direction.

In some steam generator applications it is desirableto trip the generator when the forward power is lessthan a small value. This is due to the fact that thetrapped steam will cause the generator to supply asmall amount of power even though the steam

valves are closed. In this case the Over/Underpower setting is set to Under and a positive pickupsetting is chosen. The relay will trip when themeasured forward power is less than the pickupvalue. The function should be blocked when thegenerator breaker is open (using contact inputblocking) otherwise the function will trip and preventthe generator from being brought online.

Protection from Generator OverloadProtection from generator overload is provided byselecting a positive pickup setting with Over/UnderPower setting set to Over. The relay will operatewhen the measured real power is greater than thepickup setting.

Protection from Excessive Reactive PowerThe directional power element #3 can be set tooperate on either real power or reactive power.When protection from excessive reactive power isrequired the element #3 can be set to operate onreactive power. The relay will operate when themeasured reactive power exceeds the pickup setting.

Figures 2-23 through 2-26 show reverse power, lowforward power, over power, and over reactive powerapplications.

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Figure 2-23 Tripping on Reverse Power Flow (Over Power with Negative Pickup)


2–30

32 #1 PICKUP_______________ PU

32 #1 DELAY_____________ Cycles

32 #1 TARGET LEDdisable enable

32#1 UNDER/OVER POWERover under

32 #2 PICKUP_______________ PU

32 #2 DELAY_____________ Cycles



32 #3 PICKUP_______________ PU

32 #3 DELAY_____________ Cycles



32 #3 DIR POWER SENSINGreal reactive

The reverse power pickup setting should be based on the type ofprime mover and the losses when the generator is motoring.

Reverse power relays should always be applied with a time delayin order to prevent mis-operation during power swing conditions.Typical time delay settings are 20 to 30 seconds.

Target LED for the 32 Function elements can be individually enabledor disabled.

When Low Forward Power protection is desired, set this to Underwith a positive pickup setting. The relay will trip when the realpower measurement is less than or equal to the pickup setpoint.

If used, positive direction power settings can be used for overloadprotection, providing either alarm or tripping or both, when powerequals or exceeds the setting. The pickup and time delay settingsshould be based on the capability limit of the generator.

A second reverse power setting can be used for sequential trip-ping of the generator in which case the associated time delay willbe in the range of 2 to 3 seconds.

Directional Power Sensing for Element #3 can be selected as Realor Reactive.

Application – 2

2–31

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Figure 2-24 Tripping on Low Forward Power (Under Power with Positive Pickup)

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Figure 2-25 Tripping on Overpower (Over Power with Positive Pickup)


2–32

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Figure 2-26 Tripping on Over Reactive Power with Element #3 (Over Power, Positive Pickup andDirectional Power Sensing Set to Reactive)


(32) - DIRECTIONAL POWER

Expanded I/Os

#1

Overpower Underpower Target LED Enable

Pickup:

Delay:

-3.000 PU

1 Cycle

3.000 PU

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Save Cancel

F32

X?

Expanded I/Os

#2


Pickup:

Delay:

-3.000 PU

1 Cycle

3.000 PU

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Expanded I/Os

#3


Pickup:

Delay:

-3.000 PU

1 Cycle

3.000 PU

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Real ReactiveDirectional Power Sensing:

Figure 2-27 Directional Power, 3-Phase (32) Setpoint Ranges

Application – 2

2–33

40 Loss of FieldThe Loss-of-Field function (40) provides protectionfor a partial or complete loss of field. A variety ofpossible settings make the M-3425A GeneratorProtection Relay very flexible when applied to loss-of-field protection. Ranges and increments arepresented in Figure 2-30.

The loss-of-field function is implemented with twooffset mho elements, an undervoltage element, anda directional element. The setting for each mhoelement, diameter, offset, and time delay, areadjusted individually. Each element has two timedelay settings. The second time delay (delay withVC) is applicable with voltage control, and the timeronly starts if the positive sequence voltage is belowthe voltage control setting. The function with voltagecontrol and without voltage control can beprogrammed to send to two different output contacts,if desired. The delay with voltage control may beenabled on each element but the voltage levelsetting is common. The voltage control allows forfaster tripping when low voltage may be caused bythe VAr intake by the machine with loss of excitation.A common directional unit is provided to block therelay operation during slightly underexcitedconditions (since approach #1 with negative offsetis inherently directional, the directional element isnot required). The directional unit’s angle setting(QD) can be set from 0° to 20°.

The settings of the offset mho elements should besuch that the relay detects the loss-of-field conditionfor any loading while not mis-operating during powerswings and fault conditions. Two approaches arewidely used in the industry, both of which aresupported by the M-3425A relay. Both approachesrequire knowledge of the reactances and otherparameters of the generator. They are described inFigure 2-28, Loss of Field (40) — ProtectiveApproach I and Figure 2-29, Loss of Field (40) —Protective Approach II.

Positive sequence impedance measurements areused for the loss of field functions. All impedancesettings are secondary relay quantities and can bederived from the following formula:

Z SEC

= ZPRI

x (RC ÷ R

V)

where ZSEC

= secondary reflected impedance, ZPRI

=primary impedance, R

C = current transformer ratio,

and RV = voltage transformer ratio.

The first approach is shown in Figure 2-28, Loss ofField (40) — Protective Approach I. Here, both ofthe offset mho elements (#1 and #2) are set with anoffset of –Xl

d÷2, where Xl

d is the (unsaturated)

direct axis transient reactance of the generator. Thediameter of the smaller circle (#1) is set at 1.0 puimpedance on the machine base. This mho elementdetects loss-of-field from full load to about 30%load. A small time delay provides fast protection.

The diameter of the larger circle (#2) is set equal toX

d, where X

d is the (unsaturated) direct axis

synchronous reactance of the machine. This mhoelement can detect a loss-of-field condition fromalmost no load to full load. A time delay of 30 to 60cycles (#2) should be used in order to preventpossible incorrect operation on stable swings.

The time delay with voltage control is typically setshorter than the other time delay.

The second approach is shown in Figure 2-29,Loss of Field (40) – Protective Approach II. In thisapproach, one of the mho elements is set with anoffset of –Xl

d ÷ 2, a diameter of 1.1 X

d-(Xl

d ÷ 2), and

a time delay of 10 to 30 cycles. The second elementis set to coordinate with the generator minimumexcitation limit and steady-state stability limit.

In order to obtain proper coordination, the offset ofthis element must be adjusted to be positive.Typically, the offset is set equal to the unittransformer reactance (X

T). The diameter is

approximately equal to (1.1 Xd + XT). A time delayof 30 to 60 cycles would prevent mis-operation onstable swings.

The following table provides suggested time settingswhen time delay with VC is used in addition tostandard time delay.

Typical setting is 13° (0.974 power factor). Thissetting is common to both element #1 and #2.

Approach #1 can also be used for Zone #1, andapproach #2 for Zone #2, where better coordinationwith AVR limiters, machine capability limits, andsteady state stability limits can be obtained.


2–34

40 #1 DIAMETEROhms

40 #1 OFFSETOhms

40 #1 DELAYCycles

40VC #1 DELAY WITH VCCycles

40 #2 DIAMETEROhms

40 #2 OFFSETOhms

40 #2 DELAYCycles

40VC #2 DELAY WITH VCCycles

40 VOLTAGE CONTROLVolts

40 DIRECTIONAL ELEMENTDegrees

Zone 1Voltage Control

Setting

Delay

Delay with VC

N/A

15 Cycles

Disable

Zone 280 to 90% of

Nominal Voltage

3,600 Cycles

60 Cycles

Table 2-3 Voltage Control Time Settings

Application – 2

2–35

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2–36

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Figure 2-30 Loss-of-Field (40) Setpoint Ranges

■ NOTE: Out of Step Block Enable is not available for this release, and will appear greyed-out in display.

Application – 2

2–37

46 Negative Sequence OvercurrentThe Negative Sequence Overcurrent function (46)provides protection against possible rotoroverheating and damage due to unbalanced faultsor other system conditions which can causeunbalanced three phase currents in the generator.Ranges and increments are presented in Figure2-32.

This function has a definite time element and aninverse time element. The definite time pickup valueand definite operating time are normally associatedwith an alarm function. The inverse time element isusually associated with a trip function and has apickup and an operating time defined by an (I

2)2 t =

K, where K is the Time Dial Setting and I2 is the per

unit negative sequence current.

The minimum delay for the inverse time function isfactory set at 12 cycles to avoid nuisance tripping.A maximum time to trip can be set to reduce theoperating times for modest imbalances. An importantfeature that helps protect the generator from damagedue to recurring imbalances is a linear resetcharacteristic. When I

2 decreases below the pickup

value, the trip timer takes the reset time settingfrom its 100% trip level. Figure 2-31, Negative

Sequence Overcurrent Inverse Time Curves,illustrates the inverse time characteristic of thenegative sequence overcurrent function.

Operating times are lower than shown in Figure 2-31when measured current values are greater than 15A (3 A for 1 A rated circuit).

The first task of setting this function is to determinethe capabilities of the associated machine. Asestablished by ANSI standards, the machine limitsare expressed as (I

2)2t = K. The value of K is

established by the machine design and is generallyprovided on test sheets of the machine. The relaycan accommodate any generator size because ofthe wide range of K settings from 1 to 95. Typicalvalues can be found in ANSI C50.13-1977.

The negative sequence pickup range is from 3% to100% of the Nominal Current value input duringsystem setup (see Section 2.1, Configuration).

This protection must not operate for system faultsthat will be cleared by system relaying. This requiresconsideration of line protection, bus differential andbreaker failure backup protections.

The pickup setting is usually quite low (3–5%) and the output ofthis function is usually connected to alarm only.

Time delay should be set high enough to avoid alarms on tran-sients.

The 46 Inverse Time pickup setting should coincide with thecontinuous negative sequence current capability of the generatoroperating at full output.

The maximum trip time is used to reduce the longer trip timesassociated with low to moderate imbalances to a preset time.

Emulates generator cool down time.

The time dial setting corresponds to the K provided by the generatormanufacturer for the specific unit being protected. See Figure 2-31for the negative sequence overcurrent inverse time curves.

46DT PICKUP_______________ %

46DT DELAY_____________ Cycles

46IT PICKUP_______________ %

46IT MAX DELAY_____________ Cycles

46IT RESET TIME____________ Seconds

46IT TIME DIAL________________


2–38

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* 0.24 seconds for 50 Hz units.

Figure 2-31 Negative Sequence Overcurrent Inverse Time Curves

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Figure 2-32 Negative Sequence Overcurrent (46) Setpoint Ranges

Application – 2

2–39

49 Stator Overload ProtectionThe Stator Thermal Overload function (49) providesprotection against possible damage during overloadconditions. The characteristic curves are based onIEC-255-8 standard, and represent both cold andhot curves. The function uses the thermal timeconstant of the generator and stator maximumallowable continuous overload current (I

max) in

implementing the inverse time characteristic.

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Where: t = time to tripτ = thermal time constantIL = load current

IPL

= pre-load currentImax

= maximum allowed continuous overload current

Selects the time constant, ‘τ ’

Selects the maximum allowed continuous overload current.

49#2 Screens are identical to those for 49#1.

Example: If we consider that the generator wasloaded with 80% of its rating power prior to overload,then the current goes up to 2.0 times the maximumcurrent ((I

L/I

max)=2.0). Selecting the curve P=0.8

(see Figure 2-28), we have t/τ =0.1133. If τ =30minutes, then the time delay for this conditionwould be: t = 0.1133 x 30 = 3.3999 minutes.

The 49 function has two elements, one of which canbe used for trip and the other for alarm.

t

Current-Square

t

Tripped Not Tripped

Imax2

IL2

IL2

IL2

I2PL

I2PL

Figure 2-33 Time Constant, Function 49

49 #1 TIME CONSTANTMin

49#1 MAX OVERLOAD CURRAmps


2–40

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Figure 2-34 49 Function Overload Curves

Application – 2

2–41

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Figure 2-35 Stator Thermal Protection (49) Setpoint Ranges


2–42

50/50N Instantaneous Overcurrent, Phase andNeutral CircuitsThe Instantaneous Phase (50) and InstantaneousNeutral (50N) overcurrent functions provide fasttripping for high fault currents. The settings of bothfunctions must be set such that they will not pickupfor fault or conditions outside the immediateprotective zone. If the neutral current input isconnected to a step-up transformer’s neutral CT,the 50N function can be used as a breaker flashoverprotection when used in conjunction with externalbreaker failure protection. Ranges and Incrementsare presented in Figures 2-36 and 2-37. The functionautomatically selects fundamental RMS or totalRMS calculation based on the input frequency.When the generator frequency is within 5 Hz fromthe nominal frequency, it uses fundamental RMScalculation. Outside of this range, it uses total RMScalculation, which will provide protection duringoffline down to a frequency of 8 Hz.

For providing off-line protection, one of the elementscan be supervised by a breaker ‘b’ contact, and theelement blocked when the breaker is closed. Thisallows the function to be set sensitively (below fullload current).

The relay current (IR) is equal to the primary current (Ip) dividedby the appropriate CT ratio. These screens are repeated for 50#2element.

50#1 PICKUPAmps

50#1 DELAYCycles

50N PICKUPAmps

50N DELAYCycles

Application – 2

2–43

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Figure 2-37 Instantaneous Neutral Overcurrent (50N) Setpoint Ranges


2–44

Implementation of the generator breaker failurefunction is illustrated in Figure 2-38. The breakerfailure timer will be started whenever any one of thedesignated output contacts or the externalprogrammed breaker failure initiate status input areoperated. The timer continues to time if any one ofthe phase currents are above the 50BF-Ph pickupsetting or if the 52b contact indicates the breaker isstill closed; otherwise, the timer is reset.

Since current in the generator high side CT whichenergizes the 50BF protection (I

A, I

B, I

C) might not

extinguish concurrently with the breaker opening forfaults between the CT location and the generatorbreaker, a possible area of mis-operation exists.Usually the risk of faults in this limited area is smallenough to be ignored but should be considered.

50BF-Neutral Element: This instantaneousovercurrent relay is energized from the generatorneutral CT (See Figure 2-5, One-Line FunctionalDiagram). This function is internally in series with abreaker “b” contact (IN1) to provide logic for thebreaker flashover protection (see Figure 2-38).

HV Breaker Failure (limited) The breaker failurefunction may be used for a unit breaker rather thana generator breaker. It is limited in that it has nofault detector associated with the unit breaker. Outputcontact operation would occur if any of the initiatecontacts close and the 52b contact indicated aclosed breaker after the set time delay.

This operation is chosen by disabling the neutralelement, disabling the phase element, anddesignating initiating inputs and outputs and a timedelay setting.

50BF Generator Breaker Failure/HV BreakerFlashoverThe Generator Breaker Failure/HV Breaker Flashoverfunction (50BF) is applicable when a generatorbreaker is present and line side generator CTs arebeing used. The 50BF-Ph phase detector element(if enabled) is used for breaker failure and the50BF-N (if enabled) provides breaker flashoverprotection by providing an additional breaker failureinitiate which is only active when the breaker isopen. For high impedance grounded applications,the 50BF-N function is inapplicable and must bedisabled. Ranges and increments are presented inFigure 2-39.

50BF-Ph Generator Breaker Failure: When theM-3425A Generator Protection Relay detects aninternal fault or an abnormal operating condition, itcloses an output contact to trip the generator breakeror the unit HV breaker. When a generator breaker isused, protection is available for the instance whereit fails to clear the fault or abnormal condition. Suchgenerator breaker failure protection output contactsmust be connected to trip the additional necessarybreakers to isolate the generator from the system.

The breaker-failure condition is usually detected bythe continued presence of current in any one ormore of the phases after a trip has been sent to thebreaker. However, the current detector (50BF-Ph)may not always give the correct status of thebreaker, especially for generator breakers. This isbecause faults and abnormal operating conditionssuch as ground faults, overexcitation, over/underfrequency, and reverse power may not produceenough current to operate the current detectors. Forthis reason, the breaker status input 52b contactmust be used, in addition to the 50BF-Ph, to provideadequate breaker status indication.

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Figure 2-38 Breaker Failure Logic Diagram

Application – 2

2–45

50BF PHASE ELEMENTdisable enable

50BF PICKUP PHASEAmps

50BF NEUTRAL ELEMENTdisable enable

50BF PICKUP NEUTRALAmps

50BF INPUT INITIATE i6 i5 i4 i3 i2 i1

50BF OUTPUT INITIATEo8 o7 o6 o5 o4 o3 o2 o1

50BF DELAYCycles

If generator breaker failure function is used in this application,ENABLE here.

Set phase pickup amps.

If the breaker flashover protection is to be used with the generatorbreaker failure function of the relay, set ENABLE (enable phaseelement also for this application.)

Set the neutral pickup amps.

Designate the status inputs which will initiate the breaker failuretimer. Inputs IN7–IN14 must be set using IPScom®.

Designate the outputs that will initiate the breaker failure timer.Outputs OUT9–OUT23 must be set using IPScom.

For generator breaker failure protection, the time delay should beset to allow for breaker operating time plus margin.

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Figure 2-39 Breaker Failure (50BF) Setpoint Ranges


2–46

■ NOTE: When 50DT function is used for split-phase differential, 50BF, 87 and 87GDfunctions must be disabled.

Refer to Section 2.1, Configuration, Relay SystemSetup for a description of the 50DT Split-PhaseOperate setting, and Section 2.2, System Diagrams.

In some cases, the generators may be run with afaulted turn shorted until the generator winding isrepaired. To prevent mis-operation under theseconditions, the pickup setting of the faulted phaseshould be set higher than the other phases. Toaccommodate this function, individual pickupsettings are available for each phase. Ranges andincrements are presented in Figure 2-40

50DT Definite Time Overcurrent (for split-phasedifferential)The Definite Time Overcurrent (50DT) function canbe applied in two different configurations based onthe CT connections. When CT configuration shownin Figure 2-5, One Line Functional Diagram is used,the 50DT function is used as a definite time phaseovercurrent function to provide protection for externaland internal faults in the generator. When the CTsare connected to measure the split phase differentialcurrent (shown in Figure 2-6, Alternative One LineFunctional Diagram), the 50DT function can beused as a split-phase differential relay.

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Figure 2-40 Definite Time Overcurrent (50DT) Setpoint Ranges

50DT #1 PICKUP PHASE A______________ Amps

50DT #1 PICKUP PHASE B______________ Amps

50DT #1 PICKUP PHASE C______________ Amps

50DT #1 DELAY_____________ Cycles

50DT #2 screens are identical to 50DT #1.

Application – 2

2–47

50/27 Inadvertent EnergizingThe Inadvertent Energizing function (50/27) of therelay is an overcurrent function supervised bygenerator terminal bus voltage. Inadvertent oraccidental energizing of off-line generators hasoccurred frequently enough to warrant the use ofdedicated protection logic to detect this condition.Operating errors, breaker flashovers, control circuitmalfunctions or a combination of these causeshave resulted in generators being accidentallyenergized while off-line. The problem is particularlyprevalent on large generators connected through ahigh voltage disconnect switch to either a ring busor breaker-and-a-half bus configuration. When agenerator is accidentally energized from the powersystem, it will accelerate like an induction motor.

Typical pickup setting is 0.5 amps. No coordination is required withother protection since this function is only operational when thegenerator is off-line.

The purpose of the undervoltage detector is to determine whetherthe unit is connected to the system. The voltage level during thisaccidental energization depends on the system strength. Typicalsetting is 50%–70% of rated voltage (in some cases, it may be setas low as 20%.)

The pickup time delay is the time for the undervoltage unit tooperate to arm the protection. It must coordinate with other protectionfor conditions which cause low voltages (typically longer than 21and 51V time delay settings.)

The dropout time delay is the time for the unit to operate to disarmthe protection when the voltage is increased above the pickupvalue or the generator is brought on-line.

50/27 PICKUP______________ Amps

50/27 VOLTAGE CONTROL_____________ Volts

50/27 PICKUP DELAY_____________ Cycles

50/27 DROPOUT DELAY_____________ Cycles

While the machine is accelerating, high currentsinduced into the rotor can cause significant damagein a matter of seconds. Voltage supervisedovercurrent logic is designed to provide thisprotection. (See Figure 2-41, Inadvertent EnergizingFunction Logic Diagram)

An undervoltage element (all three phase voltagesmust be below pickup) with adjustable pickup anddropout time delay supervises instantaneousovercurrent tripping. The undervoltage detectorsautomatically arm the overcurrent tripping when thegenerator is taken off-line. This undervoltage detectorwill disable or disarm the overcurrent operationwhen the machine is put back in service. Rangesand increments are presented in Figure 2-42.


2–48

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Figure 2-41 Inadvertent Energizing Function Logic Diagram


(50/27) - INADVERTENT ENERGIZING

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

50/27Pickup:

Pickup:

Pick-up Delay:

Drop-out Delay:

5 V

1 Cycle

1 Cycle

130 V

8160 Cycles

8160 Cycles

(50) - OVERCURRENT

0.50 A 15.00 A

(27) - UNDERVOLTAGE

Expanded I/O’s

X?

Save Cancel

F50/27

Figure 2-42 Inadvertent Energizing (50/27) Setpoint Ranges

Application – 2

2–49

51N Inverse Time Neutral OvercurrentThe Inverse Time Neutral Overcurrent function (51N)provides protection against ground faults. Since nozero sequence or ground current is usually presentduring normal operation, this function can be set forgreater sensitivity than the phase overcurrentprotection. If the 51N and 50N functions are notused at the generator neutral, they can be used todetect system ground faults by being energized bythe step-up transformer neutral CTs. Ranges andincrements are presented in Figure 2-43.

The curves available for use are shown in AppendixD, Inverse Time Curves. They cover a range from1.5 to 20 times the pickup setting. An additional one

(51N) - INVERSE TIME NEUTRAL OVERCURRENT


Expanded I/O’s

X?

Save Cancel

#1Pickup:

Time Dial:

0.25 A

0.5

12.00 A

11.0

Curves

Beco Definite Time

IECI

IEEE Moderately Inverse

Beco Inverse

IECVI

IEEE Very Inverse

Beco Very Inverse

IECEI

IEEE Extremely Inverse

Beco Extremely Inverse

IECLTI

FL 6 5 4 3 2 1OUTPUTS

8 7 6 5 4 3 2 1Blocking Inputs@

F51N

Figure 2-43 Inverse Time Neutral Overcurrent (51N) Setpoint Ranges

The relay current (IR) is equal to the primary current (I

P) divided by

the appropriate CT ratio. IR = IP ÷ CT ratio

Select one of the time curves shown in Appendix D, Inverse TimeCurves. The appropriate curve in the selected family is designatedhere.

Appropriate Time Dial for coordination with “downstream” relayprotection chosen from the time curve above.

51N PICKUP______________ Amps

51N CURVEbedef beinv bevinv

51N TIME DIAL________________

cycle time delay should be added to these curves inorder to obtain the relay operating time. Inversetime curves saturate beyond 20 times pickup. Forcurrents in excess of 20 times pickup, operatingtimes are fixed at the 20 times pickup level.

The function automatically selects fundamental RMSor total RMS calculation based on the inputfrequency. When the generator frequency is within

5 Hz from the nominal frequency, it usesfundamental RMS calculation. Outside of this range,it uses total RMS calculation, which will provideprotection during offline down to a frequency of 8Hz.


2–50

The inverse time overcurrent function can be voltagecontrolled (VC), voltage restrained (VR), or neither.For voltage-controlled operation, the function is notactive unless the voltage is below the voltage controlsetpoint. This philosophy is used to confirm that theovercurrent is due to system fault. When applied,most users will set voltage control limits in therange of 0.7 to 0.9 per unit RMS voltage. Whenvoltage restraint is selected (See Figure 2-44,Voltage Restraint (51VR) Characteristic), the pickupsetting is continuously modified in proportion to thecollapsing terminal voltage. The voltage restraintfunction is well-suited to small generators withrelatively short time constants.

■ NOTE: The 51V function should be blocked byfuse loss if in the voltage control modeonly. Fuse loss blocking is not desirablefor voltage restraint mode because thepickup is automatically held at 100%pickup during fuse loss conditions, andoperation will continue as normal.

The internally derived voltage used to realize thevoltage control or restraint feature depends on theconfigured VT configuration and the Delta-YTransform setting (see Section 2.1, Configuration,Relay System Setup). Table 2-4, Delta/WyeTransformer Voltage-Current Pairs describes thecalculation for the various system VT configurations.

51V Inverse Time Phase Overcurrent withVoltage Control/RestraintTime-overcurrent relays, one per phase, are used totrip circuits selectively and to time-coordinate withother up- or downstream relays. For this function,eight complete series of inverse time trippingcharacteristics are included. The same descriptionsand nomenclature which are traditionally used withelectromechanical relays are used in the relay. Thus,user may choose from four BECO curves (BEDEF,BEINV, BEVINV, and BEEINV), four IEC curves(IECI, IECVI, IECEI, and IECLT), and three IEEEcurves (MINV, VINV, EINV.) Within each family, theoperator selects time dial setting and pickup (tap)setting, just as with electromechanical relays. Rangesand increments are presented in Figure 2-45.

The curves available for use are shown in AppendixD, Inverse Time Curves. They cover a range from1.5 to 20 times the pickup setting. An additional onecycle time delay should be added to these curves inorder to obtain the relay operating time. Inversetime curves saturate beyond 20 times pickup. Forcurrents in excess of 20 times pickup, operatingtimes are fixed at the 20 time pickup level. Theparticular settings will be made by information fromshort-circuit fault studies and knowledge of thecoordination requirements with other devices in thesystem that respond to time overcurrent.

51V is a true three-phase function, in that the relayincorporates separate integrating timers on eachphase.

The pickup of the 51V is set in relay amps.(Relay amps = primary amps ÷ CT ratio)

Selects one of the time curves as shown in Appendix D, InverseTime Curves. The appropriate curve in the selected family ofcurves is designated here.

Disable if neither voltage control nor voltage restraint is desired. Ifvoltage restraint is designated, the tap setting is modified asshown in Figure 2-43. If voltage control is designated, the 51V willonly operate when the voltage is less than the 51V voltage controlsetting specified below. When applied, the voltage control is usuallyset in the range of 70% to 90% of the nominal voltage.

51V PICKUPAmps

51V CURVEbedef beinv bevinv

51V TIME DIAL________________

51V VOLTAGE CONTROLdisable V_CNTL v_rstrnt

51V VOLTAGE CONTROLVolts

Application – 2

2–51

50

25 50 75 100

75

25

Input Voltage (% of rated voltage)0

100

Tap Setting as %of Tap Setting atRated Voltage

Figure 2-44 Voltage Restraint (51VR) Characteristic

Generator Directly ConnectedGenerator Connected Through

Delta AB/Wye or Delta AC/Wye Transformer

CurrentVoltage Control or Restraint

CurrentVoltage Control or Restraint

L-G L-L or L-G to L-L L-G L-L or L-G to L-L

Ia

(VA V

C)/S3 V

ABI

aV

A(V

AB V

CA)/S3

Ib

(VB V

A)/S3 V

BCI

bV

B(V

BC V

AB)/S3

Ic

(VC V

B)/S3 V

CAI

cV

C(V

CA V

BC)/S3

Table 2-4 Delta/Wye Transformer Voltage-Current Pairs


(51V) - INVERSE TIME OVERCURRENT WITH VOLTAGE CONTROL OR VOLTAGE RESTRAINT

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

0.50 A

0.5

12.00 A

11.0

Pickup:

Time Dial:

#1

Expanded I/O’s

X?

Save Cancel

F51V

Curves

Beco Definite Time

IECI

IEEE Moderately Inverse

Beco Inverse

IECVI

IEEE Very Inverse

Beco Very Inverse

IECEI

IEEE Extremely Inverse

Beco Extremely Inverse

IECLTI

Voltage Control: 5 V 180 V

Disable Voltage Control Voltage Restraint

Figure 2-45 Inverse Time Overcurrent with VoltageControl/Voltage Restraint (51VC/VR) Setpoint Ranges


2–52

59 Phase OvervoltageThe Phase Overvoltage function (59) may be usedto provide overvoltage protection for the generator.The relay provides overvoltage protection functionswith three voltage levels and three definite-timesetpoints, any one or more of which can beprogrammed to trip the unit or send an alarm. Thisis a true 3-phase function in that each phase has anindependent timing element.

The 59 function can be programmed to use phasevoltage (any one of the three phases) or positivesequence voltage as input.

Magnitude measurement depends on the 59/27Magnitude Select setting (See Section 2.1,Configuration, Relay System Setup). When the RMSoption is selected, the magnitude calculation isaccurate over a wide frequency range (10 to 80 Hz)and the accuracy of the time delay is +20 cycles. IfDFT option is selected, the magnitude calculationis accurate near 50 or 60 Hz, and the timer accuracyis K1 cycle. When the input voltage select is set topositive sequence voltage, the 59 functions usesDFT to measure the positive sequence voltage,irrespective of DFT/RMS selection. Ranges andincrements are presented in Figure 2-46.

@ : WARNING, Function DISABLED until output selected!

(59) - PHASE OVERVOLTAGE

#3

#1

#2

Input Voltage Select: Phase Voltage Positive Sequence Voltage

Pickup:

Delay:

5 V

1 Cycle

180 V

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@


Pickup:

Delay:

5 V

1 Cycle

180 V

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@


Expanded I/O’s

X?

Expanded I/O’s

Expanded I/O’sOUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

F59

Pickup:

Delay:

5 V

1 Cycle

180 V

8160 Cycles

Save Cancel

Figure 2-46 Phase Overvoltage (59) Setpoint Ranges

Generator capability is generally 105% of rated voltage.59 #2 and 59 #3 screens are identical to 59 #1.

59 #1 INPUT VOLTAGE SEL.phase_volt pos_seq_volt

59 #1 PICKUP_____________ Volts

59 #1 DELAY_____________ Cycles

Application – 2

2–53

59D Third Harmonic Voltage Differential (Ratio)This scheme, when used in conjunction with 59Nfunction may provide 100% Stator Ground faultprotection.

Figure 2-47 illustrates a third harmonic voltagedifferential scheme. This scheme compares thethird harmonic voltage appearing at the neutral tothat which appears at the generator terminals. Theratio of these third harmonic voltages is relativelyconstant for all load conditions. A stator phase-to-ground fault will disrupt this balance, causingoperation of the differential relay (see Figure 2-20).The generator terminal voltage (Line Side Voltage)can be selected as 3V

0 (Calculated by the relay

from VA, V

B and V

C) or V

X (broken delta VT input

connected at the VX input.) Positive sequence

undervoltage blocking will prevent the function frommisoperating when the generator is offline (theterminal voltage is below the set value).

59D RATIO________________

The ratio (or third harmonic) voltage measured at the generatorterminals to the third harmonic voltage measured at neutral.

The 59D Ratio Pickup Setting can be calculated using fieldmeasurement of Third Harmonic Voltages as follows:

This setting is typically enabled.

Where:

is the minimum measured Ratio of the Third Harmonic Voltages atvarious loading conditions of the generator.

Selection of VX will give better accuracy and sensitivity than 3V

0. If

3V0 is selected, VT configuration must be set to Line-Ground. If thenominal third harmonic voltage is <1 V, 3V0 line side voltageselection is not recommended, because noise in the 3V

0 and V

Ncan cause 59D misoperation.

59D POS SEQ VOLT BLKdisable ENABLE

59D POS SEQ VOLT BLK_____________ Volts

59D DELAY_____________ Cycles

59D Ratio PickupV

3XM

V3NM

3VOM

V3NM

OR( () )= 1.5 x

59D LINE SIDE VOLTAGE3v0 VX

V3XM

V3NM

3VOM

V3NM

OR( ( ))


2–54

V3N V3X

M-3425A

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Figure 2-48 Third Harmonic Voltage Differential (59D) Setpoint Ranges

The ratioV

3X

V3N

3Vo

V3N

PickupOR >( () )Where: V

3x is the Third Harmonic Triple Zero Sequence voltage measured at the generator

terminals.

V3N is the Third Harmonic voltage measure at the neutral.

Figure 2-47 Third Harmonic Voltage Differential (Ratio) Schemefor Generator Ground Fault Protection

Application – 2

2–55

59N Overvoltage, Neutral Circuit or ZeroSequenceThe Neutral Overvoltage function (59N) providesstator ground fault protection for high impedancegrounded generators. The 59N function can provideground fault protection for 90–95% of the statorwinding (measured from the terminal end).

@ : WARNING,You have not selected an output!

(59N) - NEUTRAL OVERVOLTAGE

Pickup:

Delay:

5.0 V

1 Cycle

180.0 V

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Pickup:

Delay:

5.0 V

1 Cycle

180.0 V

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

#3

Expanded I/O’s

#2

Expanded I/O’s

Pickup:

Delay:

5.0 V

1 Cycle

180.0 V

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

#1

X?

59N

Expanded I/O’s

Save Cancel

20 Hz Injection Mode: o Enable o Disable

Figure 2-49 Overvoltage, Neutral Circuit or Zero Sequence (59N) Setpoint Ranges

59N #1 PICKUPVolts

59N #1 DELAYCycles

59N 20HZ INJECTION MODEdisable ENABLE

59N #2 and 59N #3 screensare identical to 59N #1.

With typical grounding transformer ratios and a typical minimum setting of5 volts, this protection is capable of detecting ground faults in about 95% ofthe generator stator winding from the terminal end.

If grounded-wye/grounded-wye VTs are connected at the machine terminals,the voltage relay must be time coordinated with VT fuses for faults on thetransformer secondary winding. If relay time delay for coordination is notacceptable, the coordination problem can be alleviated by grounding one of thesecondary phase conductors instead of the secondary neutral. When thistechnique is used, the coordination problem still exists for ground faults on thesecondary neutral conductor. Thus, its usefulness is limited to those applicationswhere the exposure to ground faults on the secondary neutral is small.

Since system ground faults can induce zero sequence voltages at thegenerator due to transformer capacitance coupling, this relay mustcoordinate with the system ground fault relaying. It is possible to set59N#1, 59N#2, and 59N#3 to coordinate with the PT secondary fuses, andalso coordinate with worst case capacitive coupling interference voltagefrom system ground faults (high side of the GSU).

For applications where the M-3425A relay (where the 64S function ispurchased or not) is used with 100% Stator Ground protection with 20 Hzinjection schemes, the 59N 20 Hz injection mode must be enabled in orderto calculate the voltage magnitude accurately for the 59N function, due tothe 20 Hz injection voltage. The time delay accuracy of the function is –1 to+5 cycles when the 20 Hz injection mode is enabled.

The 59N function provides three setpoints, andresponds only to the fundamental frequencycomponent, rejecting all other harmonic components.Ranges and increments are presented in Figure 2-50.


2–56

59X Multipurpose Overvoltage (Turn-to-TurnStator Fault Protection or Bus GroundProtection)For generators where the stator-winding configurationdoes not allow the application of split-phasedifferential, a neutral voltage method can be used todetect turn-to-turn stator winding faults. Figure 2-50illustrates this method. Three VTs are connected inwye and the primary ground lead is tied to thegenerator neutral. The secondary is connected in a“broken delta” with an overvoltage relay connectedacross its open delta to measure 3V

0 voltage. In

High Impedance grounded generators, connectingthe primary ground lead to the generator neutral,makes this element insensitive to stator groundfaults. The relay will, however, operate for turn-to-turn faults, which increase the 3V

0 voltage above

low normal levels. Installation requires the cablefrom the neutral of the VT to generator neutral beinsulated for the system line-to-ground voltage andthe relay to be tuned to fundamental (60/50 Hz)frequency components of the voltage since somethird-harmonic frequency component of the voltagewill be present across the broken delta VT input.

Alternatively, this function can be used to detectbus ground faults, when connected as shown inFigure 2-10.

When used for Turn-to-Turn fault protection the pickup should beset above the normal zero sequence voltage level. Typically thepickup is set to 5 V.

When used for Bus Ground protection it is again set above thenormal zero sequence voltage seen at the bus. Typical setting isbetween 10 and 20 Volts to provide sensitive protection.

The Time Delay for Turn-to-Turn faults should be set to approximately5 cycles. For bus ground fault protection application the time delayshould coordinate with other ground fault relaying and VT fuses.

59X #2 screens are identical to 59X #1.

59X #1 PICKUP_____________ Volts

59X #1 DELAY_____________ Cycles

Application – 2

2–57

59X

R

3V0

VT

R

GENERATOR

See Note Below

■ NOTE: Installation requires the cable from the neutral of the VT to generator neutral be insulated for thesystem line-to-ground voltage.

Figure 2-50 Turn-to-Turn Stator Winding Fault Protection

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Figure 2-51 (59X) Multi-purpose Overvoltage Setpoint Ranges


2–58

A frequency check element is included in the fuseloss detection logic to avoid erroneous alarms whenthe generator is in a start up condition. For a 50Hzsystem, the 60FL alarm will be inhibited if themeasured frequency is greater than 55.12 Hz F

U or

less than 44.88 Hz FL. For a 60 Hz system, the 60FL

alarm will be inhibited if the measured frequency isgreater than 65.12 Hz F

U or less than 54.88 Hz F

L.

External Fuse-Loss FunctionFor the specific application where the precedinglogic cannot be considered reliable (such as whencurrent inputs to the relay are not connected, orsustained positive sequence current during faultconditions is minimal), an external fuse failurefunction can be used as an input to the relay. Theexternal 60 FL Function contact is connected acrossany control/status input. The relay protectionfunctions are then blocked by an assertion of thecontrol/status input (INx), as a blocking function ineach function’s respective setting screen.

60FL VT Fuse Loss Alarm FunctionThe 60FL alarm function is enabled by the internallogic by selecting the “FL” option in the 60 FLfunction setup screen. It is enable by the externallogic by selecting the appropriate control/statusinput (INx) in the 60FL function setup screen.

A timer associated with the fuse loss alarm logic isavailable. This timer is to assure proper coordinationfor conditions that may appear as a fuse loss, suchas secondary VT circuit faults that will be clearedby local low voltage circuit action (fuses or circuitbreakers). Ranges and increments are presented inFigure 2-53.

60FL VT Fuse LossSome functions may operate inadvertently when aVT fuse is blown or an event causes a loss of one,two, or all three potentials to the relay. Provisionsare incorporated for both internal and externalpotential loss detection and blocking of user definedfunctions. The logic scheme and options areillustrated in Figure 2-52.

Internal Fuse Loss Detection LogicThe internal logic scheme available will detect aloss of one, two, and all three potentials.

For the loss of one or two potentials, positive andnegative sequence quantities are compared. Thepresence of negative sequence voltage in the absenceof negative sequence current is considered to be afuse loss condition. An additional supervising conditionincludes a minimum positive sequence voltage toassure voltage is being applied to the relay.

For the loss of all three phase potentials, acomparison of the three phase voltages is made tothe three phase currents. If all three potentials areunder 0.05 V

nom, and all three currents are below

1.25 Inom

combined with I1 > 0.33A, a three phase

potential loss is declared. A seal in circuit is providedto ensure a three phase fuse loss condition is notdeclared during a three phase fault if the faultcurrent decays below the 1.25 Inom pickup setting.

Protection functions in the relay may be blocked byan assertion of the fuse failure logic (FL), in eachfunction’s respective setting screen. Typicalfunctions to block on a loss of potential event are21, 27, 32, 40, 51V (for Voltage Control only), 67,67N, 78 and 81.

The 60FL function does not have to be enabled inorder to use the FL as a blocking input in the relayconfiguration menu.

The initiating control/status inputs are user-designated. The closingof any of the externally connected contacts (across these in-puts) will start the associated time delay to the 60FL functionoperation. In order to use internal fuse loss logic for 60FL func-tion, “FL” must be checked. Externally initiated fuse loss detec-tion may be input to other status inputs. Inputs IN7–IN14 mustbe set using IPScom®.

The time delay is set to coordinate for conditions which mayappear as a fuse loss but will be corrected by other protection(such as a secondary VT circuit fault which will be cleared bylocal low voltage circuit action). This delay does not affect inter-nal FL blocking option.

60FL INPUT INITIATEFL i6 i5 i4 i3 i2 i1

60FL 3 PHASE DETECTdisable enable

60FL DELAYCycles

Application – 2

2–59

V1

> 12

.8 V

V2

> 0.

33 V

1

I 2 >

0.16

7 I 1

I 1 >

0.33

A

I A >

1.2

5 I N

I B >

1.2

5 I N

I C >

1.2

5 I N

VA

< 0

.05

VN

VB

< 0

.05

VN

VC

< 0

.05

VN

So

ftw

are

Sel

ect

En

able

/Dis

able

3 P

has

e F

use

Lo

ss D

etec

tio

n

Ena

ble

Dis

able

OR

OR

OR

AN

D

AN

D

AN

D

OR

AN

D

AN

D

F <

FU

F >

FL

AN

D

AN

D

Inte

rnal

60F

L L

og

ic:

3 P

has

e L

oss

of

Po

ten

tial

Inte

rnal

60F

L L

og

ic:

1 &

2 P

has

e L

oss

of

Po

ten

tial

Fre

qu

ency

Ch

ecki

ng

I 1V

erif

ies

On

-Lin

e co

nd

itio

nV

A,B

,CIn

dic

atio

n o

f 3-

ph

ase

loss

of

po

I A,B

,CP

reve

nts

op

erat

ion

du

rin

g f

ault

s

Sea

l-in

cir

cuit

en

sure

s lo

gic

do

esn

't p

roan

ou

tpu

t d

uri

ng

3-p

has

e fa

ult

wh

en c

ur

dec

ays

bel

ow

1.2

5 I N

(.06

7 A

)**

Val

ues

in p

aren

thes

es a

pp

lyto

a 1

A C

T s

eco

nd

ary

rati

ng

.

Ext

erna

l "F

L"F

unct

ion

INx

Ext

ern

al F

use

Lo

ss F

un

ctio

n

T Del

ay

60F

L A

larm

Fu

nct

ion

init

iate

by

inte

rnal

"F

L"

or

Sta

tus

Inp

ut

Co

nta

ct IN

x

Pro

tect

ion

Fu

nct

ion

Blo

ckS

ign

al b

y IN

x fr

om

Ext

ern

al F

L

60F

L A

larm

Sig

nal

Pro

tect

ion

Fu

nct

ion

Blo

ckS

ign

al b

y In

tern

al F

L L

og

icF

L

V1

Ver

ifie

s V

T v

olt

age

is a

pp

lied

.

V2

Pro

vid

es in

dic

atio

n o

f b

low

n f

use

.

I 2P

reve

nts

op

erat

ion

du

rin

g p

has

e-p

has

e fa

ult

s.

I 1P

reve

nts

ou

tpu

t co

nta

cts

fro

m c

hat

teri

ng

wh

ere

a

fuse

blo

ws

du

rin

g n

o lo

ad o

per

atio

n.

Figure 2-52 Fuse Loss (60FL) Function Logic


2–60

��

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'$#0$#%1 2 � * + , - .

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Figure 2-53 Fuse Loss (60FL) Setpoint Ranges

Application – 2

2–61

64B/F Field Ground Protection64F Field Ground DetectionTypical connections for Field Ground Protectionapplications (including hydro turbine-generator andbrushless generators) is given in Figure 2-54. Thisfunction requires the connection of an externalcoupler (M-3921). To improve accuracy andminimize the effects of stray capacitance, theM-3921 Field Ground Coupler should be mountedclose to the exciter. Connections from the couplerto the relay should use low capacitance shieldedcable, and be as short as possible. Cable shieldshould be terminated at the relay end to the RelayGround Stud (See Figure 5-9, External Connections).If cabling between the coupler and relay exceeds100 feet, provisions should be made for in circuitcalibration to nullify the effects of cablingcapacitance. See Section 6.4, Auto Calibration, forcalibration procedure.

The Field Ground function provides detection ofinsulation breakdown between the excitation fieldwinding and the ground. There are two pickup andtime delay settings, and one adjustable injectionfrequency setting for the 64F function. The adjustablefrequency is provided to compensate for the amountof capacitance across the field winding and theground so that the function accuracy is improved.The minimum time delay should be set greater than(2/IF + 1) seconds. Where IF = Injection frequency.Ranges and increments are presented in Figure 2-55.

64F #1 PICKUPkOhm

64F #1 DELAYCycles

64F #2 PICKUPkOhm

64F #2 DELAYCycles

Table 2-5 gives typical frequency settings based onthe rotor capacitance. The rotor capacitance can bemeasured with a capacitance meter by connectingthe meter across the field winding to ground.

Factors Affecting 64F PerformanceSome excitation systems include shaft voltagesuppressors which include capacitors that areinstalled between the +/- field and ground. The effectof these capacitors is given by the following equation:

R JJJJJ___1___ (2π IF C)

where:R = Parallel winding-ground resitance

IF = Injection frequency setting

C = Capacitance value

To minimize this effect the following my beimplemented:

• The injection frequency setting can bereduced, however accuracy decreasesas a result.

• With the concurrence of the excitermanufacturer, surge capacitors rated ata lower value may be installed.

This setting should not exceed 80% of the ungrounded resitance valueto prevent nuisance tripping. Typical setting for the 64F #1 pickupelement for alarming is 20 Kohms.

Typical delay setting for tripping is 800 cycles.

Typical setting for 64F #2 pickup element for tripping is 5 Kohms.

Typical delay setting for alarming is 180 cycles.


2–62

PROCESSOR

PROTECTION RELAYM-3425A

SquarewaveGenerator

SignalMeasurement and

Processing

Field GroundDetection

37

35

36

Relay Ground Stud

CouplingNetworkM-3921

TB5

TB4

TB1

Vf

Shield

TB3

TB2

TB1

Vout

Rear TerminalBlock Pin No.

Gen.Rotor

ExcitationSystem

Rf.CfShaft

GroundBrush

Brushes

Ground/Generator Frame

Typical Field Ground Protection

TB3

TB2

TB1

Gen.Rotor

Rf.CfShaft

GroundBrush

MeasurementBrush


Jumper TB2 to TB3 ifonly one brush is used

Brushless Generator Application

64F Application for Brushless Generators

The 64F Function can be implemented on brushlessgenerators that employ a "measurement" brush (seeFigure 2-54 Detail C) to verify the integrity of field. In thisconfiguration generally only one field polarity is available.Therefore, a suitably sized jumper must be installed fromTB2 to TB3 (Coupling Network box M-2931) and then tothe positive or negative field lead.

In some configurations the measurement brush iscontinuously applied. In others the measurement brush isapplied periodically. In configurations that automatically liftthe measurement brush, the 64B Function must beblocked by an input to the relay to prevent an alarm whenthe measurement brush is lifted. If the 64B Function is notdesired, then the 64B Function should be disabled.

The 64F Function can not be used on brushlessgenerators utilizing LED coupling.

Detail A

TB3

TB2

TB1

Gen.Rotor

ExcitationSystem

Rf.Cf

Water providesalternate

ground path.

Brushes


Francis or Kaplan Turbine-GeneratorApplication

64F Application for Hydro Turbine-Generators

The application of the 64F Function requires a groundreturn path, either through a shaft ground brush (Figure2-54 Detail A) or though an alternate ground path (i.e.water for some hydro machines.)

Hydro Turbine-Generator unit shafts that extend into thewater with no electrical isolation between the turbine shaftand the generator shaft can use the water as the alternateground path (see Figure 2-54 Detail B). In this application,the water provides the alternate ground path and a shaftgrounding brush is not required. Francis and KaplanTurbine Generators usually meet this applicationrequirement.

A shaft ground brush must be utilized for the 64F Functionon Pelton Hydro Turbine-Generator applications.

Detail B

Detail C

Figure 2-54 M-3921 Field Ground Coupler

Application – 2

2–63

64B Brush Lift-Off DetectionBrush Lift-Off Detection (64B) provides detection ofopen brushes of the rotor shaft. This function worksin conjunction with the 64F Field Ground Detectionfunction, and requires the M-3921 Field GroundCoupler.

88888 WARNING: Machine should be off-line andfield excitation should be off during thecapacitance measurement.

■ NOTE: Field breaker should be closed for thecapacitance measurements.

otgnidniWdleiFecnaticapaCdnuorG gnitteSycneuqerFlacipyT

1 2ot μF zH25.0

3ot2 μF zH94.0

4ot3 μF zH64.0

5ot4 μF zH34.0

5 6ot μF zH93.0

7ot6 μF zH53.0

8ot7 μF zH23.0

9ot8 μF zH03.0

01ot9 μF zH82.0

01> μF zH62.0

Table 2-5 Typical Frequency Settings

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Figure 2-55 Field Ground Protection (64B/F) Setpoint Ranges


2–64

When 64B operates, indicating open brushconditions, the 64F Function cannot detect a fieldground. For most generators, when the brushes ofthe rotor shaft are lifted, the capacitance across thefield winding and the ground significantly reduces toless than 0.15 μF. The 64B Function analyzes thiscapacitance-related signal, and initiates an outputcontact when it detects an open brush condition.Typically, this output is used to alert operatingpersonnel of an open brush condition. Ranges andincrements are presented in Figure 2-58. The typicalpickup setting is listed in Table 2-6, Typical BrushLift-Off Pickup Settings.

In order to assure correct setting, it is recommendedthat the actual operating value be predeterminedduring the final stage of the relay installation. Byintroducing a brush-open condition, the actual valuecan be easily obtained from the relay. The followingprocedure can be used to obtain the actual operatingvalue of the 64B during an open brush condition:

88888 WARNING: Machine should be off-line andfield excitation should be off during thecapacitance measurement.

■ NOTE: Field breaker should be closed for thecapacitance measurements.

64B PICKUP_______________ mV

64B DELAY_____________ cycles

64B/F FREQUENCY_______________ Hz

1. After installation has been completed,determine the rotor capacitance, asoutlined for the 64F function.

2. With the machine still off-line, applypower to the relay and set the 64B/Foperating frequency in accordance withthe value listed in Table 2-5, TypicalFrequency Settings.

3. Introduce a brush-open condition bydisconnecting the rotor brushes or liftingthe brushes from their ground. Observethe 64B voltage value displayed byIPScom or the relay. The displayed valueis the actual measured operating valueof the 64B function.

4. To ensure correct operation and preventerroneous trips, the Pickup Setting forthe 64B Lift-off condition should be setat 80–90% of the actual operating value.

The 64B/F Frequency is a shared setting common to both the 64Band 64F Functions. If either function is enabled, this setpoint isavailable, and should be set to compensate for the amount ofcapacitance across the field winding and ground, so that themeasurement accuracy is improved.

To minimize measurement errors, the 64B/F frequency shouldbe set according to the amount of capacitance across the fieldwinding and the ground. Table 2-5 includes typical settings of thefrequency for capacitance, ranging from 1 μF to 10 μF.

ecnaticapaCffO-tfiLhsurBtnelaviuqE ffO-tfiLhsurBlacipyTgnitteSpukciP

52.0~50.0 μF Vm0052

Table 2-6 Typical Brush Lift-Off Pickup Setting

Application – 2

2–65

The expected 20 Hz current during no fault conditionis given by:

V20

• N2

INF

=X

CS

Where V20 is the 20 Hz voltage measured acrossthe load resistor RL and X

CS is the capacitive

reactance of the gnereator stator winding and unittransformer referred to the grounding transformersecondary. N is the turn ratio of the groundedtransformer. The pickup setting should be based onthe required insulation resistance setting. In orderto detect a fault of 5,000 Ohms on the generatorstator, the pickup current should be set at:

��%�7+��@

�

��NA��

��-.��$��

When the generator is operating normally (no groundfault) only a small amount of 20 Hz current will flowas a result of the stator capacitance to ground.When a ground fault occurs anywhere on thegenerator stator windings the 20 Hz current willincrease. The 64S function will issue a trip signalafter a set time delay when the measured 20 Hzcurrent exceeds the pickup current as illustrated inFigure 2-57.

The 64S protection can be blocked by UndervoltageInhibit. If the 20 Hz voltage (nominal 25 V) is lessthan the Undervoltage Inhibit setting (andUndervoltage Inhibit is enabled), the 64S functionwill be blocked. For cases where the Load Resistor(RL) is small, the Undervoltage Inhibit should not beenabled, as the voltage will be small.

The 59N function (90 to 95%) should also be usedin conjunction with 64S protection to provide backup.

▲ CAUTION: Dangerous high voltages may bepresent at the generator terminals if the 20 Hzinjection voltage is not removed when the generatoris taken out of service.

If the 20 Hz injection voltage generator receivespower from the generator terminal voltage, then the20 Hz injection voltage generator will be automaticallyswitched off whenever the generator terminal voltageis not present.

64S 100% Stator Ground Protection by LowFrequency Signal Injection■ NOTE: The Stator Ground Protection function

(64S) must be selected when theM-3425A is initially ordered.

The 100% stator ground fault protection is providedby injecting an external 20 Hz signal into the neutralof the generator. The protection is provided whenthe machine is on-line as well as off-line (providedthat the 20 Hz generator and relay are powered on.)This scheme requires the following externalcomponents in addition to M-3425A protectionsystem:

• 20 Hz Signal-generator (BECO Part No.430-00426) (Siemens 7XT33)

• Band-pass filter. (BECO Part No.430-00427) (Siemens 7XT34)

• 20 Hz Measuring Current Transformer, 400/5 A CT (BECO Part No. 430-00428)(ITI CTW3-60-T50--401)

■ NOTE: Chapter 5, Installation contains lowfrequency signal injection equipmentinstallation information.

The voltage signal generated by the 20 Hz signal-generator is injected into the secondary of thegenerator neutral grounding transformer through aband-pass filter. The band-pass filter passes the 20Hz signal and rejects out-of-band signals. The outputof the 20 Hz band-pass filter is connected to the V

Ninput of the M-3425A relay through a suitable voltagedivider, that limits the M-3425A to OOOOO 200 V ac (thevoltage generator may be bypassed if the expected50/60 Hz voltage during a phase-to-ground fault ofthe generator is OOOOO 200 V.) The 20Hz current is alsoconnected to the I

N input of the M-3425A, through

the 20Hz current transformer.

64S PICKUPmAmps

64S VOLT INHIBITdisable ENABLE

64S VOLT INHIBITVolts

64S DELAYCycles


2–66

RL

1B1

1A1

1B4

1A3 1A4

20 HzBand Pass

Filter

20 HzGenerator

4A1

1A1

1A2

1A3

2A3

2A1

3A2

3A14A3

Bl

3A3

Supply VoltageDC AC+VAux V A(L1)

-VAux V B(L2)

VC(L3)

ExternalBlock

DeviceOperative

44 45

M-3425A

52 53

400A5A

L K

l k

Max. 200 V

V N

I N

NeutralGrounding

Transformer

WiringShielded

20 Hz CT

400/5 A

59N

HighVoltage

LowVoltage

Figure 2-56 64S Function Component Connection Diagram

Equipment Description BECO Part No.

Siemens7XT33

20 Hz Signal-Generator 430-00426

OEM Part No.

Siemens7XT34

430-00427

ITICTWS-60-T50-401

430-00428

20 Hz Band-pass Filter

20 Hz Measuring Current Transformer400-5 A CT

Table 2-7 Low Frequency Signal Injection Equipment Part Number Cross Reference

Application – 2

2–67

20 Hz Injection Voltage

I20

5 V 10 V 15 V 20 V 25 V 30 V 35 V 40 V

140 %

60 %

TRIP

45 V0 V

64SPickupCurrent

Figure 2-57 64S Function Time Delay Pickup Current Correlation


(64S) - 100% STATOR GROUND

#1

Expanded I/O’s

Save Cancel

X?

Pickup:

Delay:

2 mA

1 Cycle

40 mA

8160 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Undervoltage Inhibit: Enable Disable

5 V 30 V

F64S

Figure 2-58 100% Stator Ground Protection (64S) Setpoint Ranges


2–68

calculated using VA, V

B and V

C inputs. The function

provides both definite time and inverse timeelements. The inverse time element provides severalcurves. The curves available for use are shown inAppendix D, Inverse Time Curves. They cover arange from 1.5 to 20 times the pickup setting. Anadditional one cycle time delay should be added tothese curves in order to obtain the relay operatingtime. Inverse time curves saturate beyond 20 timespickup. For currents in excess of 20 times pickup,operating times are fixed at the 20 time pickuplevel.

To obtain maximum sensitivity for fault currents,the directional element is provided with a maximumsensitivity angle adjustment (MSA). This setting iscommon to both the 67NDT and 67NIT elements.The pickup sensitivity of the relay remains constantfor 90° either side of the so-called MaximumSensitivity Angle (MSA). At angles over 90° fromMSA, the relay operation is blocked. Typical MSAsetting for a generator internal ground fault protectoris approximately 150°.

67N Residual Directional OvercurrentThe Residual Directional Overcurrent function (67N)provides protection from ground faults. The 67Nfunction can provide generator ground faultprotection. It can also provide directionaldiscrimination when multiple generators are busedtogether. The 67N Function is subject to the followingconfiguration limitations:

• VX polarization cannot be selected if 25

(Sync) function is enabled.

• 3V0 polarization can only be used with

Line-Ground VT configuration.

• 67N Function is not available if 87GD isenabled.

The 67N Function operates on the residual currenteither from internal calculation (3I

0) using I

A, I

B and

IC or using a residual current input from I

N input of

the relay (this is preferred compared to 3I0). The

relay can be polarized with the neutral voltage (VN),

broken delta voltage connected at VX

input or 3V0

Figure 2-59 Residual Directional Overcurrent (67N) Trip Characteristics

Application – 2

2–69

Pickup value for the 67N element.

Directional discrimination enable. When disabled, this functionwill work like a 50N.

Time Delay setting.

Inverse Time Pickup

Directional discrimination enabled. When disabled, this functionwill operate like 51N.

Select the inverse time curve.

Time dial setting

See Figure 2-59 for Max Sensitivity Angle (MSA) settings.

Select the operating current.

Select the polarization voltage. If 3V0 is selected, VT configu-ration must be set to Line-Ground.

67NDT PICKUP______________ Amps

67NDT DIR ELEMENTdisable ENABLE

67NDT DELAY_____________ Cycles

67NIT PICKUP______________ Amps

67NIT DIR ELEMENTdisable ENABLE

67NIT CURVEbdef binv bvinv beinv

67NIT TIME DIAL________________

67N MAX SENSITIVITY ANGLE____________ Degrees

67N OPERATING CURRENT3I0 in

67N POLARIZING QUANTITY3V0 vn vx


2–70


(67N) - RESIDUAL DIRECTIONAL OVERCURRENT

Note: VX cannot be selected if 25 (Sync) function is enabled. 3V0 can only be used with Line-Ground VT configuration.

Expanded I/O’s

Save Cancel

X?

Expanded I/O’s

Def. Time

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Pickup:

Delay:

0.5 A

1 Cycle

240.0 A

8160 Cycles

Enable DisableDirectional Element:

Inv. Time

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Pickup:

Time Dial:

0.25 A

0.5

12.00 A

11.0

Enable DisableDirectional Element:

Max Sensitivity Angle: 0o 359o

3I0 INOperating Current:

3V0 (Calculated) VN VXPolarizing Quantity:

F67N

Curves

BECO Definite Time

IECEI

BECO Inverse

IECLTI

BECO Very Inverse

IEEE Moderately Inv.

BECO Extremely Inverse

IEEE Very Inverse

IECI

IEEE Extremely InverseI

IECVI

Figure 2-60 Residual Directional Overcurrent (67N) Setpoint Ranges

Application – 2

2–71

78 Out-of-StepThe Out-of-Step function (78) is used to protect thegenerator from out-of-step or pole slip conditions.This function uses one set of blinders, along with asupervisory MHO element. Ranges and incrementsare presented in Figure 2-63.

The pickup area is restricted to the shaded area inFigure 2-61, Out-of-Step Relay Characteristics, definedby the inner region of the MHO circle, the region to theright of the blinder A and the region to the left of blinderB. For operation of the blinder scheme, the operatingpoint (positive sequence impedance) must originateoutside either blinder A or B, and swing through thepickup area for a time greater than or equal to the timedelay setting and progress to the opposite blinder fromwhere the swing had originated. When this scenariohappens, the tripping logic is complete. The contactwill remain closed for the amount of time set by theseal-in timer delay.

XT

= Transformer Reactance

XS

= System Reactance

Xd’= Transient Reactance of the Generator

Consider, for example, Figure 2-62. If the Out-of-step swing progresses to impedance Z

0(t

0), the

MHO element and the blinder A element will bothpick up. As the swing proceeds and crosses blinderB at Z

1(t

1), blinder B will pick up. When the swing

reaches Z2(t

2), blinder A will drop out. If TRIP ON

MHO EXIT option is disabled and the timer hasexpired (t

2–t

1>time delay), then the trip circuit is

complete. If the TRIP ON MHO EXIT option isenabled and the timer has expired, then for the tripto occur the swing must progress and cross theMHO circle at Z

3(t

3) where the MHO element drops

out. Note the timer is active only in the pickupregion (shaded area). If the TRIP ON MHO EXIToption is enabled, a more favorable tripping angle isachieved, which reduces the breaker tripping duty.The relay can also be set with a Pole Slip Counter.The relay will operate when the number of pole slipsare greater than the setting, provided the Pole SlipReset Time was not expired. Typically, the PoleSlip Counter is set to 1, in which case the Pole SlipReset Time is not applicable.

Typical setting is (1.5XT+2Xd’)

Typical setting is –2Xd’.

Typical setting is (1/2) (Xd’+ XT + XS) tan(Θ–(δ/2)). Typicalvalue for δ is 120°.

Typical setting for Θ is 90°.

The time delay should be set based on the stability study. Inthe absence of such a study, it can be set between 3 and 6cycles.

This setting is typically enabled.

Typical setting is 1 pole slip.

Typical setting is 120 cycles.

78 DIAMETER______________ Ohms

78 OFFSET______________ Ohms

78 BLINDER IMPEDANCE______________ Ohms

78 IMPEDANCE ANGLE____________ Degrees

78 DELAY_____________ Cycles

78 TRIP ON MHO EXITdisable enable

78 POLE SLIP COUNT_____________ slips

78 POLE SLIP RESET TIME_____________ Cycles


2–72

SYSTEM

A B

R

P GN F

HM

MHO

ELEMENT

ELEMENTS

GEN(X'

d)

TRANS

O

X

BLINDER

C

XT

XS

D

d

'

SWINGLOCUS

1.5 X T

2Xd

Figure 2-62 Out-of-Step Protection Settings

A B

Z3(t3)

Z2(t2)Z1(t1)

Z0(t0)

Figure 2-61 Out-of-Step Relay Characteristics

Application – 2

2–73

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Figure 2-63 Out-of-Step (78) Setpoint Ranges


2–74

81 FrequencyThe Frequency function (81) provides eitheroverfrequency or underfrequency protection of thegenerator. It has four independent pickup and timedelay settings. The overfrequency mode isautomatically selected when the frequency setpointis programmed higher than the base frequency (50or 60 Hz), and the underfrequency mode selectedwhen the setpoint is programmed below the basefrequency. Ranges and increments are presented inFigure 2-65.

The steam turbine is usually considered to be morerestrictive than the generator at reduced frequenciesbecause of possible natural mechanical resonancein the many stages of the turbine blades. If thegenerator speed is close to the natural frequency ofany of the blades, there will be an increase invibration. Cumulative damage due to this vibrationcan lead to cracking of the blade structure.

Sample settings of the 81 function are shown inFigure 2-64. The frequency functions are

81 #1 PICKUP_______________ Hz

81 #1 DELAY_____________ Cycles

81 #2 PICKUP_______________ Hz

81 #2 DELAY_____________ Cycles

81 #3 PICKUP_______________ Hz

81 #3 DELAY_____________ Cycles

81 #4 PICKUP_______________ Hz

81 #4 DELAY_____________ Cycles

automatically disabled when the input voltage(positive sequence) is very low (typically between2.5 V and 15 V, based on the frequency.)

The 81 function should be disabled using breakercontact when the unit is offline.

These magnitude and time settings describe a curve(as shown in Figure 2-64, Example of Frequency(81) Trip Characteristics) which is to be coordinatedwith the capability curves of the turbine and generatoras well as the system underfrequency load-sheddingprogram. These capabilities are given by adescription of areas of prohibited operation, restrictedtime operation, and continuous allowable operation.

The underfrequency function is usually connectedto trip the machine whereas the overfrequencyfunction is generally connected to an alarm.

In order to prevent mis–operation during switchingtransients, the time delay should be set to greaterthan five (5) cycles.

Application – 2

2–75

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Figure 2-65 Frequency (81) Setpoint Ranges

61.0

60.8

60.6

60.4

60.2

60.0

59.8

59.6

59.4

59.2

59.0

Time (cycles)

81O

ver

Fre

qu

ency

(H

z)81

Un

der

Fre

qu

ency

(H

z)

Trip

Trip

Over FrequencyTime Delay #2

Over FrequencyTime Delay #1

Under FrequencyTime Delay #4

Under FrequencyTime Delay #3

Over FrequencyMagnitude #1

Under FrequencyMagnitude #4

Over FrequencyMagnitude #2

Under FrequencyMagnitude #3

Figure 2-64 Example of Frequency (81) Trip Characteristics


2–76

81A Frequency AccumulatorFrequency Accumulation feature (81A) provides anindication of the amount of off frequency operationaccumulated.

Turbine blades are designed and tuned to operate atrated frequencies, operating at frequencies differentthan rated can result in blade resonance and fatiguedamage. In 60 Hz machines, the typical operatingfrequency range for 18 to 25 inch blades is 58.5 to61.5 Hz and for 25 to 44 inch blades is between59.5 and 60.5 Hz. Accumulated operation, for thelife of the machine, of not more than 10 minutes forfrequencies between 56 and 58.5 Hz and not morethan 60 minutes for frequencies between 58.5 and59.5 Hz is acceptable on typical machines.

The 81A function can be configured to track offnominal frequency operation by either set point orwhen the frequency is within a frequency band.

When using multiple frequency bands, the lowerlimit of the previous band becomes the upper limit

81A #1 HIGH BAND PICKUP_______________ Hz

81A #1 LOW BAND PICKUP_______________ Hz

81A #1 DELAY_____________ Cycles


81A #2 DELAY_____________ Cycles


81A #3 DELAY_____________ Cycles


81A #4 DELAY_____________ Cycles


81A #5 DELAY_____________ Cycles


81A #6 DELAY_____________ Cycles

for the next band, i.e., Low Band #2 is the upperlimit for Band #3, and so forth. Frequency bandsmust be used in sequential order, 1 to 6. Band #1must be enabled to use Bands #2–#6. If any band isdisabled, all following bands are disabled.

When frequency is within an enabled band limit,accumulation time starts (there is an internal tencycle delay prior to accumulation), this allows theunderfrequency blade resonance to be establishedto avoid unnecessary accumulation of time. Whenaccumulated duration is greater than set delay,then the 81A function operated the programmedoutput contact. The contact can be used to alert theoperator or trip the machine.

The accumulator status can be set to preserve theaccumulated information from previous devices.This allows the relay to begin accumulatinginformation at a pre-defined value. This setpoint isonly available through IPScom® CommunicationsSoftware.

Application – 2

2–77

0 5 10 15Time (mins)

81-4 LB

81-3 LB

81-2 LB

81-1 LB

81-1 HB

Fn

Example- Band

#1 Band

#2 Band

#3 Band

#4 Band

#5 Band

Figure 2-66 Frequency Accumulator (81A) Example Bands


High Pickup:

Low Pickup:

Delay:

Acc. Status:

50.00 Hz

50.00 Hz

3 Cycles

0 Cycle

67.00 Hz

67.00 Hz

360000 Cycles

360000 Cycles

#1

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Reset

#3

#5

#2

#4

#6

(81A) FREQUENCY ACCUMULATOR

Expanded I/O’s

Save Cancel

X?

F81A

Reset

Low Pickup:

Delay:

Acc. Status:

50.00 Hz

3 Cycles

0 Cycle

67.00 Hz

360000 Cycles

360000 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Reset

Low Pickup:

Delay:

Acc. Status:

50.00 Hz

3 Cycles

0 Cycle

67.00 Hz

360000 Cycles

360000 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Reset

Low Pickup:

Delay:

Acc. Status:

50.00 Hz

3 Cycles

0 Cycle

67.00 Hz

360000 Cycles

360000 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Reset

Low Pickup:

Delay:

Acc. Status:

50.00 Hz

3 Cycles

0 Cycle

67.00 Hz

360000 Cycles

360000 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Reset

Low Pickup:

Delay:

Acc. Status:

50.00 Hz

3 Cycles

0 Cycle

67.00 Hz

360000 Cycles

360000 Cycles

OUTPUTS8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Blocking Inputs@

Expanded I/O’s

Expanded I/O’s

Expanded I/O’s

Expanded I/O’s

Expanded I/O’s

Figure 2-67 Frequency Accumulator (81A) Setpoint Ranges


2–78

81R Rate of Change of FrequencyThe Rate of Change of Frequency function (81R) canbe used for load shedding or tripping applications.

The function also has an automatic disable featurewhich disables 81R function during unbalanced faultsand other system disturbances. This feature usesnegative sequence voltage to block the 81R function.When the measured negative sequence voltageexceeds the inhibit setting, the function 81R andmetering are blocked. The time delay and magnitudesettings of 81R should be based on simulation studies.The ranges and increments are shown in Figure 2-68.

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Figure 2-68 Rate of Change of Frequency (81R) Setpoint Ranges

81R #1 PICKUP______________ Hz/s

81R #1 DELAY_____________ Cycles

81R #2 PICKUP______________ Hz/s

81R #2 DELAY_____________ Cycles

81R NEG SEQ VOLT INHIBIT_______________ %

Application – 2

2–79

87 Phase DifferentialThe Phase Differential function (87) is a percentagedifferential with an adjustable slope of 1–100%.Although this protection is used to protect themachine from all internal winding faults, single-phase to ground faults in machines with highimpedance grounding may have currents less thanthe sensitivity of the differential relay (typicallybetween 3 and 30 primary amps). Ranges andincrements are presented in Figure 2-70.

Turn-to-turn faults are not detected by differentialrelays because the current into the generator equalsthe current out (see functions 50DT and 59X forturn-to-turn fault protection.) Even though thepercentage differential relay is more tolerant of CTerrors, all CTs should have the same characteristicsand accuracies.

A typical setting is 0.3 amps.

A typical setting is 10%.

A typical setting is one cycle. Typical settings given above assumematched current transformer performance, and that transformer in-rush of the unit transformer does not cause dc saturation of thegenerator CTs. If there is a significant difference in current trans-former ratings (C800 vs C200, for example), or if saturation of thegenerator CTs is expected during energizing of the step up trans-former, more appropriate settings might be 0.5 A pick up, 20% slope,and a delay of 5 to 8 cycles.

If line side and neutral side CTs do not have the same ratio, the ratioerror can be corrected (the line side measured current is multipliedby the phase CT correction settings.)

Line Side CTRPhase CT Correction =

Neutral Side CTR

To provide restraint for CT saturation at high offsetcurrents, the slope is automatically adjusted (at arestraining current equal to two times nominal current)to four times the slope setting, see Figure 2-69.

For very high currents in large generators, theproximity of CTs and leads in different phases cancause unbalanced currents to flow in the secondaries.These currents must be less than the minimumsensitivity of the relay.

There are two elements in this function. Element #2is intended to provide phase differential protectionfor SFC (Static Frequency Converter) starting gasturbine generator applications. Element #1 shouldbe disabled with a contact blocking input during aconverter start operation (generator off-line), sincethe current is carried by only neutral side CTs andthe resulting differential current may mis-operate87#1 function. The 87#2 element, which is set witha higher current pickup, will still provide protectionfor this condition.

87 #1 PICKUP______________ Amps

87 #1 SLOPE_______________ %

87 #1 DELAY_____________ Cycles

87 #2 PICKUP______________ Amps

87 #2 SLOPE_______________ %

87 #2 DELAY_____________ Cycles

87 PHASE CT CORRECTION________________


2–80

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Figure 2-69 Differential Relay (87) Operating Characteristics

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Figure 2-70 Phase Differential (87) Setpoint Ranges

Application – 2

2–81

87GD Ground (Zero Sequence) DifferentialThe Zero Sequence Differential function (87GD)provides ground fault protection for low impedancegrounded generator applications. High sensitivityand fast operation can be obtained using thisfunction. Ranges and increments are presented inFigure 2-71.

The relay provides a CT Ratio Correction Factor(R

C) which removes the need for auxiliary CTs when

the phase and neutral CT ratios are different.

When the system can supply zero sequence currentto the ground fault (such as when several generatorsare bussed together), the 87GD function operatesdirectionally. The directional element calculates theproduct (–3I

0INCosØ) for directional indication. The

relay will operate only if I0 (Zero sequence current

derived from phase CTs) and IN (Neutral current

from Neutral CT) have the opposite polarity, whichis the case for internal generator faults.

87GD PICKUP______________ Amps

87GD DELAY_____________ Cycles

87GD C.T. RATIO CORRECT________

A typical setting is 0.2 amps. (Relay amps = primary amps ÷ CTratio.) For higher values of R

C, noise may create substantial

differential current making higher pickup settings desirable.

▲▲▲▲▲ CAUTION: Do NOT set the Delay to less than 2 Cycles.

In order to prevent mis-operation during external faults with CTsaturation conditions, a time delay of 6 cycles or higher isrecommended.

CT Ratio Correction Factor = (Phase CT Ratio)/(Neutral CT Ratio)

The advantage of directional supervision is thesecurity against ratio errors and CT saturation duringfaults external to the protected generator.

The directional element is inoperative if the residualcurrent (3I

0 ) is approximately less than 0.2 A, in

which case the algorithm automatically disables thedirectional element and the 87GD function becomesnon-directional differential. The pickup quantity isthen calculated as the difference between thecorrected triple zero-sequence current (R

C3I

0) and

the neutral current (IN). The magnitude of the

difference (RC3I

0–I

N) is compared to the relay pickup.

For security purposes during external high phase-fault currents causing CT saturation, this function isdisabled any time the value of I

N is less than

approximately 0.20 amps.

■ NOTE: When 87GD is enabled, 67N function isnot available.

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2–82

Breaker MonitoringThe Breaker Monitoring feature calculates an estimateof the per-phase wear on the breaker contacts bymeasuring and integrating the current (IT) or currentsquared (I2T) passing through the breaker contactsduring the interruption period. The per-phase valuesare added to an accumulated total for each phase,and then compared to a user-programmed thresholdvalue. When the threshold is exceeded in any phase,the relay can operate a programmable output contact.The accumulated value for each phase can be displayed

Expanded Inputs IN7–IN14 (if equipped) must be set using IPScom.

Expanded Outputs OUT9–OUT23 (if equipped) must be set usingIPScom.

(BM) - BREAKER MONITOR


Save Cancel

X?

Expanded I/O’s

Expanded I/O Initiate

#10 KA

0.1 Cycle

50000 KA

4095.9 Cycles

Pickup:

Delay:

Blocking Inputs

6 5 4 3 2 1

Input Initiate

6 5 4 3 2 1

OUTPUTS

8 7 6 5 4 3 2 1

Output Initiate

8 7 6 5 4 3 2 1

0 KA Cycles

0 KA Cycles

0 KA Cycles

50000 KA Cycles

50000 KA Cycles

50000 KA Cycles

Phase A:

Phase B:

Phase C:

Preset Accumulators

Timing Method Select: IT I^2T

FL

FBM

Figure 2-72 Breaker Monitor (BM) Setpoint Ranges

BM PICKUP______ kA-cycles

BM INPUT INITIATEi6 i5 i4 i3 i2 i1

BM OUTPUT INITIATE08 07 06 05 04 03 02 01

BM DELAY____________ Cycles

BM TIMING METHODit i2t

as an actual value. The accumulation starts after aset time delay from the trip initiate command toaccount for the time it takes for the breaker to startopening its contacts. The accumulation continuesuntil the current drops below 10% of the nominalcurrent setting or 10 cycles, whichever occurs first.

■ NOTE: Preset Accumulator Setpoints are onlyavailable through IPScom®.

Application – 2

2–83

Trip Circuit MonitoringExternal connections for the Trip Circuit Monitoringfunction are shown in Figure 2-73. The default TripCircuit Monitor input voltage is 250 V dc. See Section5.5, Circuit Board Switches and Jumpers, Table 5-3for other available trip circuit input voltage selections.

This function should be programmed to block whenthe breaker is open, as indicated by 52b contactinput (IN1). If the TCM is monitoring a lockout relay,a 86 contact input (INx) should be used to blockwhen the lockout relay is tripped.

When the Output Contact is open, and continuityexists in the Trip Circuit, a small current flows thatactivates the Trip Circuit Monitoring Input. If the TripCircuit is open, and the output contact is open, nocurrent flows and the Trip Circuit Monitoring Input is

52b

M-3425A

Trip CircuitMonitoring Input

2

1 Aux Input

OutputContact

StationBattery

+

-

OtherContacts

52a

52 or 86Trip Coil

86or

Figure 2-73 Trip Circuit Monitoring Input

deactivated. An Output Contact that is welded closedwould also cause the Trip Circuit Monitoring Input todeactivate, indicating failure of the Output Contact.

When the Output Contact is closed, no current flowsin the Trip Circuit Monitoring Input. If the M-3425Ahas issued a trip command to close the OutputContact and Trip Circuit Monitoring Input remainsactivated, this is an indication that the Output Contactfailed to close.

The output of the Trip Circuit Monitoring function canbe programmed as an alarm to alert maintenancepersonnel.

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Figure 2-74 Trip Circuit Monitor (TC) Setpoint Ranges

TCM DELAY_____________ Cycles


2–84

IPSlogic™The relay provides six logic functions and associatedIPSlogic. The logic functions can be used to allowexternal devices to trip through the relay, providingadditional target information for the external device.More importantly, these functions can be used inconjunction with IPSlogic to expand the capabilityof the relay by allowing the user to define customizedoperating logic.

Programming the IPSlogic can only be implementedthrough IPScom® Communications Software. TheIPSlogic cannot be programmed using the Human-Machine Interface (HMI).

IPS LOGICUSE IPSCOM TO CONFIGURE

Application – 2

2–85

Blo

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s

Sel

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And

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Initi

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Pro

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And

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Pro

gram

mab

leO

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ts 1

-8*O

utpu

ts 9

-23

Initi

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Via

Com

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Poi

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And

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Sel

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ble

And

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Initi

ate

Via

Com

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Poi

nt

Pro

gram

mab

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1-6

*Inp

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7-14

Pro

gram

med

Tim

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elay

1- 6

5,50

0 C

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s(1

091

sec)

Pro

gram

med

Pro

file

Set

ting

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-4

Pro

gram

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Out

puts

1-8

*Out

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1-2

3

Log

Tar

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Log

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Out

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Figure 2-75 IPSlogic™ Function Setup


2–86

Settings and Logic Applicable whenIPSlogic™ Function(s) programmed usingIPScom®

There are four initiating input sources: InitiatingOutputs, Initiating Function Trips, Function Pickup(including the IPSlogic Functions themselves),Initiating Inputs, and initiation using theCommunication Port. The only limitation is that anIPSlogic Function may not be used to initiate itself.There are two blocking input sources: BlockingInputs and blocking using the Communication Port.

The activation state of the input function selected inthe Initiating Function can be either timeout (Trip) orpickup. The desired time delay for securityconsiderations can be obtained in the IPSlogicFunction time delay setting.


(IPS) IPSLogic X?

#1 #2 #3 #4 #5 #6

#1

Initiate via Communication Point

Block via Communication Point

6 5 4 3 2 1

Initiating Inputs

Save Cancel

OR

OR

OR

OR

OR

OR

OR

NOR

AND

Initiating Function Timeout

Initiating Function Pickup

Expanded Outputs

OUTPUTS

8 7 6 5 4 3 2 1

@

IPS #1Activated

1 Cycle 8160 CyclesDelay:

FL 6 5 4 3 2 1

Blocking Inputs

Expanded Blocking Inputs

Expanded Initiating Inputs

8 7 6 5 4 3 2 1

Initiating Outputs

Expanded Initiating Outputs

0 Cycle 65500 CyclesDO/RST Delay:

Dropout (DO) Timer Reset (RST) Timer

Profile

#1 #2 #3 #4NA

Notes:

1. This logic gate may be selected as either AND or OR.

2. This logic gate may be selected as AND, OR, NOR, or NAND.

Figure 2-76 IPSlogic Function Programing

The IPSlogic Function can be programmed toperform any or all of the following tasks:

• Change the Active Setting Profile

• Close an Output Contact

• Be activated for use as an input to anotherExternal Function

Since there are six IPSlogic Functions per settingprofile, depending on the number of different relaysettings defined, the scheme may provide up to 24different logic schemes. The IPScom IPSlogicFunction programming screen is shown in Figure2-76.

Application – 2

2–87

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Figure 2-77 Selection Screen for Initiating Function Timeout

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Figure 2-78 Selection Screen for Initiating Function Pickup


2–88

DO/RST (Dropout/Reset) Timer FeatureThe DO/RST timer can be set as either Dropout orReset mode. The operation of the Dropout DelayTimer and the Reset Delay Timer are describedbelow.

Reset Delay TimerThe Reset Delay Timer logic is presented in Figure2-80. The Reset Delay Timer feature allows theuser to delay the reset of the PU Time Delay Timerand hold the accumulated timer value (A) for theduration of the Reset Time Delay time period (B).The Reset Delay Timer starts when the IPSlogicPU Status drops out (C).

PU Status

PU Time DelaySetting (30)

Output

25 35

Dropout Delay Timer

Seal in Delay

Seal in Delay

Dropout Delay

Cycles

PU Time Delay Timing

IPSlogic Functions (1 - 6)

A

B

C D

E

Figure 2-79 Dropout Delay Timer Logic Diagram

Dropout Delay TimerThe Dropout Delay Timer logic is presented inFigure 2-79. The Dropout Delay Timer feature allowsthe user to affect an output time delay that startswhen the IPSlogic PU Status drops out (A) and canhold the Output (D) status true beyound the OutputSeal In Delay value (C).

However, the Seal In Delay (E) may hold the Output(B) true if the time after IPSlogic PU Status dropout(A) and Dropout Delay Timer value (D) are less thanthe Seal In Delay time (E).

Reset Delay Timer

PU Status

Output

25 25

Reset Delay10 Cycles

12 8Cycles

ResetDelay

5

Seal InTimer

ResetDelay

10

PU Time Delay Timing

IPSlogic Functions (1 - 6)

A

DC

B

E

F

G

PU Time DelaySetting (30)

Figure 2-80 Reset Delay Timer Logic Diagram

If the IPSlogic PU Status remains dropped out (D)after the reset delay has timed out, then the IPSlogicPU timer value will be reset to zero (E).

If the IPSlogic PU Status reasserts (F) while theReset Delay Timer is still timing, then the PU TimerDelay begins timing from the accumulated value (G).

Operation – 3

3–1

3 Operation

3.1 Front Panel Controls .................................................................. 3–1

3.2 Initial Setup Procedure/Settings ................................................ 3–5

3.3 Setup Unit Data .......................................................................... 3–5

3.4 Setup System Data .................................................................... 3–6

3.5 Status/Metering .......................................................................... 3–9

3.6 Target History ........................................................................... 3–10

Arrow PushbuttonsThe left and right arrow pushbuttons are used tochoose among the displayed menu selections. Whenentering values, the left and right arrow pushbuttonsare used to select the digit (by moving the cursor) ofthe displayed setpoint that will be increased ordecreased by the use of the up and downpushbuttons.

The up and down arrow pushbuttons increase ordecrease input values or change between upperand lower case inputs. If the up or down pushbuttonis pressed when adjusting numerical values, thespeed of increment or decrement is increased.

EXIT PushbuttonThe EXIT pushbutton is used to exit from a displayedscreen and move up the menu tree. Any changedsetpoint in the displayed screen will not be saved ifthe selection is aborted using the EXIT pushbutton.

ENTER PushbuttonThe ENTER pushbutton is used to choose ahighlighted menu selection, to replace a setpoint orother programmable value with the currently displayedvalue, or to move down within the menu tree.

Target & Status Indicators and ControlsThe target/status indicators and controls consist ofthe POWER SUPPLY (2) LEDs, RELAY OK LED,the OSCILLOGRAPH TRIG LED, BREAKERCLOSED LED, TARGET LED, DIAGNOSTIC LEDand TIME SYNC LED.

This chapter contains information that describesthe operation of the M-3931 Human Machine InterfaceModule (HMI) and the M-3925A Target module. Itfurther describes the direct setting and configurationprocedures for entering all required data to the relay.Included in this chapter is a description of theprocess necessary for review of setpoints and timing,monitoring function status and metering quantities,viewing the target history, and setup of theoscillograph recorder.

3.1 Front Panel Controls

The relay has been designed to be set andinterrogated locally with the optional HMI panel. Anintegral part of this design is the layout and functionof the front panel indicators and controls, illustratedin Figure 3-1.

Alphanumeric DisplayTo assist the operator in setting and interrogatingthe relay locally, the HMI displays menus whichguide the operator to the desired function or setpointvalue. These menus consist of two lines. The bottomline lists lower case abbreviations of each menuselection with the chosen menu selection shown inuppercase. The top menu line provides a descriptionof the chosen menu selection.

Screen BlankingThe display will automatically blank after exitingfrom the Main Menu, or from any screen after five(5) minutes of unattended operation. To wake up thedisplay, the user must press any key except EXIT.


3–2

Power Supply #1 (#2) LEDThe green PS LED indicator will remain illuminatedfor the appropriate power supply whenever power isapplied to the unit and the power supply is operatingcorrectly. A second power supply is available as anoption, for units without expanded I/O.

Relay OK LEDThe green RELAY OK LED is controlled by therelay's microprocessor. A flashing RELAY OK LEDindicates proper program cycling. The LED can alsobe programmed to be continuously illuminated.

Oscillograph Triggered LEDThe red OSC TRIG LED will illuminate to indicatethat oscillographic data has been recorded in theunit’s memory and is available for download.

Breaker Closed LEDThe red BRKR CLOSED LED will illuminate toindicate when the breaker status input IN1 (52b) isopen.

Target Indicators and Target ResetWhen a condition exists that causes the operationof outputs 1 through 8 (1 through 23 for units withexpanded I/O), the TARGET LED will illuminate,indicating a relay operation. The TARGET LED willremain illuminated until the condition causing thetrip is cleared, and the operator presses the TARGETRESET pushbutton. For units equipped with theoptional M-3925A Target Module, additional targetinginformation is available. The Target module includesan additional 24 target LEDs, and 8 output statusLEDs. LEDs corresponding to the particular operatedfunction as well as the present state of the outputsare available. Pressing and holding the TARGETRESET pushbutton will display the present pickupstatus of all functions available on the target module.This is a valuable diagnostic tool which may beused during commissioning and testing.

Time Sync LEDThe green TIME SYNC LED will illuminate to indicatethat the IRIG-B time signal is received and theinternal clock is synchronized with the IRIG-B timesignal. IRIG-B time information is used to accuratelytag target and oscillograph events.

Diagnostic LEDThe diagnostic DIAG LED will flash when a self-testerror is detected. The LED will flash the Error Codenumber; for example, for Error Code 32, the LEDwill flash 3 times, followed by a short pause, andthen flash 2 times, followed by a long pause, thenrepeat LED flash sequence. For units equipped withthe HMI, the Error Code number is also displayedon the screen.

Accessing ScreensTo prevent unauthorized access to relay functions,the unit includes a provision for assigning accesscodes. If access codes have been assigned, theaccess code entry screen will be displayed afterENTER is pressed from the default message screen.

Default Message ScreensWhen power is applied to the unit, the relay performsa number of self-tests to ensure that it is operatingcorrectly. During the self-tests, the screen displaysan “X” for each test successfully executed.

If all self-tests are executed successfully, the relaywill briefly display the word PASS and then a seriesof status screens that include:

• Model Number

• Software Version Number

• Serial Number

• Date and time as set in the system clock

• User Logo Screen

If a test fails, an error code will be displayed and therelay will not allow operation to proceed. In such acase, the error code should be noted and the factorycontacted. A list of error codes and their descriptionsare provided in Appendix C, Error Codes.

When the relay has power applied and is unattended,the user logo lines are blanked.

If a function has operated and the targets have notbeen reset, the screen will display the time and dateof the operation and automatically cycle throughscreens for each applicable target (see Figure 3-2).Pressing the ENTER pushbutton will enter localmode operation, displaying the access code entryscreen or, if access codes have been disabled, thefirst level menu.

Figure 3-3 presents the software menu flow map forHMI-equipped units. This map can be used as aquick reference guide to aid in navigating the relay'smenus.

Operation – 3

3–3

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Figure 3-2 Screen Message Menu Flow

Figure 3-1 M-3425A Front Panel


3–4

VOLTAGE RELAYVOLT curr freq v/hz

• 27 Phase Undervoltage• 59 Phase Overvoltage• 27TN Neutrl Undervolt• 59X Overvoltage• 59N Neutral Overvoltage• 59D Volt. Diff. 3rd Har.

CURRENT RELAYvolt CURR freq v/Hz

• 46 Neg Seq Overcurrent• 50 Inst Overcurrent• 50/27 Inadvertent Energing• 50BF Breaker Failure• 50DT Def. Time Overcurr• 50N Inst Overcurrent• 51N Inv Time Overcurrent• 49 Stator Overload• 51V Inv Time Overcurrent• 87 Differential Overcurr• 87GD Gnd Diff Overcurr• 67N Res Dir Overcurr

FREQUENCY RELAYvolt curr FREQ v/hz

• 81 Frequency• 81R Rate of Change Freq• 81A Frequency Accum.

VOLTS PER HERTZ RELAYvolt curr freq V/HZ

• 24 Def Time Volts/Hertz• 24 Inv Time Volts/Hertz

POWER RELAY PWR lof fuse dist

• 32 Directional Power

LOSS OF FIELD RELAY pwr LOF fuse dist

• 40 Loss of Field

V. T. FUSE LOSS RELAY pwr los FUSE dist

• 60FL V. T. Fuse Loss

PHASE DISTANCE RELAY pwr lof fuse DIST

• 21 Phase Distance• 78 Out of Step

FIELD GROUND RELAYFIELD stator sync

• 64B/F Field Ground

STATOR GROUND RELAY field STATOR sync

• 64S Stator Ground

SYNC CHECK RELAY field stator SYNC

• 25S Sync Check• 25D Dead Volt

BREAKER MONITORBRKR trpckt ipslog

• Set Breaker Monitoring• Preset Accumulators• Clear Accumulators

TRIP CIRCUIT MONITORbrkr TRPCKT ipslog

• Trip Circuit Monitor

IPS LOGICbrkr trpckt IPSLOG

• IPS Logic

CONFIGURE RELAYCONFIG sys stat

• Voltage Relay• Current Relay• Frequency Relay• Volts per Hertz Relay• Power Relay• Loss of Field Relay• V.T. Fuse Loss Relay• Phase Distance Relay• Field Gnd Relay• Stator Gnd Relay• Sync Check Relay• Breaker Mon Relay• Trip Ckt Mon Relay• IPSLogic Relay

SETUP SYSTEMconfig SYS stat

• Input Activated Profiles• Active Setpoint Profile• Copy Active Profile• Nominal Voltage• Nominal Current• V. T. Configuration• Delta-Y Transform• Phase Rotation • 59/27 Magnitude Select• 50DT Split-phase Diff.• Pulse Relay• Latched Outputs• Relay Seal-in Time• Active Input State• V.T. Phase Ratio• V.T. Neutral Ratio• V.T. VX Ratio• C.T. Phase Ratio• C.T. Neutral Ratio

STATUSconfig sys STAT

• Voltage Status• Current Status• Frequency Status• V/Hz Status• Power Status• Impedance Status• Sync Check Status• Breaker Mon Acc Status• 81A Accumulators Status• In/Out Status• Timer Status• Relay Temperature• Counters• Time of Last Power Up• Error Codes• Checksums

VIEW TARGET HISTORYTARGETS osc_rec comm

• View Target History• Clear Target History

OSCILLOGRAPH RECORDERtargets OSC_REC comm

• View Record Status• Clear Records• Recorder Setup

COMMUNICATIONtargets osc_rec COMM

• COM1 Setup• COM2 Setup• COM3 Setup• Communication Address• Response Time Delay• Comm Access Code• Ethernet Setup• Ethernet IP Address

SETUP UNIT SETUP exit

• Software Version• Serial Number• Alter Access Codes• User Control Number• User Logo Line 1• User Logo Line 2• Clear Output Counters• Clear Alarm Counter• Date & Time• Clear Error Codes• Ethernet Firmware Ver.• Diagnostic Mode

EXIT LOCAL MODE setup EXIT

NOTE: Depending on which functions are purchased, somemenus may not appear.

Figure 3-3 Main Menu Flow

Operation – 3

3–5

3.2 Initial Setup Procedure/Settings

The M-3425A Generator Protection Relay is shippedfrom the factory with all functions disabled (user willonly be able to enable purchased functions).

The Setup Procedure provided below is a suggestedsetup procedure for initially entering settings intothe relay. While it is written for HMI-equipped units,the same procedure is applicable when setting therelay through remote communication utilizingM-3820D IPScom® Communications Software.

Following the Setup Procedure are several sectionswhich provide additional detail concerning thesettings required for proper commissioning.

Setup ProcedureNOTE: Configuration Record forms are available

in Appendix A, Configuration RecordForms, to record settings for futurereference.

1. Enter the Setup Unit data. This is generalinformation required including alteringaccess codes, setting date and time,defining user logos, and otheradjustments. See Section 3.3, SetupUnit Data.

2. Configure the Setup System data. Thisis the general system and equipmentinformation required for operation,including such items as CT and VT ratios,VT configuration, and Nominal values.See Section 3.4, Setup System Datasubsection.

3. Enable the desired functions andelements. See Section 3.4, ConfigureRelay Data subsection.

4. Enter the desired setpoints for theenabled functions. See Section 3.4,Setpoints and Time Settings subsection.

5. Enter configuration information for theoscillograph recorder. See Section 3.4,Oscillograph Recorder Data subsection.

6. If remote communication is used, setthe parameters as needed. See Section3.4, Communications Settingssubsection, or in Chapter 4, RemoteOperation.

3.3 Setup Unit Data

NOTE: Please see Figure 3-3, Main Menu Flow,for a list of submenus associated withthe SETUP UNIT menu.

To access the SETUP UNIT menu proceed asfollows:

1. Press the ENTER pushbutton to displaythe main menu.

2. Press the right arrow pushbutton untilSETUP UNIT is displayed on the topline of the screen.

3. Press the ENTER pushbutton to accessthe SETUP UNIT menu.

SETUP UNIT SETUP exit

4. Press the ENTER pushbutton to movedown within the SETUP UNIT menu tothe desired category. To exit a specificcategory and continue to the next menucategory, press the EXIT pushbutton.

Setup Unit Data EntryThe general information required to complete theentry of Setup Unit Data includes:

Access Codes: The relay includes three levels ofaccess codes. Depending on their assigned code,users have varying levels of access to the installedfunctions.

1. Level 1 Access = Read setpoints,monitor status, view target history.

2. Level 2 Access = All of level 1privileges, plus read & changesetpoints, target history, set timeclock.

3. Level 3 Access = All of level 2privileges, plus access to allconfiguration functions and settings.

Each access code is a user-defined one- to four-digit number. Access codes can only be altered bya level 3 user.

If the level 3 access code is set to 9999, theaccess code feature is disabled. When accesscodes are disabled, the access screens arebypassed, and all users have full access to all therelay menus. The relay is shipped from the factorywith the access code feature disabled.


3–6

User Control Number: This is a user-defined valuewhich can be used for inventory or identification.The relay does not use this value, but it can beaccessed through the HMI or the communicationsinterface, and can be read remotely.

User Logo: The user logo is a programmable, two-line by 24-character string, which can be used toidentify the relay, and which is displayed locallywhen the relay is idle. This information is alsoavailable remotely.

Date and Time: This screen is used to view and setthe relay's internal clock. The clock is used to timestamp system events such as trip and oscillographoperations.

The clock is disabled when shipped from the factory(indicated by “80” seconds appearing on the clock)to preserve battery life. If the relay is to beunpowered for an extended length of time, the clockshould be stopped (see Diagnostic Mode). If theIRIG-B interface is used, the hours, minutes, andseconds information in the clock will besynchronized with IRIG-B time information everyhour.

The relay can accept a modulated IRIG-B signalusing the rear panel BNC connector, or ademodulated TTL level signal using extra pins onthe rear panel COM2 RS-232 interface connector(see Figure B-4 for COM2 pinout.) If the TTL signalis to be used, then Jumper 5 will be required to bepositioned (see Section 5.5, Circuit Board Switchesand Jumpers).

Setup Unit Features That Do Not Require DataEntryThe Setup Unit menu categories that provide theuser with read only information are SoftwareVersion, Serial Number and Ethernet FirmwareVer..

The Setup Unit menu also contains features thatprovide the user with the ability to Clear OutputCounters, Clear Alarm Counter, Clear ErrorCodes and access the Diagnostic Mode. The errorcodes are described in Appendix C, Self Test ErrorCodes. Note that while the relay is in DiagnosticMode, all protective functions are inoperative.

3.4 Setup System Data

NOTE: Please see Figure 3-3, Main Menu Flow,for a list of submenus associated withthe SETUP SYSTEM menu.

To access the SETUP SYSTEM menu proceed asfollows:


2. Press the right arrow pushbutton untilSETUP SYSTEM is displayed on thetop line of the screen.

3. Press the ENTER pushbutton to accessthe SETUP SYSTEM menu.

SETUP SYSTEMconfig SYS stat

To input the data, access the menu as follows:


2. Press the right arrow pushbutton untilSETUP SYSTEM is displayed on thetop line of the screen.

3. Press the ENTER pushbutton to accessthe SETUP SYSTEM menu and beginthe data input.

System setup data is required for proper operationof the relay. Information needed to complete thissection includes: Nominal Voltage, Nominal Current,VT Configuration, and other system-relatedinformation. See Section 2.1, Configuration, RelaySystem Setup subsection for a more detaileddescription of the settings required.

Operation – 3

3–7

Configure Relay DataNOTE: Please see Figure 3-3, Main Menu Flow,

for a list of submenus associated withthe CONFIGURE RELAY menu.

To input the data, access the CONFIGURE RELAYmenu as follows:


2. Press the right arrow pushbutton untilCONFIGURE RELAY is displayed onthe top line of the screen.

3. Press ENTER to access theCONFIGURE RELAY menu and beginthe data input.

CONFIGURE RELAYCONFIG sys stat

The general information required to complete theinput data in this section includes:

• enable/disable

• output choices (OUT1–OUT8; for unitswith expanded I/O, OUT9–OUT23 mayonly be set through IPScom®)

• input blocking choices (IN1–IN6; for unitswith expanded I/O, IN7–IN14 may only beset through IPScom), plus fuse lossblocking

Each of the purchased functions within the relaymay be individually enabled or disabled. In addition,many functions have more than one element whichmay also be enabled or disabled. Unused functionsand elements should be disabled to avoid nuisancetripping and speed up HMI response time.

After enabling a function/element, the user ispresented with two additional screens for selectionof input blocking and output contact designations.Any combination of the control/status inputs or theinternally generated VT fuse loss logic can beselected to dynamically block the enabled function.“OR” logic is used if more than one input is selected.

Outputs 1–6 (OUT9–OUT23 for units with expandedI/O, set through IPScom only) are form “a” contacts(normally open) and outputs 7 and 8 are form “c”contacts (center tapped “a” and “b” contacts). Outputcontacts 1–4 contain special circuitry for high-speedoperation and pick up approximately 4 ms fasterthan other contacts.

See Section 2.1, Configuration, for more information.

Setpoints and Time SettingsNOTE: Please see Figure 3-3, Main Menu Flow,

for a list of submenus and specificelements associated with the Setpointsand Time Setting menus.

To input the data, access these menus as follows:


2. Press the right arrow pushbutton untilVOLTAGE RELAY, the first of thesetpoint and time setting menus, isdisplayed on the top line of the screen.

NOTE: Some menus are dynamic, and do notappear if the function is not purchasedor is unavailable.

3. Press ENTER to begin the data input forthis menu, or continue pressing the rightarrow pushbutton until the desiredsetpoint and time setting menu isdisplayed, then press ENTER to beginthe data input.

The general information required to complete theinput data in this section includes individual relayfunction:

• pickup settings (converted to relayquantities)

• time delay settings

• frequency settings

• time dials

• power level settings (in percent rated)

• impedance diameter in relay ohms fordistance and offset settings

Settings should be programmed based on systemanalysis as described in Chapter 2, Application. Acomplete description of the individual function aswell as guidelines for settings are explained therein.


3–8

Oscillograph Recorder Data■ NOTE: Please see Figure 3-3, Main Menu Flow,

for a list of submenus associated withthe OSCILLOGRAPH RECORDERmenu.

To input the data, access the OSCILLOGRAPHRECORDER menu as follows:


2. Press the right arrow pushbutton untilOSCILLOGRAPH RECORDER isdisplayed on the top line of the screen.

3. Press the ENTER pushbutton to accessthe OSCILLOGRAPH RECORDER menuand begin the data input.

OSCILLOGRAPH RECORDERtargets OSC_REC comm

The Oscillograph Recorder provides comprehensivedata recording (voltage, current, and status input/output signals) for all monitored waveforms (at 16samples per cycle). Oscillograph data can bedownloaded using the communications ports to anyIBM compatible personal computer running theM-3820D IPScom® Communications Software. Oncedownloaded, the waveform data can be examinedand printed using the optional M-3801D IPSplot®

PLUS Oscillograph Data Analysis Software.

▲ CAUTION: Oscillograph records are not retainedif power to the relay is interrupted.

The general information required to complete theinput data of this section includes:

• Recorder Partitions: When untriggered,the recorder continuously recordswaveform data, keeping the data in abuffer memory. The recorder's memorymay be partitioned into 1 to 16 partitions.

When triggered, the time stamp isrecorded, and the recorder continuesrecording for a user-defined period. Thesnapshot of the waveform is stored inmemory for later retrieval using IPScomCommunications Software. The OSC TRIGLED on the front panel will indicate arecorder operation (data is available fordownloading).

• Trigger Inputs and Outputs: The recordercan be triggered remotely through serialcommunications using IPScom, or

automatically using programmed statusinputs or outputs.

• Post-Trigger Delay: A post-trigger delayof 5% to 95% must be specified. Aftertriggering, the recorder will continue tostore data for the programmed portion ofthe total record before re-arming for thenext record. For example, a setting of80% will result in a record with 20%pretrigger data, and 80% post-trigger data.

forebmuNsnoititraP

selcyCforebmuNnoititraPhcaErep

1 selcyC614

2 selcyC082

3 selcyC802

4 selcyC861

5 selcyC631

6 selcyC021

7 selcyC401

8 selcyC88

9 selcyC08

01 selcyC27

11 selcyC46

21 selcyC46

31 selcyC65

41 selcyC65

51 selcyC84

61 selcyC84

Table 3-1 Recorder Partitions

Communications SettingsTo enter the communications settings, access theCOMMUNICATION menu as follows:

1. Press the ENTER pushbutton to accessthe main menu.

2. Press the right arrow pushbutton untilCOMMUNICATION is displayed on thetop line of the screen.

Operation – 3

3–9

3. Press the ENTER pushbutton to accessthe COMMUNICATION menu and beginthe data entry.

COMMUNICATIONtargets osc_rec COMM

The general information required to complete thecommunications settings entry of this sectioninclude:

• Baud rate for COM1 and COM2communication ports. The COM3 port doesnot have a separate baud rate setting butuses the setting of COM2 (or COM1: seeSection 5.5 Circuit Board Switches andJumpers).

• Communications address is used toaccess multiple relays using a multidropor network communication line.

• Communications access code is used forcommunication system security (enteringan access code of 9999 disables thecommunication security).

• Communication protocol and dead synctime for COM2 and COM3.

• Parity for COM2 or COM3 if MODBUS orMODBUS over TCP/IP protocol is used.

• Response Time Delay

• IP Address, Net Mask and GatewayAddress are required if the ethernet port isutilized and the network does not supportthe DHCP protocol.

Detailed information concerning setup and operationof the communication ports is described in Chapter4, Remote Operation.

3.5 Status/Metering

Monitor Status/MeteringNOTE: Please see Figure 3-3, Main Menu Flow,

for a list of submenus associated withthe STATUS menu.

To access the STATUS menu and begin monitoring,proceed as follows:


2. Press the right arrow pushbutton untilSTATUS is displayed on the top line ofthe screen.

3. Press the ENTER pushbutton to accessthe STATUS menu.

STATUSconfig sys STAT

NOTE: Some menus are dynamic, and do notappear if the function is not purchasedor is unavailable.

4. Press the ENTER pushbutton to movedown within the STATUS menu to thedesired category. To exit a specificcategory and continue to the next menucategory, press the EXIT pushbutton.

The menu categories for monitored values are:• Voltage Status: phase voltages, neutral

voltage, positive sequence voltage,negative sequence voltage, zero sequencevoltage, third harmonic neutral voltage,field ground measurement circuit, statorlow frequency injection voltage

• Current Status: phase currents (A–B–C/a-b-c), differential current, neutral current,ground differential current, positivesequence current, negative sequencecurrent, zero sequence current, stator lowfrequency injection current

• Frequency Status: frequency, rate ofchange of frequency

• Volts/Hz Status: volts per hertz

• Power Status: real power, reactive power,apparent power, power factor

• Impedance Status: impedance (Zab, Zbc,Zca), positive sequence impedance, fieldground resistance

• Sync Check Status: 25S Sync Checkand 25D Dead Volt

• BRKR Monitor

• 81A Accum. Status

• IN/OUT Status: Status of input and outputcontacts

• Timer: 51V Delay Timer, 51N Delay Timer,46IT Delay Timer, 24IT Delay Timer

• Relay Temperature

• Counters: output, alarm counter

• Time of Last Power up

• Error Codes

• Checksums: setpoints, calibration, ROM


3–10

3.6 Target History

The M-3425A Generator Protection Relay includesthe ability to store the last 32 target conditions in anonvolatile memory. A target is triggered wheneveran output is operated. A second function attemptingto operate an output (which is already operated) willnot trigger a new target, since no new output hasbeen operated or closed. If the second functionoperation closes a different, unoperated output, anew target will be triggered. A target includes:

• an indication which function(s) haveoperated, and timers expired (operated),

• status information which indicates anyfunction that is timing (picked up),

• individual phase element information atthe time of the trigger, if the operatingfunction was a three phase function,

• phase currents at the time of operation

• neutral current at the time of operation,

• input and output status, and

• a date/time tag.

When a target is triggered, the front panel TARGETLED will light, indicating a recent event. If theoptional M-3925A Target Module is present, thecorresponding function LED will be lit. If the optionalM-3931 HMI module is available, a series of screenswill be presented, describing the most recentoperation. This information is also available remotelyby using the IPScom® Communication Software.

To access the TARGET HISTORY menu performthe following:

1. Press the ENTER pushbutton to accessthe main menu.

2. Press the right arrow pushbutton untilTARGET HISTORY is displayed on thetop line of the screen.

To view Target History records proceed as follows:

1. Ensure that the View Target HistoryMenu is selected to TRGT (upper case).

VIEW TARGET HISTORYTRGT clear

If TRGT is not selected (Upper Case),then use the Right/Left arrow pushbuttonsto select TRGT.

2. Press ENTER, the following will bedisplayed:

VIEW TARGET HISTORY1 Target number

Detailed descriptions for each View TargetHistory screen are presented on thefollowing page.

Operation – 3

3–11

TARGET 1PHASE A=X B=X C=X

TARGET 1-CURRENT STATUS-

TARGET 1a=0.02 b=0.03 c=0.04

TARGET 1N=0.50 AMPS

This display gives the phase pickup information for the specificfunction.

This screen displays the phase current at the time the targetoperated.

This screen displays the neutral current at the time the targetoperated.

VIEW TARGET HISTORYTRGT clear

VIEW TARGET HISTORY 1 Target number

TARGET 101-JAN-2001 12:27:35.125

TARGET 108 05 01

TARGET 1I3 I1

TARGET 1-OPERATE TARGETS-

TARGET 127#1 PHASE UNDERVOLTAGE

TARGET 1PHASE A=X B= C=

TARGET 1-PICKUP TARGETS-

TARGET 127#1 PHASE UNDERVOLTAGE

This screen gives access to the target history, and also allowsthe user to clear the target history record from memory.

Using up and down buttons, user may select which particulartarget to view from the last 24 recorded triggers.

This screen gives the date and time tag of the selected target.

This screen displays operated outputs.

This screen displays operated inputs at time of trip.

The following screens display the timed out or “operate” func-tions.

This screen displays the specific function which timed out andtriggered the target.

This screen displays the phase information for the displayedfunction at time out.

The following screens display the timing on “picked up” func-tions when the target was recorded.


3–12


1

3

A

B

C

4–1

Remote Operation – 4

4Remote Operation

4.1 Remote Operation ...................................................................... 4–1

4.2 Installation and Setup (IPScom®) ............................................. 4–8

4.3 Operation .................................................................................... 4–8

4.4 Checkout Status/Metering (Windows) ..................................... 4–22

4.5 Cautions .................................................................................... 4–27

4.6 Keyboard Shortcuts ................................................................. 4–28

4.7 IPSutil™ Communications Software ........................................ 4–29

This chapter is designed for the person or groupresponsible for the remote operation and setting ofthe relay using the M-3820D IPScomCommunications Software or other means.

4.1 Remote Operation

The M-3425A Generator Protection Relay providesthree serial communication ports and one ethernetport.

Serial Ports (RS-232)Two serial interface ports, COM1 and COM2, arestandard 9-pin, RS-232, DTE-configured ports. Thefront-panel port, COM1, can be used to locally setand interrogate the relay using a temporaryconnection to a PC or laptop computer. The secondRS-232 port, COM2, is provided at the rear of theunit. COM2 is unavailable for communications whenthe optional ethernet port is enabled. Thedemodulated IRIG-B may still be used via the COM2Port when ethernet is enabled.

The individual addressing capability of IPScom andthe relay allows multiple systems to share a director modem connection when connected throughCOM2 using a communications-line splitter (seeFigure 4-1). One such device enables 2 to 6 units toshare one communications line. Appendix B, FigureB-2 illustrates a setup of RS-232 Fiber Optic network.

Serial Port (RS-485)COM3 located on the rear terminal block of theM-3425A is an RS-485, 2-wire connection. AppendixB, Figure B-3 illustrates a 2-wire RS-485 network.

Individual remote addressing also allows forcommunications through a serial multidrop network.Up to 32 relays can be connected using the same2-wire RS-485 communications line.

Optional Ethernet PortThe M-3425A when equipped with the optionalEthernet Port can be accessed from a local network.When the ethernet port is enabled the COM2 serialport (RS-232) is unavailable for communications.Although the ethernet connection speed is fasterthan the RS-232 port (can be up to 10 Mbps), theethernet module connects internally through theCOM2 serial connection and is therefore limited toconnection speeds up to 9600 bps.

Either COM2, COM3 or Ethernet port may be used toremotely set and interrogate the relay using a localarea network, modem or other direct serial connection.Equipment such as RTU’s, data concentrators,modems, or computers can be interfaced for direct,on-line, real time data acquisition and control.Generally, all data available to the operator throughthe front panel of the relay with the optional M-3931HMI module is accessible remotely through the BECO2200, MODBUS, BECO 2200 over TCP/IP orMODBUS over TCP/IP data exchange protocols.

1

3

A

B

C


4–2

The communication protocols are used to fulfill thefollowing communications functions:

• Real-time monitoring of line status


• Downloading of recorded oscillograph data

• Reconfiguration of all relay functions

Protocol documents are available directly fromBeckwith Electric or from our websitewww.beckwithelectric.com.

Direct ConnectionIn order for IPScom to communicate with the relayusing direct serial connection, a serial “null modem”cable is required, with a 9-pin connector (DB9P) forthe system, and an applicable connector for thecomputer (usually DB9S or DB25S). Pin-outs for anull modem adapter are provided in Appendix B,Communications.

An optional 10 foot null modem cable (M-0423) isavailable from the factory, for direct connectionbetween a PC and the relay’s front panel COM port,or the rear COM2 port.

When fabricating communication cables, every effortshould be made to keep cabling as short as possible.Low capacitance cable is recommended. The RS-232standard specifies a maximum cable length of 50feet for RS-232 connections. If over 50 feet of cablelength is required, other technologies should beinvestigated.

Other communication topologies are possible usingthe M-3425A Generator Protection Relay. AnApplication Note, “Serial Communication withBeckwith Electric’s Integrated Protection SystemRelays” is available from the factory or from ourwebsite at www.beckwithelectric.com.

Communications-Line Splitter

Up to six controlscan be used with a

communications-line splitter.Address 2

Address 4

Address 5

Address 6

Address 3Address 1

IBM-Compatible PC

Integrated ProtectionSystem

Null Modem Cable forDirect RS-232 Connection

Master Port

Figure 4-1 Multiple Systems Addressing Using Communications-Line Splitter

1

3

A

B

C

4–3


Communication Access Code: If additional linksecurity is desired, a communication access codecan be programmed. Like the user access codes, ifthe communication access code is set to 9999(default), communication security is disabled.

Individual relay communication addresses shouldbe between 1 and 200. The dead sync time, whilenot critical for most communication networks, shouldbe programmed to match the communicationschannels baud rate (see Table 4-1, below).

etaRduaB emiTcnyS-daeD

0069 sm4

0084 sm8

0042 sm61

0021 sm23

Table 4-1 Dead-Sync Time

Ethernet Communication SettingsThe RJ45 ethernet port can be enabled utilizingeither IPSutil™ from the Ethernet Settings menu orfrom the HMI Communication menu. When theethernet port is enabled the COM2 Serial Port is notavailable for communications. The demodulatedIRIG-B may still be used via the COM2 Port whenethernet is enabled.

The following parameters must be set for properethernet communication:

DHCP Protocol

ENABLE: If the network server supports the DHCPprotocol the network server will assign the IPAddress, Net Mask and Gateway Address.

DISABLE: If the network server does not supportthe DHCP protocol or the user chooses to manuallyinput ethernet settings, then obtain the IP Address,Net Mask and Gateway address from the NetworkAdministrator and enter the settings.

ETHERNET ProtocolsSERCONV:To utilize the BECO2200 protocol overa TCP/IP connection select the SERCONV(BECO2200 TCP/IP) protocol. The IP Address ofthe relay must be entered in the IPScomCommunication screen. Also, ensure that the COM2protocol is selected to BECO2200 and the baudrate is set to 9600 bps.

Setting Up the M-3425A Generator ProtectionRelay for CommunicationThe initial setup of the relay for communicationmust be completed by utilizing the optional M-3931HMI Module or using direct serial connection.

For units shipped without the optional HMI Module,the communication parameters may be altered byfirst establishing communication using the defaultparameters and the IPSutil™ program.

IPSutil is an auxiliary program shipped on the samedisk with the IPScom® program. It is used exclusivelyfor altering communication and setup parameters onunits shipped without the M-3931 HMI Module.

Serial Communication SettingsThe following parameters must be set for properserial communication:

COM1 Baud Rate: Standard baud rates from 300 to9600 are available.

COM2 Baud Rate: Standard baud rates from 300 to9600 are available. COM2 and COM3 share thesame baud rate (see Section 5.5, Circuit BoardSwitches and Jumpers).

COM2 Dead Sync Time: This delay establishesthe line idle time to re-sync packet communication.Dead sync time should be programmed based onthe channel’s baud rate.

COM2 Protocol: BECO 2200 or MODBUS protocolis supported on COM2.

COM2 Parity: None, odd or even parity is availableif MODBUS protocol is selected.

COM2 Stop Bits: One or two stop bits available ifMODBUS protocol is selected.

COM3 Dead Sync Time: This delay establishesthe line idle time to re-sync packet communication.Dead sync time should be programmed based onthe channel’s baud rate.

COM3 Protocol: BECO 2200 or MODBUS protocolis supported on COM3.

COM3 Parity: None, odd or even parity is availableif MODBUS protocol is selected.

COM3 Stop Bits: One or two stop bits available ifMODBUS protocol is selected.

Communications Address: For multidrop networks,each device must have a unique address.

Response Time Delay: The extra time delay maybe added while the relay is sending the response. Ifset to 0, the response of the relay will be equal tothe time required to process the incoming packet(usually 20–80 ms.)

1

3

A

B

C


4–4

6. Ensure that TCP is selected (Upper Case).

If TCP is not selected (Upper Case), thenuse the Right/Left arrow pushbuttons toselect TCP.


DHCP PROTOCOLDISABLE enable

8. If the network does not support the DHCPprotocol, then go to Manual Configurationof Ethernet Board (following page) tomanually configure the ethernet board.

9. If the DHCP Protocol is to be enabled, thenuse the Right/Left arrow pushbutton to selectENABLE (Upper Case), then press ENTER,the following will be displayed:

TCP/IP SETTINGSTCP prot

10. Ensure that PROT is selected (Upper Case).

If PROT is not selected (Upper Case), thenuse the Right arrow pushbutton to selectPROT.


SELECT PROTOCOLmodbus serconv

12. Use the Right/Left arrow pushbuttons toselect the desired protocol (Upper Case),then press ENTER, the following will bedisplayed:

TCP/IP SETTINGStcp PROT

13. Press EXIT, the ethernet board willreconfigure and the following will bedisplayed:

CONFIGURING ETH...

If the ethernet board successfully obtainsan IP Address the following will be displayedfor approximately 2 seconds:

ETHERNET IP ADDRESSXX.XX.XX.XX

The ethernet board is now configured foruse and may be accessed through anetwork.

The Standard Port Number for the BECO2200 overTCP/IP protocol is 8800. The master device mayrequire the entry of the Standard Port Number.

MODBUS:To utilize the MODBUS protocol over aTCP/IP connection select the MODBUS (MODBUSover TCP/IP) protocol. The IP Address of the relaymust be entered in the IPScom® Communicationscreen. Also, ensure that the COM2 protocol isselected to MODBUS, baud rate is set to 9600 bps,1 stop bit and no parity selected.

The Standard Port Number for the MODBUS overTCP/IP protocol is 502. The master device mayrequire the entry of the Standard Port Number.

Ethernet Port SetupEnabling the ethernet port and selecting the requiredsupport settings can be accomplished using eitherthe HMI or IPSutil™. Both methods are presentedbelow.

HMI Ethernet Port Setup1. Ensure that the Communication Menu is

selected to COMM (upper case).

COMMUNICATION targets osc_rec COMM

If COMM is not selected (Upper Case),then use the Right/Left arrow pushbuttonsto select COMM.


COM1 SETUPCOM1 com2 com3 com_adr

3. Use the Right arrow pushbutton to selectETH (Upper Case).

ETHERNET SETUP access ETH eth_ip


ETHERNETDISABLE enable

5. Use the Right arrow pushbutton to selectENABLE (Upper Case), then press ENTER,the following will be displayed:

TCP/IP SETTINGSTCP prot

1

3

A

B

C

4–5


8. Use the Right/Left arrow pushbuttons toselect the desired protocol (Upper Case),then press ENTER, the following will bedisplayed:

TCP/IP SETTINGStcp PROT

9. Press EXIT, the ethernet board willreconfigure and the following will bedisplayed:

CONFIGURING ETH...

If the ethernet board is successfullyconfigured, then the entered IP Addresswill be displayed for approximately 2seconds:

ETHERNET IP ADDRESSXX.XX.XX.XX

The ethernet board is now configured foruse and may be accessed through anetwork.

IPSutilTM Ethernet Port Setup with DHCP1. Connect the appropriate RS232 cable from

the PC hosting IPSutil to the target relay.

2. Launch IPSutil, then select Ethernet fromthe menu bar. IPSutil will display the EthernetSettings screen Figure 4-43.

3. From the Ethernet Settings screen selectEthernet Enable.

4. Select DHCP Protocol Enable.

5. Select the desired protocol.

6. Select Save, IPSutil will respond with theAdvance Setup dialog box stating “It willtake about 15 seconds to reset Ethernetboard to allow the menu of the unit toreflect the change.”

7. Select OK, IPSutil will configure the ethernetboard, then close the Ethernet Settingsscreen. The ethernet board is nowconfigured for use and may be accessedthrough a network.

IPSutilTM Ethernet Port Setup without DHCP1. Connect the appropriate RS232 cable from

the PC hosting IPSutil to the target relay.

2. Launch IPSutil, then select Ethernet fromthe menu bar. IPSutil will display the EthernetSettings screen Figure 4-43.

Then the display will return to the following:

ETHERNET SETUP

access ETH eth_ip

If the ethernet board fails to obtain an IPAddress within 15 seconds the followingwill be displayed (for approximately 2seconds):

CONFIGURING ETH...

ETH BOARD ERROR

Contact the Network Administrator todetermine the cause of the configurationfailure.

Manual Configuration of Ethernet Board1. Ensure that DISABLE is selected (Upper

Case).

If DISABLE is not selected (Upper Case),then use the Left arrow pushbutton to selectDISABLE.


IP ADDRESSXX.XX.XX.XX

3. Enter the desired IP Address, then pressENTER, the following will be displayed:

NET MASKXX.XX.XX.XX

4. Enter the desired Net Mask, then pressENTER, the following will be displayed:

GATEWAYXX.XX.XX.XX

5. Enter the desired Gateway, then pressENTER, the following will be displayed:

TCP/IP SETTINGStcp prot

6. Ensure that PROT is selected (Upper Case).

If PROT is not selected (Upper Case), thenuse the Right arrow pushbutton to selectPROT.


SELECT PROTOCOLmodbus serconv

1

3

A

B

C


4–6

Figure 4-2 IPScom® Menu Selections

■ NOTE: Greyed-out menu items are for future release, and are not currently available.

Comm

Window

NewOpen...Close

SaveSave As...

Print

Printer Setup

Print Summary

Exit Alt+F4

Cascade

Tile

Arrange Icons

Close All

Choosing the Comm menu sends youdirectly to the Communication dialog box.

Help

ContentsUsing Help

About...

Profile Info

HelpCommFile Relay WindowIPScom

User Logo Lines/ Unit Identifier

Unit Address

Relay TypeFile

Setup System

Setpoints

Set Date/Time

Display

Reset LED

Clear History

A:1 M-3425

Primary Status

Secondary Status

Accumulator Status

Phase Distance

Loss of Field

Out of Step

Phasor Diagram

Sync Scope

Function Status

Switching Method

Active Profile

Copy Profile

Setup

Retrieve

Trigger

Clear

Relay

Setup

Retrieve

View

Clear

1

3

A

B

C

4–7


3. From the Ethernet Settings screen selectEthernet Enable.

4. Select DHCP Protocol Disable.

5. Enter values for IP Address, Net Mask andGateway.

6. Select the desired protocol.

7. Select Save, IPSutil will respond with theAdvance Setup dialog box stating “It willtake about 15 seconds to reset Ethernetboard to allow the menu of the unit toreflect the change.”

8. Select OK, IPSutil will configure the ethernetboard, then close the Ethernet Settingsscreen. The ethernet board is nowconfigured for use and may be accessedthrough a network.

Installing the ModemsUsing IPScom to interrogate, set or monitor therelay using a modem requires both a remote modemconnected at the relay location and a local modemconnected to the computer with IPScom installed.

In order to use IPScom to communicate with therelay using a modem, the following must be providedwith the unit:

• An external modem (1200 baud or higher),capable of understanding standard ATcommands.

• Serial modem cable with 9-pin connectorfor the unit and the applicable connectorfor the modem.

■ NOTE: Any compatible modem may be used;however, the unit only communicates at1200 to 9600 baud.

Similarly, the computer running IPScom must alsohave access to an internal or external compatiblemodem.

The local modem can be initialized, using IPScom,by connecting the modem to the computer, andselecting the COMM menu in IPScom. SelectMODEM, enter the required information, and finallyselect INITIALIZE from the expandedCommunications dialog box. The following stepsoutline the initialized modem setup procedure.

1. Connecting the modem to the computer:a. If the computer has an external modem,

use a standard straight-through RS-232modem cable to connect the computerand modem (M-3933). If the computerhas an internal modem, refer to themodem’s instruction book to determinewhich communications port should beselected.

b. The modem must be attached to (ifexternal) or assigned to (if internal) thesame serial port as assigned in IPScom.While IPScom can use any of the fourserial ports (COM1 through COM4),most computers support only COM1and COM2.

c. Connect the modem to the telephoneline and power up.

2. Connecting the Modem to the Relay:Setup of the modem attached to the relaymay be slightly complicated. It involvesprogramming the parameters (using the ATcommand set), and storing this profile inthe modem’s nonvolatile memory.

After programming, the modem will powerup in the proper state for communicatingwith the relay. Programming may beaccomplished by using “Hyperterminal” orother terminal software. Refer to your modemmanual for further information.

■■■■■ NOTE: The relay does not issue or understandany modem commands. It will not adjustthe baud rate and should be considereda “dumb” peripheral. It communicateswith 1 start, 8 data, and 1 stop bit.

a. Connect the unit to an external modemby attaching a standard RS-232 modemcable to the appropriate serialcommunications port on both the unitand the modem.

b. Connect the modem to the telephoneline and power up.

The modem attached to the unit must have thefollowing AT command configuration:

E0 No EchoQ1 Don’t return result code&D3 On to OFF DTR, hang-up and reset&S0 DSR always on&C1 DCD ON when detectedS0=2 Answer on second ring

The following commands may also be required atthe modem:

&Q6 Constant DTE to DCEN0 Answer only at specified speedW Disable serial data rate adjust\Q3 Bi-directional RTS/CTS relay&B1 Fixed serial port rateS37 Desired line connection speed

There are some variations in the AT commandssupported by modem manufacturers. Refer to thehardware user documentation for a list of supportedAT commands and direction on issuing thesecommands.

1

3

A

B

C


4–8

4.2 Installation and Setup (IPScom)

IPScom runs with the Microsoft Windows® 95operating system or later. IPScom® only supportscommunication using the BECO 2200 protocol.

IPScom is available on CD-ROM, or it my bedownloaded from our website atwww.beckwithelectric.com

The M-3820D IPScom Communications Softwarepackage is not copy-protected and can be copied toa hard disk. For more information on your specificrights and responsibilities, see the licensingagreement enclosed with your software or contactBeckwith Electric.

Hardware RequirementsIPScom will run on any IBM PC-compatible computerthat provides at least the following:

• 8 MB of RAM

• Microsoft Windows 95 or later

• CD-ROM drive

• one serial (RS-232) communication port

• pointing device (mouse)

Installing IPScom1. Insert software CD-ROM into your drive.

An Auto-Install program will establish aprogram folder (Becoware) and subdirectory(IPScom). After installation, the IPScomprogram item icon (see Figure 4-3) islocated in Becoware. The default locationfor the application files is on drive C:, in thenew subdirectory “IPScom”(C:\Becoware\Ipscom).

2. If the Auto-Install program does not launchwhen the CD-ROM is inserted into the drivethen proceed as follows:

a. Select Run from the Start Menu.b. In the Run dialog box, locate the

installation file contained on theinstallation disk(sfi_m3425Acom_V______.exe).

c. Select Run to start the installationprocess.

Figure 4-3 IPScom Program Icon

Installing IPSutil™IPSutil is utility software used to program system-level parameters for units shipped without the M-3931HMI Module. The IPSutil.exe file is automaticallyinstalled in the Becoware folder, along with theIPScom files, and does not require separateinstallation.

4.3 Operation

Activating CommunicationsAfter the relay has been set up, the modemsinitialized, and IPScom installed, communication isactivated as follows:

1. Choose the IPScom icon from theBecoware folder.

2. The IPScom splash screen is displayedbriefly, providing the software versionnumber and copyright information. Thisinformation is also available by choosingthe About... command from the Help menu.

3. Choose the COMM menu selection.Complete the appropriate information onthe window for the relay to be addressed.a. If communication is through a modem,

choose the Modem command buttonto expand the communications dialogbox. Choose the desired relay locationand choose Dial button. This actionestablishes contact and automaticallyopens communication to the relay.

b. If computer is connected through thefront port, choose the Open COMbutton. This action establishescommunications.

4. Enter any valid IPScom command(s) asdesired.

5. To end communication whencommunicating by modem, choose the HangUp command button from the expandedCommunication dialog box. To close thecommunication channel when connectedlocally, choose the Close COM commandbutton.

OverviewWhen IPScom® is run, a menu and status bar isdisplayed, as shown in Figure 4-2. This sectiondescribes each IPScom menu selection and explainseach IPScom command in the same order as theyare displayed in the software program. For detailedinformation regarding each dialog box field (function),refer to Chapter 2, Application.

1

3

A

B

C

4–9


When starting IPScom, the initial menu choices arethe File menu or the Comm menu. The choicespecifies whether the operator desires to write to adata file or to communicate directly with the relay.

File Menu

File

New

Open...

Close

Save

Save As...

Print

Printer Setup

Exit Alt+F4

The File menu enables the user to create a newdata file, open a previously created data file, close,print, and save the file. The IPScom program canalso be exited through the File menu.

Since IPScom can be used with several Beckwithprotection systems in addition to the M-3425AGenerator Protection Relay, the format and contentsof a file must be established depending on whichprotective system is being addressed. When notconnected to one of the protection systems, usingthe New command, a new file is established withthe System Type dialog box (see Figure 4-4). Choicesfor Unit Type in the System Type Screen includeM-3425, M-3425A, M-3425A(SOE) and M-3425AExpanded I/O. The selected Unit Type ensures thatthe “New” file is consistant with the protective systemfirmware version (Table 4-2). Choosing the OKcommand button allows the new data file to beopened. Selecting Save or Save As commandsallows the file to be named and saved.

■■■■■ NOTE: By choosing the NEW command, unitand setpoint configuration values arebased on factory settings specified forthe profiled protection system.

��

��

� ��

��

��

� �!" # �!"

$�% ��%

%&� %�&

'(

��

Figure 4-4 System Type Dialog Box

Path: File menu / New command

COMMAND BUTTONS

OK Allows the selected Unit Type File to beopened.

Cancel Returns you to the IPScom main screen;any changes to the displayedinformation is lost.

The Save and Save As... commands allow re-saving a file or renaming a file, respectively. TheOpen command allows opening a previously createddata file. With an opened data file, use the Relay...Setup... menu items to access the setpointwindows.

If communication can be established with a relay, itis always safer to use the Read Data From Relaycommand to update the PC’s data file with therelay data. This file now contains the proper systemtype information, eliminating the need to set theinformation manually.

The Print and Printer Setup commands allow userto select printer options and print out all setpointdata from the data file or directly from the relay, if arelay is communicating with the PC.

The Exit command quits the IPScom program.

Comm Menu

HelpWindowFile RelayComm

The Communication dialog box (see Figure 4-5)allows setup of the IPScom communication data tocoordinate with the relay and by choosing theModem button, to establish contact for remotelocations. When communicating by way of a fiberoptic loop network, echo cancelling is available bychecking the Echo Cancel box. This commandmasks the sender’s returned echo.

If the modem was not used to establishcommunication (direct connection), press the OpenCOM button to start. If the relay has a defaultcommunication access code of 9999, a messagewindow will be displayed showing Access Level #3was granted. Otherwise, another dialog box willappear to prompt the user to enter the access codein order to establish the communication. CloseCOM discontinues communication.

Protective System Unit Type Firmware Version

M-3425 D-0070XXX.XX.XX

M-3425A D-0114XXX.XX.XX

M-3425A (SOE) D-0150XXX.XX.XX

M-3425A Expanded I/O D-0150XXX.XX.XX

Table 4-2 Protective System FirmwareAssociation

1

3

A

B

C


4–10

��

'��')

�� ')

) ��

��

%��

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+��

��,

) �� &��-�� -��.��

�� /��

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$0

12

01

3#

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Figure 4-5 Communication Dialog Box

Path: Comm menu

COMMAND BUTTONS

Open COM Initiates contact withthe protectivesystem, either by direct serial or modemcommunication.

Close COM Breaks communication with theprotective system, for both direct serialor modem communication.

TCP_IP Opens the ethernet applicablecommunication screen selections toallow user to enter a TCP_IP address (ifnecessary), and opening and closingcommunication with the target relay.

Modem Displays the expanded Communicationdialog box.

Cancel Returns you to the IPScom main window;any changes to the displayedinformation are lost.

Open TCP_IP Initiates contact with the protectivesystem by ethernet connection.

Close TCP_IP Closes Ethernet connection.

Bring Up When selected, following connection toTerminal the target modem, allows the user toWindow send commands to the modem.AfterDialing

Add Displays the Add/Edit dialog box,allowing you to type a protectivesystem’s unit identifier, phone number,and communication address.

Edit Displays the Add/Edit dialog box,allowing you to review and change theuser lines (unit identifier), phonenumber, and communication address ofa selected entry.

Delete Deletes a selected entry.

Save Saves any changes to the displayedinformation

Initialize Allows the user to send special setup orother AT commands directly to themodem.

Dial Dials the entry selected from thedirectory.

Hang Up Ends modem communication, allowingthe user to dial again.

Relay Menu

Relay

Setup

Monitor

Target

Sequence of Events

Oscillograph

Profile

Write File to Relay

Read Data From Relay

The Relay menu provides access to the windowsused to set, monitor, or interrogate the relay. Sixsubmenus are provided: Setup, Monitor, Target ,Sequence of Events, Oscillograph

and Profile

as well as two commands, Write File to Relay, andRead Data From Relay.

Relay

Setup

Monitor

Target

Sequence of Events

Oscillograph

Profile

Write File to Relay


Setup System

Setpoints

Set Date and Time

The Setup submenu provides three commands:Setup System, Setpoints, and Set Date/Time.The Setup System command displays the SetupSystem dialog box (Figure 4-6) allowing the input ofthe pertinent information regarding the system onwhich the protective relay is applied (see Section2.1, Configuration, Relay System Setup).

1

3

A

B

C

4–11


SETUP SYSTEM

Note: Pulse/Latched Relay Outputs should be selected in 2 stepsi)Deselect Latched/Pulse Relay Outputs and Saveii) Select Pulse/Latched Outputs and Save

Nominal Frequency: 60 Hz C.T. Secondary Rating: 5A

Input Active State Expanded

Save Cancel

Nominal Voltage: 120

Nominal Current: 5.00

140.0 V50.0 V

6.00 A0.50 A

Delta-Y Transform

Disable Delta-AB Delta-AC

OpenClose

OpenClose

OpenClose

OpenClose

OpenClose

6 5 4 3 2 1OpenClose

Input Active State:

1 .0

1.0

1.0

10

10

V.T. Configuration:

59/27 Mag. Select:

Phase Rotation:

V.T. Phase Ratio:

V.T. Neutral Ratio:

V.T. VX Ratio

C.T. Phase Ratio:

C.T. Neutral Ratio:

Outputs: 1 2 3 4 5 6 7 8Pulse Relay

Injection Frequency for F64S: 20 Hz

L ine to Ground L ine to L ine L ine-Ground to L ine-L ine

RMS DFT

ABC ACB

50DTSplit PhaseDifferential:

Enable

Disable

Outputs: 1 2 3 4 5 6 7 8Latched Outputs



Relay Seal-In Time

OUT 1:

2:

3:

4:

5:

6:

7:

8:

30

30

30

30

30

30

30

302cycles

8160cycles

8160cycles

OUT 9:

10:

11:

12:

13:

14:

15:

16:

30

30

30

30

30

30

30

302cycles

OUT 17

18

19

20

21

22

23

30

30

30

30

30

30

30

Relay Seal-In Time Expanded

SETUP

:1

:1

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1.0

1.0

1.0

1

1

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6550.0

6550.0

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Figure 4-6 Setup System Dialog Box

Path: Relay menu / Setup submenu / Setup System command

COMMAND BUTTONS

Input Active When the unit is equipped with expanded I/O, this command opens the Expanded Input ActiveState State screen (Figure 4-7), to allow the selection of Expanded Inputs 7 through 14.Expanded

Pulse/Latch When the unit is equipped with expanded I/O, this command opens the Pulse/LatchRelay screen (Figures 4-8 and 4-9) to allow the selection of expanded outputs 9 through 23.ExpandedOutputs

Save When connected to a protection system, sends the currently displayed information to the unit.Otherwise, saves the currently displayed information.

Cancel Returns you to the IPScom® main window; any changes to the displayed information are lost.

■■■■■ NOTE: Checking the inputs for the Active Input Open parameter designates the “operated” state established byan opening rather than a closing external contact.

1

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OUTPUT9

OUTPUT10

OUTPUT11

OUTPUT12

OUTPUT13

OUTPUT14

OUTPUT15

OUTPUT16

OUTPUT17

OUTPUT18

OUTPUT19

OUTPUT20

OUTPUT21

OUTPUT22

OUTPUT23

OK

Cancel

Figure 4-8 Pulse Relay Expanded Output Screen

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The Setpoints command displays the RelaySetpoints dialog box (see Figure 4-10) from whichthe individual relay function dialog boxes can beaccessed. Choosing a Relay function button willdisplay the corresponding function dialog box (seeFigure 4-11 for example).

M3425A Relay Setpoints X

ConfigureExit

21

Phase Distance

24

Volts/Hz

25

Sync Check

27TNThird Harmonic

Overvoltage

49

Stator Overload

50BF

Breaker Failure

50Instan. Phase

Overcurr.

50NInstan. Neutral

Overcurrent

59Phase

Overvoltage

59DThird Harmonic

Voltage Diff.

59NNeutral

Overvoltage

59X

MultipurposeOvervoltage

78

Out of Step

87Phase Differential

Current27Phase

Undervoltage

32

Directional Power

40

Loss of Field

46Neg. Seq.

Overcurrent

50DTDefinite TimeOvercurrent

50/27InadvertentEnergizing

51NInv. Time Neu.Overcurrent

51VInv. Time

Overcurrent

60FLVT Fuse-Loss

Detection

67NResidual Dir.Overcurrent

64S100% Stator

Ground

64F/BField Ground

Protection

87GDGround

Differential

BM

Breaker Monitor

TCTrip Circuit

Monitor

FUNCTIONS FUNCTIONS

21 -- 51V 59 -- TC

81Frequency

81AFreq. Accum.

81R

ROCOF

IPSIPS Logic

OUTPUTS 1-8INPUTS 1-FL

Configure

OUTPUTS 9-23INPUTS 7-14

Figure 4-10 Relay Setpoints Dialog Box

Path: Relay menu / Setup submenu / Setpoints window

COMMAND BUTTONS

Functions Opens the All Setpoints Table dialog boxfor the specified range of functions.

Configure Opens the Configure dialog box.

Exit Saves the currently displayedinformation and returns you to theIPScom® main window.

The Relay Setpoints dialog box gives access to twoadditional dialog boxes: All Setpoints Table andConfigure.

Choosing either of the Functions command buttons(either 21–51V or 59–TC) displays an All SetpointsTable dialog box for the specified range of setpoints(see Fig. 4-13). This dialog box contains a list ofsettings for each relay within a single window toallow scrolling through all relay setpoint configurationvalues. Choosing the Configure command buttondisplays the Configure dialog box (see Fig. 4-14),which contains a chart of programmed input andoutput contacts, in order to allow scrolling throughall relay output and blocking input configurations.Both dialog boxes (All Setpoint Table and Configure),

feature hotspots which allows the user to jump froma scrolling dialog box to an individual relay functiondialog box and return to the scrolling dialog boxagain. All available parameters can be reviewed orchanged when jumping to a relay configuration dialogbox from either scrolling dialog box.

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Figure 4-11 Typical Setpoint Dialog Box

Path: Relay menu / Setup submenu / Setpoints window/ 46command button OR 46 jump hotspot within All SetpointsTable or Configure dialog box

COMMAND BUTTONS

Save When connected to a protection system,sends the currently displayedinformation to the unit. Otherwise, savesthe currently displayed information andreturns you to the Relay Setpoints, AllSetpoints Table, or Configure dialogbox.

Cancel Returns the user to the Relay Setpoints,All Setpoints Table, or Configure dialogbox; any changes to the displayedinformation are lost.

Expanded When the unit is equipped with expandedI/O’s I/O, this selection allows the user to select

expanded outputs 9–23 and expandedinputs 7–14.

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1

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4–14

All Setpoints Table

SETUP SYSTEM

Nominal Voltage:Nominal Current:

Nominal Frequency:Phase Rotation:

C.T. Secondary Rating:59/27 Mag. Select:Delta-Y Transform:

Latch Relay Outputs:

F64S Frequency:V.T. Configuration:V.T. Phase Ratio:

V.T. Neutral Ratio:V.T. VX Ratio:

C.T. Phase Ratio:C.T. Neutral Ratio50DT Split Phase:

Fuse Relay Outputs:

OUT1:OUT2:OUT3:OUT4:

OUT5:OUT6:OUT7:OUT8:

Seal-In Time (Cycles)

Circle Diameter:Offset:

Impedance Angle:Load Encr. Angle:

Load R Reach:Delay:

Out of Step Delay:Overcurrent SV:

Out of Step Block En:Load Encr. En:

OC Supervision En:



Load R Reach:Delay:

Overcurrent SV:Out of Step Block En:

Load Encr. En:OC Supervision En:



Load R Reach:Delay:

Overcurrent SV:Out of Step Block En:

Load Encr. En:OC Supervision En:

(21)- PHASE DISTANCE

(24)- VOLTS/HZ

Pickup #1:

Delay #1:

Pickup #2:

Delay #2:

Definite Time Inverse Time

Pickup:

Time Dial:

Curves #:

Reset Rate:

(25)- SYNC CHECKPh. Ang. Window:

Upper Volt. Limit:

Lower Volt Limit:

Sync Check Delay:

Delta Voltage:

Delta Frequency:

25S Sync Check:

25S 25D

Dead Volt Limit:

Dead V1 Hot V2:

Hot V1 Dead V2:

Dead V1 Dead V2:

Dead Delay:

Input Initiate:

(27)- PHASE UNDERVOLTAGE

Pickup #1:

Delay #1:

Pickup #2:

Delay #2:

Pickup:

Pos. Seq. Volt. Block:



Lead VAR Block:

(27TN)- UNDERVOLTAGE, NEUTRAL

Pickup:

Pos. Seq. Volt. Block:



Lead VAR Block:

X

Seal-In Time Expanded

OUT9-15:



Figure 4-13 All Setpoints Table Dialog Box (partial)

Path: Relay menu / Setup submenu / Setpoints window/ Display All command button

JUMP HOTSPOTS

This window provides you with jump hotspots, identified by the hand icon, that take you to each relay dialog box andthe Setup Relay dialog box. Exiting any of these dialog boxes will return you to the All Setpoints Table dialog box.

CONTROL MENU

Close Returns you to the Relay Setpoints dialog box.

Move Allows you to reposition the dialog box.

1

3

A

B

C

4–15


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#1#2

#1#2#3

#1

#2#3

#1#2

VC#1

VC#2

Def. TimeInv. Time

#1#2

#1

#2

Def. Time #1Def. Time #2Inverse Time

XConfigure

O U T P U T S

8 7 6 5 4 3 2 1

Blocking Inputs

FL 6 5 4 3 2 1

25

24

21#1#2#3

27TN

27

32

40

50BF

46

50DT

50N

50

Figure 4-14 Configure Dialog Box (partial)

Path: Relay menu / Setup submenu / Setpoints window/ Configure command button

JUMP HOTSPOTS

This window provides you with jump hotspots, identified by the hand icon, that take you to each relay dialog box.Exiting any of these dialog boxes will return you to the Configure dialog box.

CONTROL MENU



1

3

A

B

C


4–16

SyncDead

#1#2

#1#2#3

#1

#2#3

#1#2

VC#1

VC#2

Def. TimeInv. Time

#1#2

#1

#2

Def. Time #1Def. Time #2Inverse Time

Configure

E x p a n d e d O U T P U T S

23 22 21 20 19 18 17

Expanded Blocking Inputs

14 13 12 11 10 9 8 7

25

24

21#1#2#3

27TN

27

32

40

50BF

46

50DT

50N

50

16 15 14 13 12 11 10 9

X

Figure 4-15 Configure Dialog Partial (Shown with Expanded Input/Outputs)

Path: Relay menu / Setup submenu / Setpoints window/ Configure command button

JUMP HOTSPOTS

This window provides you with jump hotspots, identified by the hand icon, that take you to each relay dialog box.Exiting any of these dialog boxes will return you to the Configure dialog box.

CONTROL MENU



1

3

A

B

C

4–17


The Set Date/Time command (see Figure 4-16)allows the system date and time to be set, orsystem clock to be stopped. This dialog box alsodisplays an LED mimic to identify when the TimeSync is in use (preventing date/time from beingchanged by user).

Figure 4-16 Unit Date/Time Dialog Box

Path: Relay menu/ Setup submenu/ Set Date/TimeCommand

There is a blue Time Sync LED mimic in this dialogbox (the LED is displayed as different shading on amonochrome monitor). When this LED is blue, therelay is synchronized with the IRIG-B signal and theTime field is grayed out, indicating that this fieldcan’t be changed. But the Date field can be changed(by editing and pressing Save).

When the LED is not blue, the relay is not time-synchronized and therefore, both the Date and Timefields can be changed.

The time field in the dialog box is not updatedcontinuously. The time at which the dialog box wasopened is the time that is displayed and remains assuch. This is true whether the relay is synchronizedwith the IRIG-B signal or not.

COMMAND BUTTONS

Stop Clock This toggles between start/stop, the relayclock. ‘Stop’ pauses, ‘Start’ resumes.

Save Saves Time and Date settings to therelay when applicable.

Cancel Returns you to the IPScom® mainwindow. Any changes to the displayedinformation is lost.

The Monitor submenu provides access for reviewingthe present status of the relay's measured andcalculated values, other real-time parameters andconditions as well as examining real-time andhistorical demand metering information (see Section4.4, Checkout Status/Metering). A cascading menuappears, providing several command options asshown below.

■ NOTE: Displayed parameters in status screenswill vary depending on unit configuration.

Primary Status

Secondary Status

Accumulator Status

Phase Distance

Loss of Field

Out of Step

Phasor Diagram

Sync Scope

Function Status

Relay

Setup

Monitor

Target

Sequence of Events

Oscillograph

Profile

Write File to Relay


The Targets submenu provides three commandoptions: Display, Reset LED, and Clear History.The Display command displays the Target Dialog.This dialog box (see Figure 4-17) provides detaileddata on target events, including time, date, functionstatus, phase current values, and IN/OUT contactstatus at the time of trip. Individually recordedevents may be selected within the dialog box andsaved into a text file, or be printed out with optionaladded comments. The Reset LED is similar topushing the Target Reset button on the relay’s frontpanel, resetting current target(s) displayed on therelay. This command does not reset any targethistory.

Relay

Setup

Monitor

Target

Sequence of Events

Oscillograph

Profile

Write File to Relay


Display

Reset LED

Clear History

The Clear History command clears all stored targetdata.

1

3

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B

C


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Figure 4-17 Target Dialog Box

Path: Relay menu / Targets submenu / Display window

Time is displayed in milliseconds.

COMMAND BUTTONS

Comment Opens comment dialog box for annotation.

Print Prints out selected target information, with comment.

Save Saves selected target information, with comment, as a text file.

Close Exits the currently displayed dialog box.

Sequence of EventsThe Sequence of Events function provides a timestamped history of the Pickup (PU), Trip (TR) orDropout (DR) for each element, input or outputselected in the Event Trigger Setup screen.

During each event the voltage, current, impedance,frequency, input and output status and Volts/Hz arerecorded. Up to 512 events are logged before thebuffer begins to write over the oldest event. If multipleevents occur, then the log entries are recorded withone millisecond resolution within each event.

Relay

Setup

Monitor

Target

Sequence of Events

Oscillograph

Profile

Write File to Relay


Setup

Retrieve

View

Clear

The Sequence of Events submenu allows the userto Setup the events that trigger the Sequence ofEvents recorder, Retrieve events from the relay,

View the pararmeters captured at the time of theevent and Clear the event recorder.

The Setup menu item displays the Event TriggerSetup screen Figure 4-18. Protective function Pickup,Trip, Dropout and/or Output/Input Pickup or Dropoutare selected to trigger the Sequence of EventsRecorder.

The Retrieve command downloads the events fromthe currently connected relay (events must beretrieved from the relay and stored in a file in order toview them.)

View permits the user to see a detailed list of pastevents and their corresponding captured parameters(real power, reactive power, differential current, deltavoltage, delta frequency, phase angle, 59D ratio, Vbrush (64B), field insulation resistance (64F), Vstator(20 Hz), and Istator (20 Hz) which are displayed inthe Event Log Viewer screen Figure 4-19.

The event log viewer screen includes the commandsOpen, Close, Print Summary, and Print Detail.Open opens a saved sequence of events file. Closecloses the print file. Print Summary prints an eventsummary, and Print Detail prints the detailed eventreport. Clear deletes event history from the control.

1

3

A

B

C

4–19


■ NOTE: When in “File Mode,” selecting “Send” will result in a warning message stating, “To send settings,IPScom needs to be connected to relay.”

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Events Download X

Event Record

Total Event Number:

Cancel

Download

Figure 4-20 Event Download Screen

Relay

Setup

Retrieve

Trigger

Clear

Setup

Monitor

Target

Sequence of Events

Oscillograph

Profile

Write File to Relay


The Oscillograph submenu allows storing data onselected parameters for review and plotting at alater time. The Setup command allows the user toset the number of partitions and triggeringdesignations to be made (see Table 3-1, RecorderParticitions). The Retrieve command downloadsand stores collected data to a file; Trigger allowsthe manual triggering of the recorder; Clear erasesthe existing records. Run the optional M-3801DIPSplot® PLUS Oscillograph Analysis Softwareprogram to view the downloaded oscillograph files.


■ NOTE: Oscillograph Post Trigger Delay is setto 5% in “File Mode”.

23 22 21 20 19 18 17 16

15 14 13 12 11 10 9

Setup Oscillograph Recorder

Number of Records

1 2 3 4 5 6 7 8

9 10 11 12 13 14 15 16

Post Trigger

Delay 0 %

6 5 4

3 2 1

8 7 6 5

4 3 2 1

14 13 12 11

10 9 8 7

Trigger OutputsTrigger Outputs ExpandedTrigger Inputs Expanded

Trigger Inputs

Send

Cancel

■ NOTE: When in “File Mode,” selecting “Send”will result in a warning message stating,“To send settings, IPScom needs to beconnected to relay.”

Figure 4-21 Setup Oscillograph Recorder

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Figure 4-22 Retrieve Oscillograph RecordDialog

Relay

Setup

Monitor

Target

Sequence of Events

Oscillograph

Profile

Write File to Relay


Switching Method

Active Profile

Copy Profile

The Profile submenu provides three commandoptions: Switching Method, Active Profile, andCopy Profile.

Switching Method command allows selection ofeither Manual or Input contact. Active Profile allowsuser to designate active profile. Copy Profile copiesactive profile to one of four profiles (user shouldallow approximately 2 minutes for copying.)

▲ CAUTION: Switching the active profile when therelay is on-line may cause unexpected operation ifthe wrong profile is selected.

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■ NOTE: When in “File Mode” selecting OK tochange Profile Switching Method willresult in a warning message, “To changeProfile Switching Method, IPScom needsto be connected to relay”.

Figure 4-23 Profile Switching Method Dialog

■ NOTE: During Profile Switching, relay operationis disabled for approximately 1 second.

1

3

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B

C

4–21


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■■■■■ NOTE: When in “File Mode” selecting OK to selectthe Active Profile will result in a warningmessage, “To select the Active Profile,IPScom needs to be connected to Relay”.

Figure 4-24 Select Active Profile

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■■■■■ NOTE: When in “File Mode” selecting OK tocopy the Active Profile will result in awarning message, “To copy the ActiveProfile, IPScom needs to be connectedto Relay”.

Figure 4-25 Copy Active Profile

The Write File To Relay command is used to writethe data to the relay. The Read Data From Relaycommand is used to retrieve the data from the relayto the computer for display.

Relay

Setup

Monitor

Target

Sequence of Events

Oscillograph

Profile

Write File to Relay


Window Menu/Help Menu

The Window menu enables the positioning andarrangement of all IPScom® windows so that there isbetter access to available functions. This featureallows the display of several windows at the sametime. Clicking on an inactive window activates thatwindow.

Currently in revision, the Help menu will enable theuser to look up information about any IPScom menusor commands. Though displaying (greyed-out) Helpcommands, this menu item is currently unavailable.

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The Help menu provides three commands. TheContents command initiates a link to a PDF (PortableDocument File) version of this instruction book foreasy reference. An Adobe Acrobat® reader isrequired to view this document.

The M-3425A Instruction Book has been indexed toits table of contents. By selecting the “Navigatorpane’ in Adobe Acrobat Reader, the user can directlyaccess selected topics. The About commanddisplays IPScom version and developmentinformation. Profile Info displays user infromationfor input and editing.

XAbout IPScom

OKIPScoms

Integrated Protection System

Version: D-0133V02.00.15

Copyright 1997-2002 Beckwith Electric Co., Inc.

ID M-3425A

BECKWITH ELECTRIC COM-3425A

Serial Number 1

Software Version V02.00.22

Communication Address 1

Control Number 1

Setpoint Checksum 13

Calibration Checksum 3E

Unit Information

Figure 4-26 About IPScom Dialog Box

1

3

A

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4.4 Checkout Status/Metering

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Figure 4-27 Primary Status Dialog Box

Path: Relay menu/ Monitor submenu/ Primary Status window

These are calculated values based on the VT and CT inputs.

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Figure 4-28 Secondary Status Dialog Box

Path: Relay menu/ Monitor submenu/ Secondary Status window

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Figure 4-29 Accumulator Status Screen

70

60

50

40

30

20

-10

Circle Diameter

Circle Offset

1.00

0.10

Phase Impedances:

-0.80 -0.60 -0.40 -0.20 0.20 0.40 0.60 0.80

10

X

Phase Distance

Circle Impedance Angle

AB:

BC:

CA:

Ω

Ω

Ω

Load Encr Angles:

Load Encr. R Reach:

X

Figure 4-30 Phase Distance Dialog Box

Path: Relay menu / Monitor submenu / Phase Distance window

Phase Distance window shows a graphic representation of phase distance settings.

Move the scope window to the right

Zoom In

Zoom Out

Refresh Scope

CONTROL BUTTONS

Move up the scope window

Move down the scope window

Move the scope window to the left

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Figure 4-31 Loss of Field Dialog Box

Path: Relay menu / Monitor submenu / Loss of Field window

Loss-of-Field window shows a graphic representation of loss-of-field settings, and also displays the positive sequenceimpedance.

CONTROL BUTTONS





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Refresh Scope

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Figure 4-32 Out-of-Step Dialog

Path: Relay menu / Monitor submenu / Out-of-Step window


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Refresh Scope

CONTROL BUTTONS




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4–25


Figure 4-33 Phasor Dialog Box

Path: Relay menu / Monitor submenu / Phasor Diagram window

CONTROL BUTTONS

p Voltage Toggle & display voltage channel information

p Currents (A) Toggle & display current channel information.

p Freeze Toggle & update information

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P: Pickup T:Tripped T PP T

Function Status

(21) #1 Phase Distance(21) #2 Phase Distance(21) #3 Phase Distance(24DT) #1 Volts/Hz DEF(24DT) #2 Volts/Hz DEF(24IT) Volts/Hz INV(27) #1 Phase Undervoltage(27) #2 Phase Undervoltage(27) #3 Phase Undervoltage(25S) Sync Check(25D) Dead Check(27TN) #1 Third Harmonic Undervoltage(27TN) #2 Third Harmonic Undervoltage(32) #1 Directional Power(32) #2 Directional Power(32) #3 Directional Power(40) #1 Loss of Field(40) #2 Loss of Field(40VC) #1 Loss of Field with VC(40VC) #2 Loss of Field with VC(46DT) Neg. Seq. Overcurrent DEF(46IT) Neg. Seq. Overcurrent INV(49) #1 Stator Overload(49) #2 Stator Overload(50BF) Breaker Failure(50) #1 Phase Overcurrent(50) #1 Phase Overcurrent(50) #2 Phase Overcurrent(50N) Instant. Neutral Overcurrent(50DT) #1 Time Overcurrent(50DT) #2 Time Overcurrent(50/27) Inadvertent Energizing(51N) Inv. Time Neu. Overcurrent(51V) Inv. Time Phase Overcurrent(59) #1 Phase Overvoltage(59) #2 Phase Overvoltage(59) #3 Phase Overvoltage(59D) Third Harmonic Voltage Differential

(59N) #1 Neutral Overvoltage(59N) #2 Neutral Overvoltage(59N) #3 Neutral Overvoltage

(59X) #1 Multi-purpose Overvoltage(59X) #2 Multi-purpose Overvoltage

(60FL) VT Fuse Loss(64F) #1 Field Ground(64F) #2 Field Ground

(64B) Brush Lift-Off(64S) 100% Stator Ground

(67NDT) Residual Definite Overcurrent(67NIT) Residual Inverse Overcurrent

(78) Out of Step(81) #1 Frequency(81) #2 Frequency(81) #3 Frequency(81) #4 Frequency

(81A) #1 Freq Accumulator(81A) #2 Freq Accumulator(81A) #3 Freq Accumulator(81A) #4 Freq Accumulator(81A) #5 Freq Accumulator(81A) #6 Freq Accumulator

(81R) #1Rate of Change of Frequency(81R) #2 Rate of Change of Frequency

(87) #1 Phase Differential Current(87) #2 Phase Differential Current

(87GD) Ground Differential Current(IPSL) #1 IPS LOGIC(IPSL) #2 IPS LOGIC(IPSL) #3 IPS LOGIC(IPSL) #4 IPS LOGIC(IPSL) #5 IPS LOGIC(IPSL) #6 IPS LOGIC(BM) Breaker Monitor

(TC) Trip Circuit Monitor

OUTPUT 17

OUTPUT 18

X

OUTPUT 1

OUTPUT 2

OUTPUT 3

OUTPUT9

OUTPUT 10

OUTPUT 11

OUTPUT 4

OUTPUT 5

OUTPUT 6

OUTPUT 12

OUTPUT 13

OUTPUT 14

OUTPUT 7

OUTPUT 8

OUTPUT 15

OUTPUT 16

OUTPUT 22

OUTPUT 23

OUTPUT 19

OUTPUT 20

OUTPUT 21

INPUT 1

INPUT 2

INPUT 3

INPUT 7

INPUT 8

INPUT 9

INPUT 4

INPUT 5

INPUT 6

INPUT 10

INPUT 11

INPUT 12

INPUT FL INPUT 13

INPUT 14

Figure 4-35 Function Status Screen

Path: Relay menu / Monitor submenu / Function Status window

Function Status window shows the status of various functions, with “T” representing the function which has tripped, and “P”representing the function which has picked up and is timing.Path: Help menu / About... command

COMMAND BUTTONS

OK Exits the currently displayed dialog box.

The Profile Info command will allow the user to view or make notations for the relay setpoint data files.

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4–27


4.5 Cautions

System and IPScom® CompatibilityEvery attempt has been made to maintaincompatibility with previous software versions. Insome cases (most notably with older protectionsystems), compatibility cannot be maintained. Ifthere is any question about compatibility, contactthe factory.

System PrioritySystem conflicts will not occur, as local commandsinitiated from the front panel receive priorityrecognition. When the unit is in local mode,communication using the serial ports is suspended.IPScom displays an error message to indicate thisfact.

Time and Date StampingTime and date stamping of events is only as usefulas the validity of the unit’s internal clock. Under theRelay menu, the Set Date/TIme command allowsyou to manually set the unit’s clock.

Echo CancelThe Echo Cancel check box, under the Commmenu, should only be used when several relays areconnected using a fiber optic loop network.Otherwise, echo cancel must not be selected orcommunication will be prevented.

Serial Port ConnectionsIf the serial port is connected to something otherthan a modem, and an IPScom modem commandis executed, the results are unpredictable. In somecases, the computer may have to be reset.


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4.6 Keyboard Shortcuts

Keyboard ShortcutsSYSTEM KEYS

These keys can be used within Microsoft Windows® and IPScom®.

Alt-Tab To switch between applications.

Ctrl-Esc To open Task List dialog box. Opens Start Menu (Win 95/98).

Ctrl-Tab To switch between windows within an application.

Arrow Keys To select an application or group icon.

First Character of Name To select application or group icon.

Enter To open selected group or run selected application.

MENU KEYS

These keys enable you to select menus and choose commands.

Alt or F10 To select or cancel selection of the Setup menu on the menu bar.

Left Arrow, Right Arrow To move between menus.

Up Arrow, Down Arrow To move between commands.

A character key To choose the menu or command. The underlined character matchesthe one you type.

Enter To choose the selected menu name or command.

Esc To cancel the selected menu name, or to close the open menu.

DIALOG BOX KEYS

These keys are useful when working in a dialog box.

Alt-a character key To move to the option or group whose underlined letter or numbermatches the one you type.

Arrow Keys To move highlighted selections within list boxes.

Alt-Down Arrow To open a list.

Spacebar To select an item or cancel a selection in a list. Also to select orclear a check box.

Enter To carry out a command.

Esc or Alt-F4 To close a dialog box without completing the command.

Table 4-3 Microsoft Windows Keyboard Shortcuts

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4.7 IPSutil™ Communications Software

Figure 4-36 IPSutil Main Menu Flow

M-3890 IPSutilThe M-3890 IPSutil Communication software packageprovides communication with the Beckwith IntegratedProtection System® (IPS) for setting up the relays.Its main purpose is to aid in setting up IPS relaysthat are ordered without the optional front panel HMIinterface.

Installation and SetupIPSutil runs with the Microsoft® Windows 95 operatingsystem or above. Hardware requirements are thesame as those stated for IPScom®.

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InstallationAn installation utility has been provided as a part ofIPScom® and IPSutil™ programs. After installation,IPSutil can be run from the hard drive by choosingIPSUTIL.EXE.

System SetupConnect a null modem cable from COM1 of therelay to the PC serial port. IPSutil supports COM1port direct connection only. Modem connection isnot supported. IPSutil is not supported throughCOM2 or COM3 ports of the relay.

OverviewIPSutil helps in setting up IPS relays which wereordered without the optional front panel HMI interface.Units delivered without HMI’s are shipped with a setof factory default settings for various parametersthat the end user may wish to change. While theutility program is directed to users that do not haveHMI, users of HMI-provided relays can also useIPSutil to set various parameters. When IPSutil isstarted, a warning window appears:

IPSutility should NOT be used to set up the relay which is on-line because someparameter’s modifications may result in unexpected operations. It is only for off-line relaysetup.

OK

WARNING X

Figure 4-37 Warning Message

After the user accepts the warning, the user canaccess the IPSutil main menu. The following sectionsdescribe each IPSutil menu items.

Comm Menu

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The Comm menu allows the user to makeconnections to the relay. This is the first commandthe user must use to access the unit. After the userselects the Connect submenu item, theCommunications dialog box appears (See Figure4-41).

• Select the correct PC communication portwhere the null modem cable is connectedfor the relay.

• Select the baud rate of the relay. Factorydefault is 9600 baud.

• Select the access code resident in therelay. Factory default is 9999.

• Select “Open com”.

The following message window will be displayedshowing COM opened. Now, the title bar will displaythe relay model and the software version.

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The Exit submenu allows you to quit IPSutil. If therelay was connected, this submenu disconnectsthe relay. When the relay was connected, if youhave made any changes for some parameters (forexample, baud rate, phase rotation) the followingmessage window appears.

Some parameter’s changes require resetting the relay to become effective. Do you wishto reset the relay now?

IPSUTILITY X

OK Cancel

Figure 4-38 IPSutility Reset Relay Message

Relay Comm CommandWhen Relay Comm command is selected, theRelay Comm Port Settings dialog box appears (SeeFigure 4-42). It allows you to set the relaycommunication ports COM1 or COM2/COM3 baudrate. For COM2/COM3, it allows you to set theprotocol and dead synch time. Additionally, forCOM2 and COM3, if you select MODBUS protocol,the dialog box allows you to enable the parityoption.

■ NOTE: If COM1 baud rate is changed and therelay is reset, the new baud rate must beused to communicate with COM1

Ethernet CommandWhen the Ethernet command is selected, theEthernet Settings dialog box appears (see Figure4-43.) This command allows the user to enable ordisable the ethernet connection and enable/setprotocols.

Clock CommandWhen the Clock command is selected, the “SetUnit Date/Time” dialog box appears (See Figure4-44). Date and Time can be changed and sent tothe relay. This dialog box allows you to start or stopthe clock in the relay.

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Security Menu

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The Security Menu allows you to set thecommunication access code and the level accesscodes for the relay.

The Change Comm Access Code allows you toassign new communication access code to therelay. The range of the access code is 1 to 9999.Note that the access code 9999 is a factory default(See Figure 4-45).

■ NOTE: Setting the access code to 9999 disablessecurity.

The Change User Access Code allows you toassign three different levels of access code for therelay functions accessibility. The range of the levelaccess code is 1 to 9999 (See Figure 4-46).

▲▲▲▲▲ CAUTION: This submenu allows you to changethe relay level access codes.

Miscellaneous Menu

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The Miscellaneous menu allows you to set andmonitor some of the relay parameters.

The Setup command allows you to change theusers Logo information, test outputs, assigncommunication address and user control number,phase rotation, OK LED flash mode in the relay.Note that the highest number used for thecommunication address is 255 and the highestcontrol number allowed is 9999 (See Figure 4-47).

The Monitor Status command allows you to monitorand clear the error code counters, monitor the checksums, and to view inputs test status. Note thatpowerloss counter cannot be cleared.

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Figure 4-39 Monitor Status Screen

The Calibration command provides the user withinstructions to recalibrate Nominal Frequency, ThirdHarmonic, (64F) Field Ground, and (64S) StatorProtection.

Calibration

Select Calibration Procedures

Nominal Frequency

Third Harmonic

64F Field Ground

64S Stator Protection

Calibrate Cancel

Connect VN=VX=10.0 (+/- 0.01) andVA=VB=VC=120.0 VAC at 180 Hz,0 deg phase. Press Calibrate when ready.

X

Figure 4-40 Calibration Dialog

COMMAND BUTTONS

Calibrate Sends the currently displayedinformation to the relay.

Cancel Returns you to the IPSutil main window.

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Figure 4-43 Ethernet Settings

COMMAND BUTTONS

Ethernet Enable/Disable: Allows user to enableand disable the Ehternet Port.

DHCP Protocol Enable/Disable: Allows the userto enable or disable the DHCP protocol. WhenDHCP protocol is enabled the the IP Address portionof the screen is grayed out. When DHCP protocol isdisabled the IP Address can be manually entered.

EGD Protocol Enable/Disable: Not available.

Protocol Selection MODBUS/Serconv: Providesthe user with the ability to select either MODBUSover TCP/IP or Serconv (BECO2200 over TCP\IP)protocol.

Save Saves values to the relay.

Cancel Returns you to the IPSutil main window.Any changes to the displayedinformation are lost.

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Figure 4-44 Set Unit Date/Time Dialog Box

Help Menu

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Under Help, the About... submenu provides youthe information on the IPSUtil™ version numbers.

COM1

COMM X

PC Port

Access Code

Baud Rate

300

1200

4800

600

2400

9600

Open COM

Close COM

Cancel

Figure 4-41 Communication Dialog

COMMAND BUTTONS

Open COM Initiates communication with theprotective system by direct serialcommunication.

Close COM Discontinues communication with theprotective system.


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Figure 4-42 Relay Comm Port Settings

COMMAND BUTTONS

OK Sends the currently displayedinformation to the relay.


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4–33


COMMAND BUTTONS

Stop Clock This toggles between start/stop the clockof the relay. The ‘Stop’ stops the clock inthe relay. The ‘Start’ resumes the clockin the relay.

Save When connected to the protectionsystem, the date and time informationon the display is sent to the relay.

Cancel Returns you to the IPSutil™ mainwindow. Any changes to the displayedinformation are lost.

There is a blue Time Sync LED mimic on the Set Date/Time dialog box (the LED is displayed as differentshading on a monochrome monitor). When this LED isblue, the relay is synchronized with the IRIG-B signaland the Time field is grayed out, indicating that this fieldcan’t be changed. But the Date field can be changed(by editing and pressing Save). When the LED is notblue, the relay is not time-synchronized and therefore,both the Date and Time fields can be changed. Thetime field in the dialog box is not updated continuously.The time at which the dialog box was opened is thetime that is displayed and remains as such. This is truewhether the relay is synchronized with the IRIG-B signalor not.

Change Comm Access Code X

New Access Code:

Confirm New Access Code:

xxxx

xxxx

OK Cancel

Figure 4-45 Change Communication AccessCode Dialog Box

COMMAND BUTTONS


Cancel Returns you to the IPSutil™ mainwindow. Any changes to the displayedinformation are lost.

Change User Access Code X

New User Access Code:

Confirm New User Access Code:

OK Cancel

xxxx

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xxxx

Level 1 Level 2 Level 3

Figure 4-46 Change User Access CodeDialog Box

COMMAND BUTTONS



Setup

Output Test (Relay)

User Logo

Line1:

Line2:

BECKWITH ELECTRIC CO.

M-3425A

User Control Number: 1

OK Cancel

8 7 6 5 4 3 2 1OFF

ON

OFF

ON

16 15 14 13 12 11 10 9

X

Enable

ABC

Disable

ACB

OK LED Flash:

Phase Rotation:

Output Test (Relay) Extended

23 22 21 20 19 18 17

Figure 4-47 Setup Dialog Box

COMMAND BUTTONS



■ NOTE: Output Test is not available on someversions of the M-3425A Relay.

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Legal Information

PatentThe units described in this manual are covered byU.S. Patents, with other patents pending.

Buyer shall hold harmless and indemnify the Seller,its directors, officers, agents, and employees fromany and all costs and expense, damage or loss,resulting from any alleged infringementof UnitedStates Letters Patent or rights accruing thereform ortrademarks, whether federal, state, or common law,arising from the Seller’s compliance with Buyer’sdesigns, specifications, or instructions.

WarrantySeller hereby warrants that the goods which are thesubject matter of this contract will be manufacturedin a good workmanlike manner and all materialsused herein will be new and reasonably suitable forthe equipment. Seller warrants that if, during aperiod of five years from date of shipment of theequipment, the equipment rendered shall be foundby the Buyer to be faulty or shall fail to peform inaccordance with Seller’s specifications of theproduct, Seller shall at his expense correct thesame, provided, however, that Buyers shall ship theequipment prepaid to Seller’s facility. The Seller’sresponsibility hereunder shall be limited to replace-ment value of the equipment furnished under thiscontract.

Seller makes no warranties expressed or impliedother than those set out above. Seller specificallyexcludes the implied warranties of merchantibilityand fitness for a particular purpose. There are nowarranties which extend beyond the descriptioncontained herein. In no event shall Seller be liable forconsequential, exemplary, or punitive damages ofwhatever nature.

Any equipment returned for repair must be sentwith transportation charges prepaid. The equipmentmust remain the property of the Buyer. The afore-mentioned warranties are void if the value of theunit is invoiced to the Seller at the time of return.

IndemnificationThe Seller shall not be liable for any propertydamages whatsoever or for any loss or damagearising out of, connected with, or resulting fromthis contract, or from the performance or breachthereof, or from all services covered by or furnishedunder this contract.

In no event shall the Seller be liable for special,incidental, exemplary, or consequential damages,including but not limited to, loss of profits orrevenue, loss of use of the equipment or anyassociated equipment, cost of capital, cost ofpurchased power, cost of substitute equipment,facilities or services, downtime costs, or claims ordamages of customers or employees of the Buyerfor such damages, regardless of whether said claimor damages is based on contract, warranty, tortincluding negligence, or otherwise.

Under no circumstances shall the Seller be liablefor any personal injury whatsoever.

It is agreed that when the equipment furnishedhereunder are to be used or performed in connec-tion with any nuclear installation, facility, oractivity, Seller shall have no liability for anynuclear damage, personal injury, property damage,or nuclear contamination to any property located ator near the site of the nuclear facility. Buyer agreesto indemnify and hold harmless the Seller againstany and all liability associated therewith whatso-ever whether based on contract, tort, or otherwise.Nuclear installation or facility means any nuclearreactor and includes the site on which any of theforegoing is located, all operations conducted onsuch site, and all premises used for such opera-tions.

Notice:Any illustrations and descriptions by BeckwithElectric Co., Inc. are for the sole purpose ofidentification.

The drawings and/or specifications enclosed hereinare the proprietary property of Beckwith ElectricCo., Inc., and are issued in strict confidence;therefore, shall not be used as a basis of reproduc-tion of the apparatus described therein withoutwritten permission of Beckwith Electric Co., Inc.

No illustration or description contained hereinshall be construed as an express warranty ofaffirmation, promise, description, or sample, andany and all such express warranties are specificallyexcluded nor shall such illustration or descriptionimply a warranty that the product is merchantableor fit for a particular purpose. There shall be nowarranties which extend beyond those contained inthe Beckwith Electric Co., Inc. terms of sale.

All rights reserved by Beckwith Electric Co., Inc. No reproduction may be made without prior written approvalof the Company.

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BECKWITH ELECTRIC CO., INC.6190 - 118th Avenue North • Largo, Florida 33773-3724 U.S.A.

PHONE (727) 544-2326 • FAX (727) 546-0121E-MAIL [email protected] PAGE www.beckwithelectric.com

© 2004 Beckwith Electric Co.Printed in USA

800-3425A-IB-04MC2 07/08

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