Instruction Book

Part 1 of 2

M-3425A
Generator Protection
 PROTECTION

Generator Protection
M-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.

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

protection
• 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 Time
Accumulation (81A), Inadvertent Energizing (50/27) and Turn-to-Turn Fault
(59X)
• Expanded IPScom® Communications Software provides simple and logical
setting and programming, including logic schemes

• Simple application with Base and Comprehensive protection packages

• Load encroachment blinders and power swing blocking for system backup
protection (21) to enchance security during system abnormal conditions

• Options: Ethernet Connection, Field Ground/Brush Lift-Off Protection (64F/B),

Sync Check (25), 100% Stator Ground Fault Protection by low frequency
injection (64S) and Expanded I/O (15 additional Output Contacts and 8
additional Control/Status Inputs)
M-3425A Generator Protection Relay

Protective Functions Optional Protective Functions

Base Package • Sync Check with Phase Angle, ΔV and ΔF
• Overexcitation (V/Hz) (24) with dead line/dead bus options (25)
• Phase Undervoltage (27) • Field Ground (64F) and Brush Lift Off (64B)
(Includes M-3921 Field Ground Coupler)
• Directional power sensitive triple-setpoint Re-
verse Power, Low Forward Power or Over- • 100% Stator Ground protection by low fre-
power detection, one of which can be used for quency injection (64S). The following equip-
sequential tripping (32) ment is supplied with the 64S option:
• Dual-zone, offset-mho Loss of Field (40), which – 20 Hz signal generator (430-00426)
may be applied with undervoltage controlled – Band-pass Filter (430-00429)
accelerated tripping
Standard Features
• Sensitive Negative Sequence Overcurrent pro-
tection and alarm (46) • Eight programmable outputs and six pro-
grammable inputs
• Instantaneous Phase Overcurrent (50)
• Oscillographic recording with COMTRADE
• Inadvertent Energizing (50/27) or BECO format
• Generator Breaker Failure (50BF) • Time-stamped target storage for 32 events
• Instantaneous Neutral Overcurrent (50N) • Metering of all measured parameters and
• Inverse Time Neutral Overcurrent (51N) calculated values
• Three-phase Inverse Time Overcurrent • Three communications ports (two RS-232
(51V) with voltage control and voltage re- and one RS-485)
straint. • M-3820D IPScom® Communications Soft-
• Phase Overvoltage (59) ware
• Neutral Overvoltage (59N) • Includes MODBUS and BECO 2200
• Multi-purpose Overvoltage (59X) protocols
• VT Fuse-Loss Detection and blocking • Standard 19" rack-mount design (vertical
(60FL) mounting available)
• Residual Directional Overcurrent (67N) • Removable printed circuit board and power
supply
• Four-step Over/Underfrequency (81)
• 50 and 60 Hz models available
• Phase Differential Current (87)
• Both 1A and 5 A rated CT inputs available
• Ground (zero sequence) Differential Current
(87GD) • Additional trip inputs for externally connected
• IPSlogicTM takes the contact input status and devices
function status and generates outputs by • IRIG-B time synchronization
employing (OR, AND, and NOT) boolean • Operating Temperature: –20° C to +70° C
logic and a timer. • Sequence of Events Log
Protective Functions • Trip Circuit Monitoring
Comprehensive Package • Breaker Monitoring
The Comprehensive Package includes all Base • Four Setpoint Groups
Package functions, as well as the following: Optional Features
• Three-zone Phase Distance protection for • Redundant power supply
phase fault backup protection (21). Zone three
• M-3925A Target Module
can be used for Out-of-Step Blocking. Load
encroachment blinders can be applied. • M-3931 Human-Machine Interface (HMI)
Module
• 100% Stator Ground Fault protection using Third
Harmonic Neutral Undervoltage (27TN) or (59D) • RJ45 Ethernet port utilizing MODBUS over
Third Harmonic Voltage Differential (ratio) TCP/IP and BECO2200 over TCP/IP proto-
cols
• Stator Overload (49) (Positive Sequence
Overcurrent) • M-3801D IPSplot® PLUS Oscillograph Analy-
sis Software
• Definite Time Overcurrent (50DT) can be used
for split phase differential • Expanded I/O (15 additional outputs and 8
additional inputs)
• Out-of-Step (78)
• UnderFrequency Accumulation (81A)
• Rate of Change of Frequency (81R)

–2–
 M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS
Device Setpoint
Number 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%
21 (–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,#3
Angle 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 the
out-of-step condition for blocking Function 21 #1 and/or 21 #2.
Volts / Hz
Definite Time
Pickup #1, #2 100 to 200% 1% 1%
Time Delay #1, #2 30 to 8160 Cycles 1 Cycle 25 Cycles
24
Inverse Time
Pickup 100 to 200% 1% 1%
Characteristic Curves Inverse Time #1–#4 — —
Time Dial: Curve #1 1 to 100 1
Time 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. The
pickup accuracy stated is only applicable from 10 to 80 Hz, 0 to 180 V, 100 to 150% V/Hz and a nominal voltage
setting of 120 V.
Phase Undervoltage

27 Pickup #1, #2, #3 5 to 180 V 1V 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.

–3–
M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (cont.)

Device Setpoint
Number 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 Sequence
Voltage Block 5 to 180 V 1V 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%
27
TN 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 Forward
Power Block 0.01 to 1.00 PU 0.01 PU 0.01 PU or 2%
Low Band Forward
Power 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%

32
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. This
function can be selected as either overpower or underpower in the forward direction (positive setting) or reverse
direction (negative setting). Element #3 can be set as real power or reactive power. This function includes a
programmable 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%
40 (–250.0 to 250.0 Ω) ( 0.5 Ω or 5%)
Time Delay #1, #2 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
Time Delay with
Voltage Control #1, #2 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
Voltage Control 5 to 180 V 1V 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.

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

–4–
 M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (cont.)

Device Setpoint
Number Function Ranges Increment Accuracy†

Negative Sequence Overcurrent

Definite Time
Pickup 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 Time
Pickup 3 to 100% 1% 0.5 % of 5 A
( 0.5% of 1 A)
46
Time Dial Setting 1 to 95 1 3 Cycles or 3%
(K= I22t)
Definite Maximum
Time 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
49
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%

50 (0.1 to 48.0 A) ( 0.02 A or 3%)
Time Delay #1, #2 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
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

Pickup
50
BF-Ph
Phase Current 0.10 to 10.00 A 0.01 A 0.1 A or 2%
50 (0.02 to 2.00 A) ( 0.02 A or 2%)
BF 50
BF-N 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%)
Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
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%

50 (0.04 A to 48.00 A) ( 0.02 A or 3%)
DT
Pickup Phase B #1, #2 (same as above)
Pickup Phase C #1, #2 (same as above)
Time Delay #1, #2 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
This function uses generator line-side currents.
When 50DT function is used for split-phase differential protection, 50BF, 87, and 87GD functions should not be
used, 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.

–5–
M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (cont.)

Device Setpoint
Number Function Ranges Increment Accuracy†

Instantaneous Neutral Overcurrent

Pickup 0.1 to 240.0 A 0.1 A 0.1 A or 3%

50N (0.1 to 48.0 A) ( 0.02 A or 3%)
Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
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

50 Overcurrent
Pickup 0.5 to 15.00 A 0.01 A 0.1 A or 2%
50/ (0.1 to 3.00 A) ( 0.02 A or 2%)
27
27 Undervoltage
Pickup 5 to 130 V 1V 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

Pickup 0.25 to 12.00 A 0.01 A 0.1 A or 1%

(0.05 to 2.40 A) ( 0.02 A or 1%)
Characteristic Curve Definite Time/Inverse/Very Inverse/Extremely Inverse/IEC Curves
51N Moderately 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

Pickup 0.50 to 12.00 A 0.01 A 0.1 A or 1%

(0.10 to 2.40 A) ( 0.02 A or 1%)
Characteristic Curve Definite Time/Inverse/Very Inverse/Extremely Inverse/IEC Curves
51V Moderately 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
Voltage Control (VC) 5 to 180 V 1V 0.5 V or 0.5%
or
Voltage Restraint (VR) Linear Restraint — —
* For IEC Curves the timing accuracy is 5%.

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

–6–
 M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (cont.)

Device Setpoint
Number Function Ranges Increment Accuracy†

Phase Overvoltage

59 Pickup #1, #2, #3 5 to 180 V 1V 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 or Positive 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 sequence voltage is selected, the 59 Function uses discrete Fourier transform (DFT) for
magnitude calculation, irrespective of the RMS/DFT selection, and timing accuracy is 1 Cycle or 1%.
Third-Harmonic Voltage Differential Ratio

Ratio (Vx/VN) 0.1 to 5.0 0.1

Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
59D
Positive Seq Voltage Block 5 to 180 V 1V 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 selected as
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%

59N
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%

59X
Time Delay #1, #2 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%

Multi-purpose input that may be used for turn-to-turn stator ground protection, bus ground protection, or as an
extra 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 components
of the voltages and currents. VT fuse-loss output can be initiated from internally generated
60 logic, and/or from input contacts.
FL
Alarm Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
Three Phase VT
Fuse Loss Detection Enable/Disable

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

–7–
M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (cont.)

Device Setpoint
Number Function Ranges Increment Accuracy†

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*
67N 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%)
Characteristic Curve Definite Time/Inverse/Very Inverse/Extremely Inverse/IEC Curves
Moderately Inverse/Very Inverse/Extremely Inverse/IEEE Curves
Time Dial 0.5 to 11.0 0.1 3 Cycles or 5%
0.05 to 1.10 (IEC Curves) 0.01
0.5 to 11 (IEEE curves) 0.01

Directional Element
Max 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°
78 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%)
Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
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 Hz

40.00 to 57.00 Hz*
81 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 to
53 Hz. Beyond these ranges, the accuracy is 0.1 Hz.
* This range applies to 50 Hz nominal frequency models.

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

–8–
 M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (cont.)

Device Setpoint
Number Function Ranges Increment Accuracy†

Frequency Accumulation

Bands #1, #2, #3, #4, #5, #6

High Band #1 50.00 to 67.00 Hz 0.01 Hz 0.02 Hz
81A 40.00 to 57.00 Hz*
Low Band #1–#6 50.00 to 67.00 Hz 0.01 Hz 0.02 Hz
40.00 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 to 6.
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 to
accumulation) and allows the underfrequency blade resonance to be established to avoid unnecessary accumulation of
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%

81R Time Delay #1, #2 3 to 8160 Cycles 1 Cycle + 20 Cycles
Negative Sequence
Voltage 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%)
87 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
*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
Pickup 0.20 to 10.00 A 0.01 A 0.1 A or 5%
87 (0.04 to 2.00 A) ( 0.02 A or 5%)
GD Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle or 1%
CT Ratio Correction (RC) 0.10 to 7.99 0.01
The 87GD function is provided primarily for low-impedance grounded generator applications. This function
operates as a directional differential. If 3I0 or In is extremely small (less than 0.2 secondary Amps), the element
becomes non-directional.
If 67N function with IN (Residual) operating current is enabled, 87GD will not be available. Also, if 50DT is used for
split-phase differential, 87GD function will not be available.

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

–9–
M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (cont.)

Device Setpoint
Number Function Ranges Increment Accuracy†

IPSlogicTM

IPSlogic uses element pickups, element trip commands, control/status input state changes,
IPS 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 kACycles

or kA2 Cycles or kA2 Cycles or kA2 Cycles
BM Time Delay 0.1 to 4095.9 Cycles 0.1 Cycles 1 Cycle or 1%
2
Timing Method IT or I T
Preset Accumulators 0 to 50,000 kA Cycles 1 kA Cycle
Phase A, B, C
The Breaker Monitor feature calculates an estimate of the per-phase wear on the breaker contacts by measuring and
integrating 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-programmed
threshhold 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 begins after
the set time delay.
Trip Circuit Monitoring

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

The AUX input is provided for monitoring the integrity of the trip circuit. This input can be used for nominal trip coil
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 Unit
Transformer 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-ground
voltages for all voltage-sensitive functions. This Line-Ground to Line-Line selection should only be used for a VT
connected Line-Ground with a secondary voltage of 69 V (not 120 V).

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

–10–
 M-3425A Generator Protection Relay

OPTIONAL PROTECTIVE FUNCTIONS

Device Setpoint
Number Function Ranges Increment Accuracy†

Sync Check
25D Dead Check
Dead Voltage Limit 0 to 60 V 1V 0.5 V or ±0.5%
Dead Time Delay 1 to 8160 Cycles 1 Cycle –1 to +3 Cycles or 1%
25S Sync Check
Phase Angle Window 0° to 90° 1° 1°
Upper Voltage Limit 60 to 140 V 1V 0.5 V or ±0.5%
25
Lower Voltage Limit 40 to 120 V 1V 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 be
enabled 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 ±1KΩ

64F Time Delay #1, #2 1 to 8160 Cycles 1 Cycle ( IF2 +1) Sec.
Injection Frequency (IF) 0.10 to 1.00 Hz 0.01 Hz

64B Brush Lift-Off Detection (measuring control circuit)

Pickup 0 to 5000 mV 1 mV
Time Delay 1 to 8160 Cycles 1 Cycle ( IF2 +1) Sec.
When 64F is purchased, an external Coupler Module (M-3921) is provided for isolation from dc field voltages.
Figure 8, Field Ground Protection Block Diagram, illustrates a typical connection utilizing the M-3921 Field
Ground Coupler. Hardware dimensional and mounting information is shown in Figure 9, M-3921 Field Ground
Coupler Mounting Dimensions.
100% Stator Ground Protection by low frequency injection

Pickup 2 to 40 mA 1 mA 1 mA
64S Time Delay 1 to 8160 Cycles 1 Cycle 1 Cycle* or 1%
Undervoltage Inhibit 5 to 30 V 1V 0.5 V to 0.5%
External low frequency generator, band pass filter and current transformer are required for this function. 59D and
27TN function should be disabled when the 64S function is enabled. 59N may be applied when this function is
enabled.

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

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

–11–
M-3425A Generator Protection Relay

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

Configuration Options
The M-3425A Generator Protection Relay is available in either a Base or Comprehensive package of
protective functions. This provides the user with flexibility in selecting a protective system to best suit the
application. Additional Optional Protective Functions may be added at the time of purchase at per-function
pricing.
The Human-Machine Interface (HMI) Module, Target Module, or redundant power supply can be selected at
time 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 band
pass 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 different
power system configurations or generator operating modes. Profiles can be switched either manually using
the 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.

Metering
The relay provides metering of voltages (phase, neutral and sequence quantities), currents (phase, neutral
and sequence quantities), real power, reactive power, power factor and impedance measurements.
Metering accuracies are:
Voltage: 0.5 V or 0.5%, whichever is greater
0.8 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 greater
1 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 Recorder
The oscillographic recorder provides comprehensive data recording of all monitored waveforms, storing up to
472 cycles of data. The total record length is user-configurable from 1 to 16 partitions. The sampling rate is 16
times the power system nominal frequency (50 or 60 Hz). The recorder may be triggered using either the
designated control/status inputs, trip outputs, or using serial communications. When untriggered, the recorder
continuously stores waveform data, thereby keeping the most recent data in memory. When triggered, the
recorder stores pre-trigger data, then continues to store data in memory for a user-defined, post-trigger delay
period. The data records can be stored in either Beckwith Electric format or COMTRADE format.

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

–12–
 M-3425A Generator Protection Relay

Sequence of Events Log

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

Calculations
Current and Voltage RMS Values: Uses Discrete Fourier Transform algorithm on sampled voltage and current
signals to extract fundamental frequency phasors for relay calculations. RMS calculation for the 50, 51N, 59
and 27 functions, and the 24 function are obtained using the time domain approach to obtain accuracy over a
wide frequency band. When the RMS option is selected, the magnitude calculation for 59 and 27 functions is
accurate over a wide frequency range (10 to 80 Hz). When the DFT option is selected, the magnitude
calculation 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 Hz
to 55Hz for 50 Hz (nominal), outside of this range RMS calculation is used.

Power Input Options

Nominal 110/120/230/240 V ac, 50/60 Hz, or nominal 110/125/220/250 V dc. Operates properly from 85 V ac
to 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 40
VA 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 VA
at 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 to
power the relay. Burden (nominal) 46 VA @120 V ac.

Sensing Inputs
Five Voltage Inputs: Rated for a nominal voltage of 50 V ac to 140 V ac at 60 Hz or 50 Hz. Will withstand 240
V continuous 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 3IR
continuous current and 100IR for 1 second. Current transformer burden is less than 0.5 VA at 5 A, or 0.3 VA
at 1 A.

Control/Status Inputs
The 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 IPSlogicTM. To
provide breaker status LED indication on the front panel, the INPUT1 control/status input contact must be
connected to the 52b breaker status contact.
The optional expanded I/O includes an additional 8 programmable control/status inputs (INPUT7 through
INPUT14).
▲ 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 Contacts
Any of the functions can be individually programmed to activate any one or more of the eight programmable
output 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 through
OUTPUT23). 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
per ANSI/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 at 48 V dc; 0.3 A, 125 V dc; 0.2 A, 250 V dc with L/R=40 mSec.
–13–
M-3425A Generator Protection Relay

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

Target/Status Indicators and Controls

The RELAY OK LED reveals proper cycling of the microcomputer. The BRKR CLOSED LED will turn on when
the breaker is closed (when the 52b contact input is open). The OSC TRIG LED indicates that oscillographic
data has been recorded in the unit's memory. The TARGET LED will turn on when any of the relay functions
operate. Pressing and releasing the TARGET RESET button resets the target LED if the conditions causing
the operation have been removed. Holding the TARGET RESET button displays the present pickup status of
the relay functions. The PS1 and PS2 LEDs will remain on as long as power is applied to the unit and the power
supply is operating properly. TIME SYNC LED illuminates when valid IRIG-B signal is applied and time
synchronization has been established.

Communication
Communications ports include rear panel RS-232 and RS-485 ports, a front panel RS-232 port, a rear-panel
IRIG-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™-compatible
M-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.
When the optional Ethernet port is purchased it also provides MODBUS over TCP/IP and BECO2200 over
TCP/IP protocols.

IRIG-B
The M-3425A Generator Protection Relay can accept either modulated or demodulated IRIG-B time clock
synchronization 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 via six buttons and a 2-line by 24 character
alphanumeric vacuum florescent display. Features of the HMI Module include :
• User-definable access codes allow three levels of security
• Interrogation and modification of setpoints
• 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 will light
when the corresponding function operates. The targets can be reset with the TARGET RESET pushbutton.
The OUTPUT LEDs indicate the status of the programmable output relays.

–14–
 M-3425A Generator Protection Relay

Temperature Controller Monitoring

Any Temperature Controller equipped with a contact output may be connected to the M-3425A and controlled
by the relay's IPSlogic function. Figure 1 is an example of a typical Temperature Controller Monitoring
application.

Temperature
Controller M-3425A

R1 IN X
C Alarm/Trip
IN RTN

R2

Omron E5C2 IPSlogic

P.D. 750
or equivalent

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/status
inputs. Output LEDs indicate the status of the output relays.

Tests and Standards

The relay complies with the following type tests and standards:
Voltage Withstand
Dielectric Withstand
IEC 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 circuit
1,500 V dc for 1 minute applied to IRIG-B circuit to earth
1,500 V dc for 1 minute applied between IRIG-B to each independent circuit
1,500 V dc for 1 minute applied between RS-485 to each independent circuit

Impulse Voltage
IEC 60255-5 5,000 V pk, +/- polarity applied to each independent circuit to earth
5,000 V pk, +/- polarity applied between each independent circuit
1.2 by 50 μs, 500 ohms impedance, three surges at 1 every 5 seconds

Insulation Resistance
IEC 60255-5 > 40 Megaohms

–15–
M-3425A Generator Protection Relay

Electrical Environment
Electrostatic Discharge Test
EN 60255-22-2 Class 4 (8 kV)—point contact discharge
EN 60255-22-2 Class 4 (15kV)–air discharge

Fast Transient Disturbance Test

EN 60255-22-4 Class A (4 kV, 2.5 kHz)

Surge Withstand Capability

ANSI/IEEE 2,500 V pk-pk oscillatory applied to each independent circuit to earth
C37.90.1- 2,500 V pk-pk oscillatory applied between each independent circuit
1989 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 earth

C37.90.1- 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 communication
port and field ground coupling port) through capacitive coupling clamp.

Radiated Susceptibility
ANSI/IEEE 25-1000 Mhz @ 35 V/m
C37.90.2

Output Contacts
ANSI/IEEE Make 30 A for 0.2 seconds, off for 15 seconds for 2,000 operations, per Section 6.7.1, Tripping
C37.90.0 Output Performance Requirements

Atmospheric Environment
Temperature
IEC 60068-2-1 Cold, –20° C
IEC 60068-2-2 Dry Heat, +70° C
IEC 60068-2-3 Damp Heat, +40° C @ 93% RH

Mechanical Environment
Vibration
IEC 60255-21-1Vibration response Class 1, 0.5 g
Vibration endurance Class 1, 1.0 g

IEC 60255-21-2Shock Response Class 1, 5.0 g

Shock Withstand Class 1, 15.0 g
Bump Endurance Class 1, 10.0 g

–16–
 M-3425A Generator Protection Relay

Compliance
UL-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 (Pending for expanded I/O option.)

Physical
Without 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 to
ANSI/EIA RS-310C and DIN 41494 Part 5 specifications. Vertical or horizontal panel-mount options are
available.
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)

Patent & Warranty

The 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 Connections
M-3425A external connection points are illustrated in Figures 2 and 3.

–17–
 3
2

BECKW IT H ELECT RIC CO . INC. W A RNING! CO NT A CT W IT H T ERMINA L S MA Y CA US E EL ECT RIC S HO CK MODEL: M-3425A FIRMWARE: D-0150
R

R
6 19 0 118 t h AV E NO . FO R CO NT A CT RA T INGS S EE INS T RUCT IO N MA NUA L
5 0 Hz 6 0 Hz S ERIA L NO .
8 3 F4
L A RGO , FL 3 3 7 7 3 727- 5 4 4 - 23 26
L IS T ED NRT L / C
IND.CO NT .EQ LR 8 9 4 6 4 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34

IRIG- B COM 2
COM2 RS 2 3 2
ETHERNET 24 IN IN IN IN IN IN IN
48 - + - +
! 125
6 5 4 3 2 1 RT N
250 ! P/ S S ELF- T EST 8 7 6 5 4 3 2 1
RS 4 8 5 (5 2 b)
1 A UX COM 3 INPUTS A LA RMS OUT PUTS
V V V
A B C VN IA IB IC IN Ia Ib Ic PS 2 PS 1 PS2 PS1
! F IE L D G N D VA B VB C VC A
COUPLER + - + -
F1 F2
4
3 A MP,2 5 0 V ( 3 A B)
M-3425A Generator Protection Relay

35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63
64 VX 65 64S 18 - 5 6 18 - 5 6
64F 0 .0 1A NO M 85 265 85 265
F3 F4
RA T ED V O L T A GE
RAT ED CURRENT
6 0 - 14 0 V A C,5 0 / 6 0 Hz 1A ,NO M 5 A ,NO M

Figure 2 External Connections (Without Optional Expanded I/O)

■ NOTES:

–18–
1. See M-3425A Instruction Book Section 2.3, Setpoints and Time Settings, subsection for 64B/F Field Ground Protection.
2. Before making connections to the Trip Circuit Monitoring input, see M-3425A Instruction Book Section 5.5, Circuit Board Switches and Jumpers,
for the information regarding setting Trip Circuit Monitoring input voltage. Connecting a voltage other than the voltage that the unit is configured
to may result in mis-operation or permanent damage to the unit.
3. 8 WARNING: ONLY DRY CONTACTS must be connected to inputs (terminals 5 through 10 with 11 common) because these contact
inputs are internally wetted. Application of external voltage on these inputs may result in damage to the units.
4. 8 WARNING: The protective grounding terminal must be connected to an earthed ground any time external connections have been
made to the unit.
 BECKW IT H ELECT RIC CO . INC. W A RNING! CO NT A CT W IT H T ERMINA L S MA Y CA US E EL ECT RIC S HO CK MODEL: M-3425A FIRMWARE: D-0150
6 19 0 118 t h AV E NO .
FO R CO NT A CT RA T INGS S EE INS T RUCT IO N MA NUA L 5 0 Hz 6 0 Hz S ERIA L NO .
L A RGO , FL 3 3 7 7 3 727- 5 4 4 - 23 26

66 67 68 69 70 71 72 73 74 75 76 77 78 79 80 81 82 83 84 85 86 87 88 89 90 91 92 93 94 95 96 97 98 99 100 101 102 103 104 105 97

IN IN IN IN IN IN IN IN IN
RT N 14 13 12 11 10 9 8 7
R
C US 23 22 21 20 19 18 17 16 15 14 13 12 11 10 9
83F4 INPUTS OUT PUTS
2 LIST ED
IND. CONT . EQ . 12 15 16 19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34
1 2 3 4 5 6 7 8 9 10 11 13 14 17 18

IRIG- B COM 2
RS 2 3 2
1 24 IN IN IN IN IN IN IN
48 - + - +
COM 2 ! 125
6 5 4 3 2 1 RT N 6 5 4 2
ETHERNET P/ S S ELF- T EST 8 7 3 1
250 RS 4 8 5 (5 2 b) !
A UX COM 3 INPUTS A LA RMS OUT PUTS
V V V PS 1
A B C VN IA IB IC IN Ia Ib Ic PS 2 PS2 PS1
! F IE L D G N D VA B VB C VC A
COUPLER + - + -
F1 F2

3 A MP,2 5 0 V ( 3 A B)
35 36 37 38 39 40 41 42 43 44 45 46 47 48 49 50 51 52 53 54 55 56 57 58 59 60 61 62 63
64 VX 65 64S 18 - 5 6 18 - 5 6
64F 0 .0 1A NO M 85 265 85 265
F3 F4
4 RA T ED V O L T A GE 3 RAT ED CURRENT
6 0 - 14 0 V A C,5 0 / 6 0 Hz 1A ,NO M 5 A ,NO M

–19–
Figure 3 External Connections (With Optional Expaned I/O)

■ NOTES:
1. See M-3425A Instruction Book Section 2.3, Setpoints and Time Settings, subsection for 64B/F Field Ground Protection.
2. Before making connections to the Trip Circuit Monitoring input, see M-3425A Instruction Book Section 5.5, Circuit Board Switches and Jumpers,
for the information regarding setting Trip Circuit Monitoring input voltage. Connecting a voltage other than the voltage that the unit is configured
to may result in mis-operation or permanent damage to the unit.
3. 8 WARNING: ONLY DRY CONTACTS must be connected to inputs (terminals 5 through 10 with 11 common and terminals 68 through
75 with 66 and 67 common) because these contact inputs are internally wetted. Application of external voltage on these inputs may
result in damage to the units.
4. 8 WARNING: The protective grounding terminal must be connected to an earthed ground any time external connections have been
made to the unit.
M-3425A Generator Protection Relay
M-3425A Generator Protection Relay

These functions are available in Utility System

the Comprehensive Package. A
M-3425A Typical subset of these functions are also
available in a Base Package.
Connection Diagram
52
This function is available as a
optional protective function. Unit

This function provides control for

the function to which it points.
M-3425A

Targets CT
50 50
(Optional) BFPh DT
Integral HMI VT (Note 1)
(Optional)
CT (Residual)
Metering (Note 4)

87
Waveform Capture
25 52
VT Gen
IRIG-B

Front RS232
Communication
81R 81A 81 27 59 24 M
Rear RS232
Communication (Metering) VT (Note 1)
Rear Ethernet
Port (Optional)
Rear RS-485 (Note 3)
Communication M-3921
59X +
Multiple Setting
Groups
-

Programmable I/O
64F 64B
27

Self Diagnostics

Dual Power Supply 60 CT

78 FL 51V 50/27 40 32 21 50 49 46 M
(Optional)
(Metering)
Breaker
Monitoring 3VO (Calculated) 67N Operating Current
VX (Software Select)
Trip Circuit IN
VN 50 50N 51N
Monitoring 67N Polarization
BFN
(Software Select) 67N
3IO
Event Log
(Note 5)
3V O (Calculated) VX

CT (Neutral)
59D Line Side 87 50 50N 51N (Notes 2 & 5)
Voltage 27
27 GD BFN
(Software Select) 59D 64S 59N R
32
TN
R

High-impedance Grounding with Third Low-impedance Grounding with Ground Differential

Harmonic 100% Ground Fault Protection and Overcurrent Stator Ground Fault Protection
■ NOTES:
1. When 25 function is enabled, 59X, 59D with VX and 67N with VX 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 IN can be connected either from neutral current or residual current.
5. The 50BFN, 50N, 51N, 59D, 67N (with IN or VN) 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)

–20–
 M-3425A Generator Protection Relay

These functions are available in

the Comprehensive Package. A Utility System
M-3425A Typical subset of these functions are also
available in a Base Package.
Connection Diagram
(Configured for Split-Phase Differential) This function is available as a 52
optional protective function. Unit

This function provides control for

the function to which it points.
M-3425A
VT (Note 1)

Targets CT (Residual)
(Optional) (Note 5)

Integral HMI
(Optional) 25 52
VT Gen
Metering

Waveform Capture

81R 81A 81 59 27 24 M
IRIG-B
(Metering)
50 CT (Note 3)
Front RS232 DT
Communication
Rear RS232
Communication VT (Note 1)

Rear Ethernet
Port (Optional)
(Note 2)
Rear RS-485 M-3921
Communication 59X +

Multiple Setting
Groups -

Programmable I/O 64F 64B

27

Self Diagnostics
CT
78 60FL 51V 50/27 40 32 21 50 49 46 M
Dual Power Supply
(Optional) (Metering)

Breaker
Monitoring
Trip Circuit
Monitoring 3VO (Calculated)
(Note 4)
VX
Event Log 67N
VN 67N Polarization
(Software Select)

VX 3VO (Calculated)

59D Line Side CT

CT (Neutral)
Voltage 27
50N 51N (Note 5)
(Software Select) 59D 27 64S 59N R
32
TN
R

High-impedance Grounding with Third Low-impedance Grounding with

Harmonic 100% Ground Fault Protection Overcurrent Stator Ground Fault Protection
■ NOTES:
1. When 25 function is enabled, 59X, 59D with VX and 67N with VX are not available, and vice versa.
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.
6. The 50BFN, 50N, 51N, 59D, 67N (with IN or VN) and 87GD functions are unavailable when the 64S
function has been purchased. See the M-3425A Instruction Book for connection details.
Figure 5 One-Line Functional Diagram (configured for split-phase diffential)

–21–
M-3425A Generator Protection Relay

17.48 [44.4]
ACTUAL

5.21 [13.23]
ACTUAL

Rear View

10.20 [25.91]

19.00
[48.26]

19.00 [48.26]
0.33
18.34 [46.58] [0.84]

0.40 [1.02] x 0.27 [0.68] SLOT (4x)

2.35 [5.96]

1.35 [3.42]

Standard 19" Horizontal Mount Chassis

n NOTE: Dimensions in brackets are in centimeters.

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

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

–22–
 M-3425A Generator Protection Relay

10.20
[25.9]

19.00
[48.26]
.25 X .45 SLOT [.64 X 1.14]
4 PLACES

OUTPUTS
9 10 11 12 13 14 15 16 17 18 19 20 21 22 23

COM 1
RELAY BRKR
TARGET
TARGET
4.00 OK CLOSED TARGET PS 1
RESET
[10.16]
TIME OSC. PS 2
6.96 SYNC TRIG
[17.68]
M-3425A
GENERATOR PROTECTION
R

B EC KWIT H
CO . INC .
E L EC T R IC
OUTPUTS
Made in U.S.A. EXIT ENTER OUT 1 OUT 3 OUT 5 OUT 7
1.48 OUT 2 OUT 4 OUT 6 OUT 8
3.76

0.33 18.34
[0.84] [46.58]

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

–23–
M-3425A Generator Protection Relay

5.65
[13.41]

0.40 [1.02] x
0.27 [0.68] 5.59
SLOT (4x) [14.20]
0.33 2.25 ACTUAL
[0.84] [5.72] 1.71
[4.34]

17.5
[44.45]
19.00
[48.26] 17.31
18.34 [43.97]
[46.58] Actual

Rear View
n NOTE: Dimensions in brackets are
in centimeters.
RECOMMENDED CUTOUT WHEN
RELAY IS A PANEL MOUNT

Optional Vertical Mount Chassis

■ 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)

–24–
 M-3425A Generator Protection Relay

18.34
.34 [46.17]
[.86] 17.50
[44.45]

1.48
[3.76]

2.25
[5.72]
5.28
[13.40]
\U+2205.28 (4X)

RECOMMENDED CUTOUT
STANDARD 3 UNIT PANEL M-3425A

18.34
.34 [46.17]
[.86] 17.50
[44.45]
1.48
[3.76]

7.03
[17.86]
4.00
[10.16]

\U+2205.28 (4X)

RECOMMENDED CUTOUT
4 UNIT PANEL M-3425A (EXTENDED I/O)
TOLERANCE: .XX±.015

Figure 9 M-3425A Panel Mount Cutout Dimensions

–25–
M-3425A Generator Protection Relay

M-3921 Field Ground Coupler

PROTECTION RELAY
M-3425A

PROCESSOR

Excitation
System

Field Ground Brushes

Detection

Squarewave
Generator Gen.
Rotor

Signal COUPLING
Measurement NETWORK
and Processing (M-3921)

Shaft
Ground
Brush

Ground/Machine Frame

Figure 10 Field Ground Protection Block Diagram

„ NOTES:
1. The above circuit measures insulation resistance (Rf) between rotor field winding and ground (64F).
2. Relay injects 15 V squarewave (Vout) and measures return signal (Vf) to calculate Rf.
3. The injection frequency can be set (0.1 to 1.0 Hz) based on the rotor capacitance, in order to
improve 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 pilot
ground fault detection brush.

Function Specification
Field/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 & Warranty

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

Tests and Standards

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

–26–
 M-3425A Generator Protection Relay

Voltage Withstand
Isolation
4 kV ac for 1 minute, all terminals to case

Impulse Voltage
IEC 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 Interference
Electrostatic Discharge Test
IEC 61000-4-2 Class 4 (8 kV)—point contact discharge

Fast Transient Disturbance Tests

IEC 61000-4-4 Class 4 (4 kV, 2.5 kHz)

Surge Withstand Capability

ANSI/IEEE 2,500 V pk-pk oscillatory applied to each independent circuit to earth
C37.90.1- 2,500 V pk-pk applied between each independent circuit
1989 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 Susceptibility
ANSI/IEEE 25-1000 Mhz @ 20 V/m
C37.90.2

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

Enclosure Protection
NEMA 1, IEC IPC-65

–27–
 7.87 [19.99] 2.96 REF [7.52]

3.54 [9.0] M-3921

Field Ground
4.72 [11.99] Coupler

BECKWIT H
CO. INC.
EL ECT RIC

Made in U.S.A.

9.06 [23.01]

.18 DIA [0.46] 4 X 7.40

[18.79]

.18 DIA [0.46] 4 HOLES

3.54 [9.0]

MOUNTING PATTERN
WITHOUT TABS

nNOTE: Dimensions in brackets are in centimeters.

Figure 11 M-3921 Field Ground Coupler Mounting Dimensions

2 00
0
BECKWITH ELECTRIC CO., INC.
1:
d
re

6190 - 118th Avenue North • Largo, Florida 33773-3724 U.S.A.

0
te
90

is
Re
g PHONE (727) 544-2326 • FAX (727) 546-0121
IS O

E-MAIL marketing@beckwithelectric.com
WEB PAGE www.beckwithelectric.com

© 2001 Beckwith Electric Co.

Printed in U.S.A. (#01-67) (04.25.03) 800-3425A-SP-01MC5 1/06
 WARNING
DANGEROUS VOLTAGES, capable of causing death or serious
injury, are present on the external terminals and inside the equip-
ment. Use extreme caution and follow all safety rules when han-
dling, testing or adjusting the equipment. However, these internal
voltage levels are no greater than the voltages applied to the exter-
nal terminals.

DANGER! HIGH VOLTAGE

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

PERSONNEL SAFETY PRECAUTIONS

The 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 intended
use of the product. Qualified personnel should be the only ones who operate and maintain this equipment. Beckwith
Electric 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 servicing
equipment in a test area, the Protective Earth Terminal must be attached to a separate ground securely
by use of a tool, since it is not grounded by external connectors.

Do NOT operate in an explosive environment

Do not operate this equipment in the presence of flammable or explosive gases or fumes. To do so would
risk a possible fire or explosion.

Keep away from live circuits

Operating 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 and
discharge circuits before working on the unit.

Exercise care during installation, operation, & maintenance procedures

The 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 equipment

Do not perform any unauthorized modifications on this instrument. Return of the unit to a Beckwith
Electric repair facility is preferred. If authorized modifications are to be attempted, be sure to follow
replacement procedures carefully to assure that safety features are maintained.
PRODUCT CAUTIONS
Before attempting any test, calibration, or maintenance procedure, personnel must be completely familiar
with the particular circuitry of this unit, and have an adequate understanding of field effect devices. If a
component is found to be defective, always follow replacement procedures carefully to that assure safety
features are maintained. Always replace components with those of equal or better quality as shown in the
Parts List of the Instruction Book.

Avoid static charge

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

Use caution when measuring resistances

Any attempt to measure resistances between points on the printed circuit board, unless otherwise noted
in 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 version
D-0150-V01.00.33 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
 Table of Contents

Table of Contents
M-3425A Generator Protection
Instruction Book

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 ...................................................................................... 2–1
Profiles ................................................................................................ 2–2
Functions ............................................................................................ 2–2
Special Considerations ........................................................................ 2–2
Relay System Setup .......................................................................... 2–3
2.2 System Diagrams ............................................................................... 2–7
2.3 Setpoints and Time Settings ........................................................... 2–13
21 Phase Distance ........................................................................... 2–14
24 Overexcitation Volts/Hz .............................................................. 2–18
25 Sync Check ................................................................................. 2–21
27 Phase Undervoltage .................................................................... 2–25
27TN Third Harmonic Undervoltage, Neutral .................................. 2–26
32 Directional Power ........................................................................ 2–30
40 Loss of Field ............................................................................... 2–35
46 Negative Sequence Overcurrent ................................................. 2–39
49 Stator Overload Protection ......................................................... 2–41
50/50N Instantaneous Overcurrent,Phase & Neutral Circuits ........ 2–44
50BF Generator Breaker Failure/HV Breaker Flashover................. 2–46
50DT Definite Time Overcurrent (for split-phase differential) ........ 2–49
50/27 Inadvertant Energizing ........................................................... 2–50
51N Inverse Time Neutral Overcurrent ............................................ 2–52
51V Inverse Time Phase Overcurrent with
Voltage Control/Restraint ................................................................. 2–53
59 Phase Overvoltage ...................................................................... 2–55
59D Third Harmonic Voltage Differential ......................................... 2–56
59N Overvoltage, Neutral Circuit or Zero Sequence ...................... 2–58
59X Multipurpose Overvoltage (Turn-to-Turn Stator Fault
or Bus Ground Protection) ............................................................... 2–59
60FL VT Fuse Loss ......................................................................... 2–61
64B/F Field Ground Protection ........................................................ 2–64
64F Field Ground Protection ............................................................ 2–64
64B Brush Lift-Off Detection ........................................................... 2–66
64S 100% Stator Ground Protection by Low Frequency
Signal Injection ................................................................................. 2–67

i
M-3425A Instruction Book

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

Chapter 2 Application (cont'd)

67N Residual Directional Overcurrent ............................................. 2–70
78 Out of Step .................................................................................. 2–73
81 Frequency .................................................................................... 2–76
81A Frequency Accumulators ............................................................ 2–78
81R Rate of Change of Frequency ...................................................... 2–80
87 Phase Differential .......................................................................... 2–81
87GD Ground (Zero Sequence) Differential ......................................... 2–83
Breaker Monitoring.............................................................................. 2–84
Trip Circuit Monitoring .........................................................................2–85
IPSlogic ..............................................................................................2–87

Chapter 3 Operation
3.1 Front Panel Controls ............................................................................ 3–1
Alphanumeric Display .......................................................................... 3–1
Screen Blanking .................................................................................. 3–1
Arrow Pushbuttons .............................................................................. 3–1
Exit Pushbutton ................................................................................... 3–1
Enter Pushbutton ................................................................................. 3–1
Target & Status Indicators and Controls .............................................. 3–1
Power Supply #1 (#2) LED ................................................................... 3–2
Relay OK LED ..................................................................................... 3–2
Oscillograph Recorded LED ................................................................. 3–2
Breaker Closed LED ............................................................................ 3–2
Target Indicators and Target Reset ..................................................... 3–2
Time Sync LED ................................................................................... 3–2
Diagnostic LED .................................................................................... 3–2
Accessing Screens ............................................................................. 3–2
Default Message Screens .................................................................. 3–2
3.2 Initial Setup Procedure/Settings ........................................................ 3–5
3.3 Setup Unit Data ................................................................................... 3–5
Setup Unit Data Entry .......................................................................... 3–5
Setup Unit Features That Do Not Require Data Entry .......................... 3–6
3.4 Setup System Data ............................................................................. 3–6
Configure Relay Data ........................................................................... 3–7
Setpoints and Time Settings ............................................................... 3–7
Oscillograph Recorder Data ................................................................. 3–8
Communications Settings .................................................................... 3–8
3.5 Status/Metering ................................................................................... 3–9
3.6 Target History .....................................................................................3–10

ii
 Table of Contents

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

Chapter 4 Remote Operation

4.1 Remote Operation............................................................................... 4–1
Serial Ports (RS-232) ......................................................................... 4–1
Serial Port (RS-485) ............................................................................. 4–1
Optional Ethernet Port ......................................................................... 4–1
Direct Connection ................................................................................ 4–2
Setting up the M-3425A Generator Protection
Relay for Communication ..................................................................... 4–3
Serial Communication Settings............................................................ 4–3
Ethernet Communication Settings ....................................................... 4–3
DHCP Protocol .................................................................................... 4–3
Ethernet Protocols ............................................................................... 4–3
Ethernet Port Setup ............................................................................. 4–4
HMI Ethernet Port Setup ..................................................................... 4–4
Manual Configuration of Ethernet Board .............................................. 4–5
IPSutil™ Ethernet Port Setup with DHCP ............................................ 4–5
IPSutil Ethernet Port Setup without DHCP .......................................... 4–5
Installing the Modems ........................................................................ 4–7
4.2 Installation and Setup (IPScom®) ........................................................ 4–8
4.3 Operation ............................................................................................ 4–8
Activating Communications................................................................ 4–8
Overview ............................................................................................. 4–9
File Menu ............................................................................................ 4–9
Comm Menu ....................................................................................... 4–9
Relay Menu ....................................................................................... 4–10
Window 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 ......................................................4–29
M-3890 IPSutil ...................................................................................4–29
Installation and Setup .........................................................................4–29
Installation ..........................................................................................4–30
System Setup ....................................................................................4–30
Overview.............................................................................................4–30
Comm Menu .......................................................................................4–30
Relay Comm Command ......................................................................4–30
Ethernet Command .............................................................................4–30
Clock Command .................................................................................4–30
Security Menu ....................................................................................4–31
Miscellaneous Menu ...........................................................................4–31
Help Menu ..........................................................................................4–32

iii
M-3425A Instruction Book

Figures - Part 1 of 2 Page

Chapter 1
1-1 M-3925A Target Module ..................................................................... 1–3
1-2 M-3931 Human-Machine Interface (HMI) Module............................. 1–4

Chapter 2
2-1 Setup System Dialog Box ................................................................. 2–5
2-2 Selection Screen for Expanded Input ............................................... 2–6
2-3 Pulse Relay Expanded Output Screen .............................................. 2–6
2-4 Latch Relay Expanded Output Screen .............................................. 2–6
2-5 One-Line Functional Diagram ............................................................. 2–7
2-6 Alternative One-Line Functional Diagram
(configured for split-phase differential) .............................................. 2–8
2-7 Three-Line Connection Diagram ......................................................... 2–9
2-8 Function 25 Sync Check Three-Line Connection Diagram............. 2–10
2-9 Function 59X Turn-to-Turn Fault Protection Three-Line
Connection Diagram ......................................................................... 2–11
2-10 Function 67N, 59D, 59X (Bus Ground) Three-Line
Connection Diagram ......................................................................... 2–12
2-11 Selection Screen for Expanded I/O Initiate .................................... 2–13
2-12 Phase Distance (21) Coverage ........................................................ 2–15
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 ... 2–27
2-21 27TN Blocking Regions .................................................................... 2–28
2-22 Third Harmonic Undervoltage, Neutral Circuit (27TN)
Setpoint Ranges ............................................................................... 2–29
2-23 Tripping on Reverse Power Flow
(Over Power with Negative Pickup) ................................................. 2–31
2-24 Tripping on Low Foward Power
(Under Power with Positive Pickup) ................................................ 2–32
2-25 Tripping on Overpower (Over Power with Positive Pickup) ........... 2–32

iv
 Table of Contents

Figures - Part 1 of 2 Page

Chapter 2 (cont'd)
2-26 Tripping on Over Reactive Power with Element #3
(Over Power, Positive Pickup and Directional Power Sensing
Set to Reactive) ............................................................................... 2–33
2-27 Directional Power, 3-Phase (32) Setpoint Ranges .......................... 2–34
2-28 Loss of Field (40) Protective Approach 1 ....................................... 2–37
2-29 Loss of Field (40) Protective Approach 2 ....................................... 2–37
2-30 Loss of Field (40) Setpoint Ranges ................................................ 2–38
2-31 Negative Sequence Overcurrent Inverse Time Curves .................. 2–40
2-32 Negative Sequence Overcurrent (46) Setpoint Ranges .................. 2–40
2-33 Time Constant, Function 49 ............................................................ 2–41
2-34 49 Function Overload Curves .......................................................... 2–42
2-35 Stator Thermal Protection (49) Setpoint Ranges ............................ 2–43
2-36 Instantaneous Overcurrent (50) Setpoint Ranges ........................... 2–44
2-37 Instantaneous Neutral Overcurrent (50N) Setpoint Ranges ........... 2–45
2-38 Breaker Failure Logic Diagram ........................................................ 2–47
2-39 Breaker Failure (50BF) Setpoint Ranges ........................................ 2–48
2-40 Definite Time Overcurrent (50DT) Setpoint Ranges ....................... 2–49
2-41 Inadvertent Energizing Function Logic Diagram ............................. 2–51
2-42 Inadvertent Energizing (50/27) Setpoint Ranges ............................ 2–51
2-43 Inverse Time Neutral Overcurrent (51N) Setpoint Ranges ............. 2–52
2-44 Voltage Restraint (51VR) Characteristic ......................................... 2–54
2-45 Inverse Time Overcurrent with Voltage Control/Voltage
Restraint (51VC/VR) Setpoint Ranges ............................................ 2–54
2-46 Phase Overvoltage (59) Setpoint Ranges ....................................... 2–55
2-47 Third Harmonic Overvoltage Scheme for Generator
Ground-Fault Protection ................................................................... 2–57
2-48 Third Harmonic Voltage Differential (59D) Setpoint Ranges .......... 2–57
2-49 Overvoltage, Neutral Circuit or Zero Sequence (59N)
Setpoint Ranges ............................................................................... 2–58
2-50 Turn-to-Turn Stator Winding Fault Protection ................................. 2–59
2-51 Multipurpose Overvoltage (59X) Setpoint Ranges .......................... 2–60
2-52 Fuse Loss (60FL) Function Logic .................................................... 2–62
2-53 Fuse Loss (60FL) Setpoint Ranges ................................................. 2–63
2-54 M-3921 Field Ground Coupler .......................................................... 2–64
2-55 Field Ground Protection (64B/F) Setpoint Ranges ......................... 2–65

v
M-3425A Instruction Book

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

Chapter 2 (cont'd)
2-56 64S Function Component Connection Diagram .............................. 2–68
2-57 64S Function Time Delay Pickup Current Correlation .................... 2–68
2-58 100% Stator Ground Protection (64S) Setpoint Ranges ................ 2–69
2-59 Residual Directional Overcurrent (67N) Trip Characteristics .......... 2–70
2-60 Residual Directional Overcurrent (67N) Setpoint Ranges ............... 2–72
2-61 Out-of-Step Relay Characteristics ................................................... 2–74
2-62 Out-of-Step Protection Settings ....................................................... 2–74
2-63 Out-of-Step (78) Setpoint Ranges ................................................... 2–75
2-64 Example of Frequency (81) Trip Characteristics ............................ 2–77
2-65 Frequency (81) Setpoint Ranges ..................................................... 2–77
2-66 Frequency Accumulator (81A) Example Bands .............................. 2–79
2-67 Frequency Accumulator (81A) Setpoint Ranges ............................. 2–79
2-68 Rate of Change of Frequency (81R) Setpoint Ranges ................... 2–80
2-69 Differential Relay (87) Operating Characteristics............................ 2–81
2-70 Phase Differential (87) Setpoint Ranges ......................................... 2–81
2-71 Ground Differential (87GD) Setpoint Ranges .................................. 2–83

2-72 Breaker Monitor (BM) Setpoint Ranges........................................... 2–84

2-73 Trip Circuit Monitoring Input ............................................................ 2–85

2-74 Trip Circuit Monitor (TC) Setpoint Ranges ...................................... 2–86

2-75 IPSlogic™ Function Setup ............................................................... 2–88

2-76 IPSlogic Function Programming ......................................................... 2–89

2-77 Selection Screen for Initiating Function Timeout ................................ 2–90
2-78 Selection Screen for Initiating Function Pickup ..................................2–90
2-79 Dropout Delay Timer Logic Diagram ................................................... 2–91
2-80 Reset Delay Timer Logic Diagram ...................................................... 2–91

Chapter 3
3-1 M-3425A Front Panel ......................................................................... 3–3
3-2 Screen Message Menu Flow ............................................................. 3–3
3-3 Main Menu Flow ................................................................................. 3–4

vi
 Table of Contents

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

Chapter 4
4-1 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

vii
M-3425A Instruction Book

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

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 1
1-1 M-3425A Device Functions ................................................................ 1–2

Chapter 2
2-1 Input Activated Profile ....................................................................... 2–3
2-2 Impedance Calculation ..................................................................... 2–17
2-3 Voltage Control Time Settings ......................................................... 2–36
2-4 Delta/Wye Transformer Voltage-Current Pairs ................................ 2–54
2-5 Typical Frequency Settings ............................................................. 2–65
2-6 Typical Brush Lift-Off Settings ........................................................... 2–66

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

Chapter 4
4-1 Dead-Sync Time .................................................................................. 4–3
4-2 Microsoft Windows Keyboard Shortcuts ............................................. 4–28

viii
 Table of Contents

Chapters - Part 2 of 2 Page

Chapter 5 Installation
5.1 General Information ............................................................................ 5–1
5.2 Mechanical/Physical Dimensions ...................................................... 5–1
5.3 External Connections ......................................................................... 5–9
5.4 Commissioning Checkout ................................................................ 5–15
5.5 Circuit Board Switches and Jumpers .............................................. 5–20

Chapter 6 Testing
6.1 Equipment/Test Setup ........................................................................ 6–2
6.2 Functional Test Procedures ............................................................... 6–6
Power On Self Tests ......................................................................... 6–7
21 Phase Distance .............................................................................. 6–8
24 Volts per Hertz, Definite Time ......................................................... 6–9
24 Volts per Hertz, Inverse Time ........................................................6–10
25D Dead Check ................................................................................6–12
25S Sync Check ................................................................................6–14
27 Phase Undervoltage .......................................................................6–16
27TN Third-Harmonic Undervoltage, Neutral .......................................6–17
32 Directional Power, 3-Phase ............................................................ 6–21
40 Loss of Field ..................................................................................6–24
46 Negative Sequence Overcurrent Definite Time ..............................6–26
46 Negative Sequence Overcurrent Inverse Time ..............................6–27
49 Stator Overload Protection ......................................................... 6–28
50 Instantaneous Phase Overcurrent .............................................. 6–30
50BF/50BF-N Breaker Failure .......................................................... 6–31
50/27 Inadvertant Energizing ........................................................... 6–33
50DT Definite Time Overcurrent for Split-Phase Differential ......... 6–34
50N Instantaneous Neutral Overcurrent ......................................... 6–35
51N Inverse Time Neutral Overcurrent .......................................... 6–36
51V Inverse Time Phase Overcurrent with
Voltage Control/Restraint ................................................................. 6–37
59 RMS Overvoltage, 3-Phase ........................................................ 6–39
59D Third-Harmonic Voltage Differential ......................................... 6–40
59N Overvoltage, Neutral Circuit or Zero Sequence ...................... 6–41
59X Multipurpose Overvoltage ............................................................6–42
60FL VT Fuse Loss Detection ............................................................6–43
64F Field Ground Protection ...............................................................6–44
64B Brush Lift Off Detection...............................................................6–46
64S 100% Stator Ground Protection by Injection ...............................6–47
67N Residual Directional Overcurrent, Definite Time ..........................6–49
67N Residual Directional Overcurrent, Inverse Time ..........................6–51
78 Out of Step ....................................................................................6–53
81 Frequency ......................................................................................6–55
81A Frequency Accumulator ..............................................................6–56
81R Rate of Change of Frequency .................................................. 6–57

ix
M-3425A Instruction Book

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

Chapter 6 Testing (cont'd)

87 Phase Differential .......................................................................... 6–59
87GD Ground Differential ...................................................................6–61
BM Breaker Monitoring ....................................................................... 6–63
Trip Circuit Monitoring .........................................................................6–65
IPSlogic™ .......................................................................................... 6–66
6.3 Diagnostic Test Procedures ............................................................... 6–67
Overview............................................................................................. 6–67
Entering Relay Diagnostic Mode ......................................................... 6–67
Output Relay Test (Output Relays 1–23 and 25) ................................ 6–68
Output Relay Test (Power Supply Relay 24) ...................................... 6–69
Input Test (Control/Status) ................................................................. 6–69
Status LED Test ................................................................................. 6–70
Target LED Test ................................................................................. 6–71
Expanded Input/Output Test............................................................... 6–71
Button Test......................................................................................... 6–71
Display Test ....................................................................................... 6–72
COM1/COM2 Loopback Test .............................................................. 6–72
COM3 Test (2-wire) ............................................................................6–73
Clock ON/OFF .................................................................................... 6–74
Relay OK LED Flash/Illuminated ........................................................ 6–75
Auto Calibration ..................................................................................6–75
Factory Use Only ...............................................................................6–75
6.4 Auto Calibration ..................................................................................6–76
Phase and Neutral Fundamental Calibration ....................................... 6–76
Third Harmonic Calibration ................................................................. 6–77
64S 100% Stator Ground by Low Frequency Injection Calibration ...... 6–77
Field 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: Declaration of Conformity ............................................. E–1

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 Table of Contents

Figures - Part 2 of 2 Page

Chapter 5
5-1 M-3425A Mounting Dimensions – Horizontal Chassis ..................... 5–2
5-2 M-3425A Mounting Dimensions – Horizontal
Chassis (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
5-7 (H4) Mounting Dimensions .................................................................. 5-8
5-8 Optional Dual Power Supply .............................................................. 5–9
5-9 Expanded I/O Power Supply .............................................................. 5–9
5-10 External Connections ....................................................................... 5–10
5-11 Three-Line Connection Diagram ....................................................... 5–11
5-12 Function 25 Sync Check Three-Line Connection Diagram............. 5–12
5-13 Function 59X Turn-to-Turn Fault Protection Three-Line
Connection Diagram ......................................................................... 5–13
5-14 Function 67N, 59D, 59X (Bus Ground), Three-Line
Connection Diagram ......................................................................... 5–14
5-15 M-3425A Circuit Board ........................................................................5–22
5-16 M-3425A Circuit Board (Expanded I/O) ........................................... 5–23

Chapter 6
6-1 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
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

xi
M-3425A Instruction Book

Figures (cont'd) Page

Chapter 6 (cont'd)
6-14 Voltage Input Configuration ................................................................6–79
6-15 Voltage Input Configuration ................................................................6–79
6-16 Voltage Input Configuration ................................................................6–80

Appendix A
A-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 B
B-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 D
D-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

xii
 Table of Contents

Tables - Part 2 of 2 Page

Chapter 5
5-1 Jumpers ............................................................................................ 5–20
5-2 Dip Switch SW-1 .............................................................................. 5–21
5-3 Trip Circuit Monitor Input Voltage Select Jumper Configuration .... 5–21

Chapter 6
6-1 Output Contacts ............................................................................... 6–68
6-2 Input Contacts .................................................................................. 6–69

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

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

Appendix C
C-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

Appendix E
E-1 Declaration of Conformity .................................................................. E–2

©1998 Beckwith Electric Co.

Printed in U.S.A. (9.21.01) 800-3425A-IB-01MC6 01/06

xiii
M-3425A Instruction Book

This Page Left Intentionally Blank

xiv
 Introduction – 1

1 Introduction

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 five Chapter 4: Remote Operation
Appendices. Chapter 4 is designed for the person or group
responsible for the remote operation and setting of
Chapter 1: Introduction the relay using the M-3820D IPScom ®
Communications Software or other means.
Chapter One summarizes relay capabilities,
introduces the instruction book contents, and
describes accessories. Chapter 5: Installation
The person or group responsible for the installation
Chapter 2: Application of the relay will find herein all mechanical information
required for physical installation, equipment ratings,
Chapter Two is designed for the person or group and all external connections in this chapter. For
responsible for the application of the M-3425A
reference, the Three-Line Connection Diagram is
Generator Protection Relay. It includes functional
repeated from Chapter 2, Application. Further, a
and connection diagrams for a typical application of
commissioning checkout procedure is outlined using
the relay; and describes the configuration process
the HMI option to check the external CT and VT
for the unit (choosing active functions), output connections. Additional tests which may be desirable
contact assignment and input blocking designation. at the time of installation are described in Chapter
It also illustrates the definition of system quantities
6, Testing.
and equipment characteristics required by the
protective relay, and describes the individual function
settings. Chapter 6: Testing
This chapter provides step-by-step test procedures
Chapter 3: Operation for each function, as well as diagnostic mode and
autocalibration procedures for HMI-equipped units.
Chapter Three is designed for the person(s)
responsible for the operation, direct setting, and
configuration of the relay. Chapter Three provides Appendix A: Configuration Record Forms
information regarding the operation and interpretation This Appendix supplies a set of forms to record and
of the unit's front panel controls and indicators, document the settings required for the proper
including operation of the optional M-3931, Human operation of the relay.
Machine Interface (HMI) and M-3925A Target
Modules. It further describes the procedures for Appendix B: Communications
entering all required data to the relay. Included in
this chapter is a description of the process This Appendix describes port signals, protocols,
necessary for review of setpoints and timing, and various topologies, and equipment required for
monitoring function status and metering quantities, remote communication.
viewing the target history, and setup of the
oscillograph recorder.

1–1
M-3425A Instruction Book

Appendix C: Self-Test Error Codes The relay stores time-tagged target information for
This Appendix lists all the error codes and their the thirty-two most recent trips. For units equipped
definitions. with the optional M-3925A Target Module, LEDs are
used to provide a detailed visual indication of
function operation for the most recent event.
Appendix D: Inverse Time Curves
This Appendix contains a graph of the four families The unit retains up to 472 cycles of oscillograph
of Inverse Time Curves for V/Hz applications, the waveform data. This data can be downloaded and
Inverse Time Overcurrent Curves, and the IEC analyzed using the M-3801D IPSplot ® PLUS
curves. Oscillograph Analysis Software.
The unit is powered from a wide input range switch
Appendix E: Declaration of Conformity mode power supply. An optional redundant power
This Appendix contains the Beckwith Electric Co.’s supply is available for units without the Expanded
Declaration of Conformity required by ISO/IEC I/O. When expanded I/O option is selected, the unit
17050–1:2004. includes the second power supply.
The relay includes self-test, auto calibration, and
diagnostic capabilities, in addition to IRIG-B time-
1.2 M-3425A Generator
sync capability for accurate time-tagging of events.
Protection Relay

The M-3425A Generator Protection Relay is a

microprocessor-based unit that uses digital signal
processing technology to provide up to thirty-four
protective relaying functions for generator protection.
The relay can protect a generator from internal
winding faults, system faults, and other abnormal
conditions.
The available internal functions of the relay are
listed in Table 1-1. The nomenclature follows the
standards of ANSI/IEEE Std. C37.2, Standard
Electric Power Systems Device Function Numbers.
The control/status inputs can be programmed to
block any relay function and/or to trigger the
oscillograph recorder. Any of the functions or the
control/status inputs can be individually programmed
to activate any one or more of the programmable
outputs, each with a contact.
With the optional M-3931 HMI Module, all functions
can be set or examined using a local, menu-driven,
2 line by 24 character alphanumeric display. OUT
9–23 and IN 7–14 for units purchased with expanded
I/O can only be set utilizing M-3820D IPScom®
Communications Software. The module allows local
metering of various quantities, including phase,
neutral, and sequence voltages and currents, real
and reactive power, power factor, and positive
sequence impedance measurements.

1–2
 Introduction – 1

FUNCTION DESCRIPTION Communication Ports

Prote ctive Functions
There are three physical communication ports
provided on the M-3425A. If the optional RJ45
21 Phase Distance (three- zone mho Ethernet port is purchased, then the relay includes
characteristic)
four physical communication ports:
24 Volts/Hz (Inverse & Definite Time)
• COM1, located on the relay front panel, is
27 Phase Undervoltage a standard 9-pin RS-232 DTE-configured
27TN Third Harmonic Undervoltage, Neutral port. COM1 is used to locally set and
interrogate the relay using a portable
32 Directional Power
computer.
40 Loss of Field (dual- zone offset- mho
characteristic) • COM2, located on the rear of the relay, is
a standard 9-pin RS-232 DTE-configured
46 Negative Sequence Overcurrent
port. When the optional RJ45 Ethernet
49 Stator Overload Protection (Positive Port is enabled, COM2 port is disabled.
Sequence Overcurrent)
The RJ45 Ethernet port uses a 10Base-T
50 Instantaneous Phase Overcurrent type connection that accepts an RJ45
50BF Breaker Failure connector using CAT5 twisted pair cable.
50DT Definite Time Overcurrent
The Ethernet port supports MODBUS over
TCP/IP, BECO2200 over TCP/IP. The IP
50N Instantaneous Neutral Overcurrent address can be obtained automatically
50/27 Inadvertant Energizing when using the DHCP protocol if enabled,
51N Inverse Time Neutral Overcurrent
or a static IP address can be manually
entered, using the HMI.
51V Inverse Time Overcurrent, with Voltage
Control or Restraint • COM3, located on the rear terminal block
of the relay, is an RS-485 communications
59 Phase Overvoltage
port.
59D Third- Harmonic Voltage Differential
The relay may be remotely set and interrogated
59N Neutral Overvoltage utilizing either a hard-wired RS-232 serial connection
59X Multi- purpose Overvoltage or modem (COM2 when activated as RS-232, or
60F L VT Fuse- Loss Detection
COM3), or when purchased, the ethernet connection
(RJ45 activated).
67N Residual Directional Overcurrent
78 Out of Step (mho characteristic) M-3820D IPScom® Communications Software
81 Frequency IPScom is shipped standard with every relay. This
81A Frequency Accumulation software runs on a PC-compatible computer operating
81R Rate of Change of Frequency
under Microsoft Windows® 95 or later. When properly
connected using either a direct serial connection,
87 Phase Differential Current modem or ethernet network connection. IPScom
87GD Ground (zero sequence) Differential can provide the following functions:
IPS IPSlogic • Setpoint interrogation and modification
BM Breaker Monitor • Line status real-time monitoring
TC Trip Circuit Monitoring • Recorded oscillograph data downloading
Optional Prote ctive Functions
25 Sync Check
64F/64B Field Ground Protection/
Brush Lift- Off Detection
64S 100% Stator Ground Protection by
Injection

Table 1-1 M-3425A Device Functions

1–3
M-3425A Instruction Book

M-3933/M-0423 Serial Communication Cables

1.3 Accessories
The M-3933 cable is a 10-foot RS-232 cable for use
between the relay’s rear panel (COM2) port and a
M-3925A Target Module modem. This cable has a DB25 (25-pin) connector
The optional target module, shown below, includes 24 (modem) and a DB9 (9-pin) at the relay end.
individually labelled TARGET LEDs to indicate
operation of the functions on the front panel. Eight The M-0423 cable is a 10-foot null-modem RS-232
individually labelled OUTPUT LEDs will be lit as long cable for direct connection between a PC and the
as the corresponding output contact is picked up. relay’s front panel COM1 port, or the rear COM2
port. This cable has a DB9 (9-pin) connector at
each end.

TARGETS M-3931 HMI (Human-Machine Interface) Module

24 VOLTS/Hz PHASE OVERCURRENT 50 The optional HMI module provides the means to
27 PHASE UNDERVOLTAGE PHASE OVERCURRENT 51V
59 PHASE OVERVOLTAGE NEUTRAL O/C 50N/51N
interrogate the relay and to input settings, access
27TN/59D/64S STATOR GND SPLIT PHASE DIFF 50DT data, etc. directly from the front of the relay. Its
59N/59X NEUT/GND OVERVOLT STATOR OVERLOAD 49 operation is described in detail in Section 3.1, Front
32 DIRECTIONAL POWER NEG SEQ OVERCURRENT46
21 PHASE DISTANCE FIELD GND/BRUSH LIFT64F/B
Panel Controls.
40 LOSS OF FIELD FREQUENCY 81/81R/81A
78 OUT OF STEP PHASE DIFF CURRENT 87
50BF BREAKER FAILURE GND DIFF/DIR O/C 87GD/67N
50/27INADVERTENT ENRGNG TRIP CIRCUIT MONITOR TC
60FL V.T. FUSE LOSS IPS LOGIC LOGIC

OUTPUTS BECKWITH ELECTRIC CO.

M-3425A
OUT 1 OUT 3 OUT 5 OUT 7
OUT 2 OUT 4 OUT 6 OUT 8

a
Figure 1-1 M-3925A Target Module
a
a
a

EXIT ENTER

Figure 1-2 M-3931 Human-Machine

Interface (HMI) Module

M-3801D IPSplot® PLUS Oscillograph Analysis

Software Package
The IPSplot PLUS Oscillograph Analysis Software
runs in conjunction with the IPScom ®
Communications Software on any IBM
PC-compatible computer, enabling the plotting,
printing, and analysis of waveform data downloaded
from the M-3425A Generator Protection Relay.

1–4
 Application – 2

2 Application

2.1 Configuration ............................................................................... 2–1

2.2 System Diagrams ....................................................................... 2–7

2.3 Setpoints and Time Settings ................................................... 2–13

Chapter Two is designed for the person or group

responsible for the application of the M-3425A 2.1 Configuration
Generator Protection Relay. It includes functional
and connection diagrams for a typical application of Configuration of the relay consists of enabling the
the relay; and describes the configuration process functions for use in a particular application,
for the unit (enabling functions), output contact designating the output contacts each function will
assignment and input blocking designation. It also operate, and which control/status inputs will block
illustrates the definition of system quantities and the function. The choices include eight programmable
equipment characteristics required by the protective output contacts (OUT1–OUT8) and six control/status
relay, and describes the individual function settings. inputs (IN1–IN6), or OUT9–23 and IN7–14 for units
purchased with expanded I/O, plus a block choice
Menu screens in the following examples are as they for fuse loss logic operation (see Section 2.3,
would appear on units equipped with the M-3931 Setpoint and Time Settings, 60FL Fuse Loss
Human Machine Interface (HMI) Module. The same subsection for details).
setting may be entered remotely using M-3820D
IPScom® Communications Software (see Chapter The blocking control/status inputs and output contact
4, Remote Operation). assignments must be chosen before entering the
settings for the individual functions. Both may be
recorded on the Relay Configuration Table in
Appendix A, Configuration Record Forms.

2–1
M-3425A Instruction Book

Control/status input IN1 is preassigned to be the The relay allows the user to designate up to six
52b breaker status contact. If a multiple breaker logic functions which perform similarly to internal
scheme is used, the control/status input IN1 must relay functions, using IPSlogicTM. These external
be the series combination of the “52b” breaker functions may be enabled or disabled, and output
contacts. Additional user-chosen control/status contacts and blocking control/status inputs are
inputs may initiate actions such as breaker failure, chosen the same as for the internal functions. The
initiate external fuse loss detection, or trigger the external functions are described in further detail in
oscillograph recorder. Section 2.3, Setpoint and Time Settings, IPSlogic
subsection.
■ NOTE: Uppercase text indicates selection.

27#1 PHASE UNDERVOLTAGE This menu designation is required for each relay function. After enabling
disable ENABLE the function, the user is presented with the two following screens:
This submenu item assigns the blocking designations (up to six, plus
27#1 BLOCK INPUT fuse-loss logic) for the enabled function. “OR” logic is used if more than
fl i6 i5 i4 i3 i2 I1 one input is selected.
This submenu item assigns the output contacts (up to eight) for the
27#1 RELAY OUTPUT particular relay function. If no output contacts are assigned, the function
o8 o7 o6 o5 o4 o3 o2 O1 will 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®.
Profiles Functions
Up to four setpoint profiles may be used. Each Configuration of the relay consists of enabling the
profile contains a complete set of function functions for use in a particular application,
configuration and settings. One of the four profiles designating the output contacts each function will
may be designated as the Active Profile, which will operate, and which control/status inputs will block
contain the settings that the relay will actively use. the function. The choices include eight programmable
output contacts (OUT1–OUT8) and six control/status
The Active Profile may be chosen manually or by inputs (IN1–IN6)/(OUT1–OUT23 and IN1–IN14 for
contact input. When the profile Switching Method is expanded I/O units) plus a block choice for fuse
set to Manual, the HMI, remote communications or loss logic operation (see Section 2.3, Setpoint and
one of the IPSlogic elements will select the Active Time Settings, 60FL Fuse Loss subsection for
Profile. When the Switching Method is set to Input details.)
Contact, the profile is selected by the input contacts.
When Input Contact is selected, only the input Control/status inputs may also initiate actions, such
contacts can switch the relay’s profile, and none of as Breaker Failure Initiate, Trigger Oscillograph
the Manual methods will switch the profile. Recorder, Switch Setpoint Profile, or initiate an
IPSlogic function. The control/status inputs and
A Copy Profile feature is available. This feature output contacts need to be chosen before configuring
copies an image of the Active Profile to any one of the individual functions. Both can be recorded on
the other three profiles. This feature can speed up the Relay Configuration Table in Appendix A, Forms.
the configuration process. Consider, for example, a
situation where a breaker will be removed from Special Considerations
service. Two profiles will be used: an “In Service” Control/status input IN1 is preassigned to be the
profile (Profile 1), and an “Out of Service” profile 52b breaker contact. IN5 and IN6 may be used to
(Profile 2). select setpoint profiles.
Profile 2 will be identical to the “In Service” profile, Outputs 1–6 and 9–23 are form “a” contacts (normally
with the exception of the overcurrent settings. open), and outputs 7 and 8 are form “c” contacts
(center tapped “a” and “b” normally closed) contacts.
Profile 1 is set to be the Active Profile, and all
Output contacts 1–4 contain special circuitry for
setpoints entered. An image of Profile 1 will then be
copied to Profile 2 with the Copy Active Profile high-speed operation and pick up 4 ms faster than
outputs 5–8. Function 87 outputs are recommended
command. Profile 2 is then selected as the Active
to be directed to OUT1 through OUT4 contacts.
Profile, and the overcurrent setpoints modified.

▲ CAUTION: During profile switching, relay operation

is disabled for approximately 1 second.

2–2
 Application – 2

Relay System Setup values are required to be input. Several functions

The system setup consists of defining all pertinent require proper setting of these values for correct
information regarding the system quantities. Setup operation. The Nominal Voltage and Nominal Current
screens shown here may be accessed through the settings are needed for proper normalization of per
SYSTEM SETUP menu. Regardless of the functions unit quantities. CT and VT ratios are used only in
that are enabled or disabled, all System Setup monitoring and displaying system primary quantities.

Input 5 Input 6 Se le ction

Open Open Profile 1

Closed Open Profile 2

Open Closed Profile 3

Closed Closed Profile 4

Table 2-1 Input Activated Profile

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

ACTIVE SETPOINT PROFILE This screen sets the active setpoint profile.
________

This screen initiates a copy of the Active Profile to any one of the
COPY ACTIVE PROFILE
other profiles.
TO_PROFILE_1

The secondary VT voltage when primary voltage is equal to the

NOMINAL VOLTAGE
rated generator voltage. Vnominal=( V gen rated $ VT ratio) for L-L
________ Volts
VT connections. Vnominal=(Vgen rated $ (S3 VT ratio)) for L-G VT
connections.

NOMINAL CURRENT The secondary CT current of the phase CT’s with rated generator
________ Amps current. I nom = (VA $ (Vgen rated(S3) )(CT ratio) )

Indicates VT connection. (See Figure 2-7, Three-Line Connection Diagram.)

VT CONFIGURATION When line-ground voltages are used, functions 24, 27, and 59 may
line-line line-ground operate for line-ground faults. If this is not desired, the line-gnd-to-
line-line selection should be used to prevent operation of these functions
for line-ground faults.When line-gnd-to-line-line is selected, the relay
line-gnd_to_line-line internally calculates line-line voltages from line-ground voltages for all
voltage-sensitive functions. This line-gnd-to-line-line selection should
be used only for a VT line-to-ground nominal secondary voltage of
69V (not for 120 V). For this selection, the nominal voltage setting
entered should be line-line nominal voltage, which is S3 times line-ground
nominal voltage, and voltage function pickup setpoints calculation should
be made using line-to-line voltage.

When the generator is connected through a Delta-Y (delta ab or delta

DELTA-Y TRANSFORM
ac) unit transformer, the relay will internally consider the 30° phase
dis delta_ab delta_ac
shift for 51V and 21 functions.

This screen allows the user to select the phase rotation of the M-3425A
PHASE ROTATION
to match the generator.
a-c-b a-b-c

2–3
M-3425A Instruction Book

This screen allows the selection of RMS or DFT for the 59 and 27
59/27 MAGNITUDE SELECT
functions. The magnitude can be selected as the RMS of the total
rms dft waveform (including harmonics) or the RMS of the 60/50 Hz fundamental
component of the waveform using the Discrete Fourier Transform (DFT).
When the RMS option is selected, the magnitude calculation is accurate
over a wide frequency range (10 to 80 Hz) and the accuracy of the time
delay is +20 cycles. When the DFT option is selected, the magnitude
calculation is accurate near 50 or 60 Hz and the timer accuracy is &1
cycle. When a wider frequency response is needed, select RMS. For
generator protection applications, it is recommended to use the RMS
selection. RMS is the default when shipped from the factory. 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,

50DT SPLIT-PHASE DIFF this selection should be enabled. If the 50DT function is to be used as a
disable enable definite time overcurrent function, or if 50DT is not enabled, this selection
should be disabled.

If pulse relay operation is selected, output will dropout after the seal-in
PULSE RELAY
delay expires, even if the condition which caused the relay to pick up is
o8 o7 o6 o5 o4 o3 o2 o1 still out of band. When selected, latching outputs are not available. *

If any of the outputs are selected as latched, then after tripping, this
LATCHED OUTPUTS
output will stay activated, even when the tripping condition is removed.
o8 o7 o6 o5 o4 o3 o2 o1 The Latched Output can be reset using the TARGET RESET pushbutton.
When selected, Pulse Relay is not available. *
Minimum time the output contact will remain picked up to ensure proper
RELAY SEAL-IN TIME OUT1
seal-in, regardless of the subsequent state of the initiating function. Indi-
________ Cycles vidual Seal-In settings are available for all outputs.*

ACTIVE INPUT OPEN/close This designates the “active” state for the individual status input. Program-
ming uppercase (see I6) causes the “active” or “operated” condition to be
I6 i5 i4 i3 i2 i1
initiated by the external contact opening. Otherwise, external contact clo-
sure will activate the input.*
*■ Note: Settings for expanded I/O must be made through IPScom®.
V.T. PHASE RATIO Ratio of the phase VTs. Example: 13,800 V : 120 V =13,800/120=115:1
________ : 1

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

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

________ :1

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

________ : 1

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

________ : 1

2–4
 Application – 2

SETUP

SETUP SYSTEM

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

Nominal Voltage: 120 50.0 V 140.0 V

Delta-Y Transform

Nominal Current: 5.00 0.50 A 6.00 A Disable Delta-AB Delta-AC

Input Active State: 6 5 4 3 2 1

Input Active State Expanded
Open Open Open Open Open Open
Close Close Close Close Close Close

V.T. Configuration: Line to Ground Line to Line Line-Ground to Line-Line

59/27 Mag. Select: RMS 50DT Enable Relay Seal-In Time Relay Seal-In Time Expanded
DFT
Split Phase
Phase Rotation: ABC AC B Differential: Disable OUT 1: 30 8160 OUT 9: 30 8160 30 OUT 17
cycles cycles
V.T. Phase Ratio: :1 1.0 2: 30 10: 30 30 18
1.0 6550.0
3: 30 11: 30 30 19
V.T. Neutral Ratio: 1.0 :1 1.0 6550.0
4: 30 12: 30 30 20
V.T. VX Ratio 1.0 :1 1.0 6550.0
5: 30 13: 30 30 21
C.T. Phase Ratio: 10 :1 1 65500 6: 30 14: 30 30 22
C.T. Neutral Ratio: 10 :1 1 65500 7: 30 15: 30 30 23
Pulse Relay 2 2
8: 30 cycles 16: 30 cycles
Outputs: 1 2 3 4 5 6 7 8

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

Injection Frequency for F64S: 20 Hz Latch Relay Expanded Outputs

Note: Pulse/Latched Relay Outputs should be selected in 2 steps

i)Deselect Latched/Pulse Relay Outputs and Save
ii) Select Pulse/Latched Outputs and Save

Save Cancel

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 Active
State 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/Latch
Relay screen (Figures 2-3 and 2-4) to allow the selection of expanded outputs 9 through 23.
Expanded
Outputs
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 by
an opening rather than a closing external contact.

2–5
M-3425A Instruction Book

? X
Expanded Input Active State

7 Open Close 11 Open Close

OK
8 Open Close 12 Open Close

Cancel
9 Open Close 13 Open Close

10 Open Close 14 Open Close

Figure 2-2 Selection Screen for Expanded Input

? X

Pulse Relay Expanded Outputs

OUTPUT9 OUTPUT17

OUTPUT10 OUTPUT18

OUTPUT11 OUTPUT19
OUTPUT12 OUTPUT20 OK
OUTPUT13 OUTPUT21
Cancel
OUTPUT14 OUTPUT22

OUTPUT15 OUTPUT23
OUTPUT16

Figure 2-3 Pulse Relay Expanded Output Screen

? X

Latch Relay Expanded Outputs

OUTPUT9 OUTPUT17

OUTPUT10 OUTPUT18

OUTPUT11 OUTPUT19

OUTPUT12 OUTPUT20 OK
OUTPUT13 OUTPUT21
Cancel
OUTPUT14 OUTPUT22

OUTPUT15 OUTPUT23

OUTPUT16

Figure 2-4 Latch Relay Expanded Output Screen

2–6
 Application – 2

2.2 System Diagrams

These functions are available in Utility System

the Comprehensive Package. A
M-3425A Typical subset of these functions are also
available in a Base Package.
Connection Diagram
52
This function is available as a
optional protective function. Unit

This function provides control for

the function to which it points.
M-3425A

Targets CT
50 50
(Optional) BFPh DT
Integral HMI VT (Note 1)
(Optional)
CT (Residual)
Metering (Note 4)

87
Waveform Capture
25 52
VT Gen
IRIG-B

Front RS232
Communication
81R 81A 81 27 59 24 M
Rear RS232
Communication (Metering) VT (Note 1)
Rear Ethernet
Port (Optional)
Rear RS-485 (Note 3)
Communication M-3921
59X +
Multiple Setting
Groups
-

Programmable I/O
64F 64B
27

Self Diagnostics

Dual Power Supply 60 CT

78 FL 51V 50/27 40 32 21 50 49 46 M
(Optional)
(Metering)
Breaker
Monitoring 3V O (Calculated) 67N Operating Current
VX (Software Select)
Trip Circuit IN
VN 50 50N 51N
Monitoring 67N Polarization
BFN
(Software Select) 67N
3IO
Event Log
(Note 5)
3VO (Calculated) VX

CT (Neutral)
59D Line Side 87 50 50N 51N (Notes 2 & 5)
Voltage 27
27 GD BFN
(Software Select) 59D 64S 59N R
32 TN
R

High-impedance Grounding with Third Low-impedance Grounding with Ground Differential

Harmonic 100% Ground Fault Protection and Overcurrent Stator Ground Fault Protection

■ NOTES:
1. When 25 function is enabled, 59X, 59D with VX and 67N with VX 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. 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.
6. The 50BFN, 50N, 51N, 59D, 67N (with IN or VN) and 87GD functions are unavailable when the 64S
function has been purchased. See the M-3425A Instruction Book for connection details.

Figure 2-5 One-Line Functional Diagram

2–7
M-3425A Instruction Book

These functions are available in

the Comprehensive Package. A Utility System
M-3425A Typical subset of these functions are also
available in a Base Package.
Connection Diagram
(Configured for Split-Phase Differential) This function is available as a 52
optional protective function. Unit

This function provides control for

the function to which it points.
M-3425A
VT (Note 1)

Targets CT (Residual)
(Optional) (Note 5)

Integral HMI
(Optional) 25 52
VT Gen
Metering

Waveform Capture

81R 81A 81 59 27 24 M
IRIG-B
(Metering)
50 CT (Note 3)
Front RS232 DT
Communication
Rear RS232
Communication VT (Note 1)

Rear Ethernet
Port (Optional)
(Note 2)
Rear RS-485 M-3921
Communication 59X +

Multiple Setting
Groups -

Programmable I/O 64F 64B

27

Self Diagnostics
CT
78 60FL 51V 50/27 40 32 21 50 49 46 M
Dual Power Supply
(Optional) (Metering)

Breaker
Monitoring
Trip Circuit
Monitoring 3VO (Calculated)
(Note 4)
VX
Event Log 67N
VN 67N Polarization
(Software Select)

VX 3VO (Calculated)

CT
59D Line Side CT (Neutral)
Voltage 27 50N 51N (Note 5)
(Software Select) 59D 27 64S 59N R
32
TN
R

High-impedance Grounding with Third Low-impedance Grounding with

Harmonic 100% Ground Fault Protection Overcurrent Stator Ground Fault Protection
■ NOTES:
1. When 25 function is enabled, 59, 59X, 59D with VX and 67N with VX 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.
6. The 50BFN, 50N, 51N, 59D, 67N (with IN or VN) and 87GD functions are unavailable when the 64S
function has been purchased. See the M-3425A Instruction Book for connection details.
Figure 2-6 Alternative One-Line Functional Diagram (configured for split-phase differential)
2–8
 Application – 2

1 Wire to split phase differential CTs for 4 Alarm output can be grouped to a single alarm
use with 50DT split phase function. at the discretion of user.
A B C
2 Required generator breaker status input 5 Available control output to service other relays
Other (52b). Contact is closed when generator for VT Fuse Loss can be designated.
Relays M-3425A
breaker is open. Use unit breaker 6 Input contact number is designated by user.
1
50 51 contact if no generator breaker present.
3 Output contact pairs designated by
1 user.
48 49
WARNING: ONLY dry contact inputs must be
M-3425A connected because these contact inputs are
1 internally wetted. Application of external
46 47
39 38 41 40 43 42 voltage on these inputs may result in
damage to the units.
NOTE : M-3425A current terminal polarity marks
( . ) indicate "entering" current direction when
A B C M-3425A
Three VT Wye-Wye primary current is "from" the generator to the
10
52 Alternate Connection system. If CT connections differ from those
52b
Gen 11
shown, adjust input terminals.

A A

B B

C C

42 43 40 41 38 39 42 43 40 41 38 39

Three VT Wye-Wye Two Vt Open-Delta

Connection Connection
M-3425A M-3425A

Generator
M-3921 a b c a b c
Field Ground
Coupler Module Other Other
Relays M-3425A Relays M-3425A
Other
a b c Relays M-3425A 59 58 59 58
58 59

57 56 57 56
56 57
OR OR
55 54 55 54
54 55

M-3425A M-3425A

45 44 52 53
R OR
High Impedance Grounding R Low Impedance Grounding

Example of Control/Output Connections

+

DC: 24V M-3425A +

60 62 6 3 16 12 3 3
48V
Power
Supply 61 63 11 10
- 15 13
OR
DC: 110V 2
125V 5
220V 52b 60FL TRIP SELF- POWER VT 52G
250V ALARM TEST OK FUSE
BREAKER OSCILLOGRAPH
AC: 110V FAILURE RECORDER FAILURE STATUS LOSS
ALARM ALARM 52Ga
120V INITIATE INITIATE
230V -
240V
EXTERNAL ALARM 4 CONTROL TRIP
INPUTS OUTPUTS OUTPUTS OUTPUT

Figure 2-7 Three-Line Connection Diagram

2–9
M-3425A Instruction Book

M-3425A
65 Used when Generator
VX
Side VTs are connected
Line-Ground.
64

OR VX Used for Sync Check (25)

M-3425A

65
VX Used when Generator Side VTs
64 are connected Line-Line

A B C M-3425A

10
52
52b
Gen 11

A B C

M-3425A

39
Three VT Wye-Wye
38 Connection

41

40

43

42

OR
M-3425A

42
A B C

43 Two VT Open-Delta
Connection

40

41

38

39

Generator

■ 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

2–10
 Application – 2

A B C M-3425A

52 10
52b
Gen
11

A B C

M-3425A

VX
65
R
64

V X used for turn-to-turn

fault protection (59X)

Generator

a b c
Line to Neutral
Voltage Rated
Cable

M-3425A
M-3425A
52 53
OR R
45 44

R Low Impedance Grounding

High Impedance Grounding

■ 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

2–11
M-3425A Instruction Book

Bus Section
A

M-3425A

53
R Residual CT I N input can be connected
52 either at Neutral or as Residual.

M-3425A
67N
65 64 Connection

59X A B C M-3425A
Bus Ground
52 10
52b
Gen
11

A B C

M-3425A

VX
65
R
64

67N, 59D
Connection

VX can be used for both 67N and

Generator
59D if connected in this manner.

a b c

M-3425A
I N input can be connected
52 53
either at Neutral or as Residual.

R Low Impedance Grounding

OR
M-3425A

45 44
R

High Impedance Grounding

■ 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

2–12
 Application – 2

2.3 Setpoints and Time Settings

The individual protective functions, along with their magnitude and timing settings are described in the
following pages. Settings for disabled functions do not apply. Some menu and setting screens do not appear
for functions that are disabled or not purchased. Menu screens are as they would appear on units equipped
with the M-3931 HMI Module. The same setting may be entered using M-3820D IPScom Communications
Software.

For those units equipped with Expanded I/O, setting of Expanded Inputs and Outputs is accomplished by
selecting “Expanded I/O” from the individual function screen. IPScom® will display the Expanded I/O
Initiate dialog screen (Figure 2-11).

? X

Expanded Input
Expanded Output Initiate Initiate
OUTPUT9 OUTPUT17 Input 7

OUTPUT10 OUTPUT18 Input 8

OUTPUT11 OUTPUT19 Input 9 OK

OUTPUT12 OUTPUT20 Input 10

Cancel
OUTPUT13 OUTPUT21 Input 11

OUTPUT14 OUTPUT22 Input 12

OUTPUT15 OUTPUT23 Input 13

OUTPUT16 Input 14

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

2–13
M-3425A Instruction Book

21 Phase Distance
The Phase Distance function (21) is designed for When the generator is connected to the system
system phase fault backup protection and is through a delta/wye transformer, proper voltages
implemented as a three-zone mho characteristic. and currents (equivalent to the high side of the
transformer) must be used in order for the relay to
Three separate distance elements are used to detect see correct impedances for system faults. By
AB, BC, and CA fault types. The ranges and enabling the Delta-Y Transform feature (see Section
increments are shown in Figure 2-14. The diameter, 2.1, Configuration, Relay System Setup), the relay
offset, system impedance angle (relay characteristic can internally consider the 30° phase shift (30° lead
angle), and definite time delay need to be selected delta-ab or 30° lag delta-ac) through the delta/wye
for each zone for coordination with the system transformer, saving auxiliary VTs. Impedance
relaying in the specific application. calculations for various VT connections are shown
in Table 2-2. All impedance settings are secondary
Zone 1, Zone 2 and Zone 3 may be used for backup
relay quantities and can be derived from the following
protection for unit transformer and transmission
faults. Zone 3 in conjunction with Zone 2 can be formula:
used to detect an Out of Step condition and it can Z SEC = ZPRI x (RC ÷ RV)
be programmed to block Function 21 #1 and/or 21
#2. If Zone 3 is being used for out-of-step blocking, where ZSEC = secondary reflected impedance, ZPRI
= primary impedance, RC = current transformer
it does not trip.
ratio, and RV = voltage transformer ratio.
If Zone 1 is not set to see the transmission system,
out-of-step blocking is not recommended. The minimum current sensitivity depends on the
programmed reach (diameter and offset). If the
When Zone 3 is used for Out-of-step blocking, the current is below the minimum sensitivity current,
out of step delay is used for the detection of the the impedance calculated will saturate, and not be
transit time of the swing between Zone 3 and Zone accurate. This will not cause any relay misoperation.
2 impedances.
An overcurrent supervision feature can be enabled,
The load encroachment blinder function can be set which will block the 21 function when all three
with a reach and an angle as shown in Figure 2-13. phase currents are below the pickup value.
When enabled, this feature will block the 21 Function
from misoperating during high load conditions.

Typically the first zone of protection is set to an impedance value

21 #1 DIAMETER enough in excess of the first external protective section (typically
________ Ohms the unit transformer) to assure operation for faults within that
protective zone. See Figure 2-12, Phase Distance (21) Coverage.
A negative or positive offset can be specified to offset the mho
21 #1 OFFSET circle from the origin. This offset is usually set at zero. See Figure
________ Ohms 2-13, Phase Distance (21) Function Applied For System Backup.
The impedance angle should be set as closely as possible to the
actual impedance angle of the zone being protected.
21 #1 IMPEDANCE ANGLE
________ Degrees
When enabled the 21 Function is blocked when the impedance falls
within the zone but above the R Reach and below the Load En-
21#1 LOAD ENCROACHMENT croachment angle.
disable ENABLE
■ NOTE: The 21 #2 and #3 zone settings can be set for an additional
external section of protection on the system (typically
21 #1 LOAD ENCR ANGLE transmission Zone 1 distance relays) plus adequate
________ Degrees overreach. #2 and #3 screens are identical to those in #1.
Element #3 also includes out-of-step time delay when out-
of-step blocking is enabled for Zone #1 and/or Zone #2.
21 #1 LOAD ENCR R REACH
________ Ohms

2–14
 Application – 2

When enabled, the overcurrent supervision blocks the 21 Function

21 #1 OC SUPERVISION
when all three phase currents are below the pickup.
disable enable

21 #1 OC SUPERVISION
________ Amps

21 #1 OUT OF STEP BLOCK When enabled the 21 Function is blocked on the detection of an
disable enable out-of-step condition.

The time delays are set to coordinate with the primary protection of
21 #1 DELAY those overreached zones and, when applicable, with the breaker
________ Cycles failure schemes associated with those protective zones.

21 #3 OUT OF STEP DELAY In Zone #3 when out-of-step blocking is enabled for Zone #1 or #2.
________ Cycles

Protected Range Zone 3

+X
Protected Range Zone 2

Protected Range Zone 1

–R +R

–X
3
52 52 52

Bus
M-3425A
21

Figure 2-12 Phase Distance (21) Coverage

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

2–15
M-3425A Instruction Book

+jX

ZONE 3

Transmission Line
ZONE 2

Circle
Diameters ZONE 1

Unit Transformer
R2
Block
R1
Θ
Block
δ2 δ1
–R +R

–jX

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

2–16
 Application – 2

? X

#1 #2 #3
(21) PHASE DISTANCE
Circle Diameter: 0.1 Ohm 100.0 Ohm(s)

-100.0 Ohm(s) 100.0 Ohm(s)

Offset:

Impedance Angle: 0° 90°

Load Encr. Angle: 1° 90° Enable

Load Encr. R Reach: 0.1 Ohm 100.0 Ohm(s) Disable

Delay: 1 Cycle 8160 Cycles

Enable
Overcurrent SV: 0.1 A 20 A
Disable

Out of Step Block Enable Out of Step Block Disable

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-14 Phase Distance (21) Setpoint Ranges

Transformer Direct
Connected Transformer Delta-AC Connected Transformer Delta-AB Connected

VT Connection VT Connection VT Connection

L-L or L-G to L-L L-G L-L or L-G to L-L L-G L-L or L-G to L-L L-G

VAB VA – VB VBC – VAB VB–V0 VAB – VCA Va–V0

AB Fault I a – Ib
I a – Ib (3)I b Ib (3)I a Ia

VBC VB – VC VCA–VBC VC–V0 VBC –VAB Vb–V0

BC Fault (3)Ib
Ib–Ic Ib–Ic (3)Ic Ic Ib

VCA VC – VA VAB–VCA VA–V0 VCA –VBC Vc–V0

CA Fault I c –Ia (3)Ia Ia (3)Ic Ic
Ic –Ia

Table 2-2 Impedance Calculation

2–17
M-3425A Instruction Book

24 Overexcitation Volts/Hz
The Volts-Per-Hertz function (24) provides Setting this relay function involves determining the
overexcitation protection for the generator and unit- desired protection levels and operating times. The
connected transformers. This function incorporates first step is to plot the combined generator and
two definite time elements which can be used to associated unit transformer overexcitation capability
realize traditional two-step overexcitation protection. limits. This data is typically available from the
In addition, the relay includes an inverse time manufacturer and should be plotted on the same
element that provides superior protection by closely voltage base. Depending on the resulting
approximating the combined generator/unit characteristic, one of the four families of inverse
transformer overexcitation curve. Industry standard time curves (as shown in Appendix D, Inverse
inverse time curves may be selected along with a Time Curves) can be matched to provide the
linear reset rate which may be programmed to protection. The two definite time elements can be
match specific machine cooling characteristics. used to further shape the protection curve or provide
The percent pickup is based on the Nominal Voltage an alarm.
setting and the nominal frequency. The V/Hz function
provides reliable measurements of V/Hz up to 200% Figure 2-15 illustrates a composite graph of generator
for a frequency range of 2–80 Hz. The ranges and and transformer limits, a chosen inverse time curve
increments are presented in Figure 2-16. and pickup, and a definite time pickup and delay.

24DT #1 PICKUP Definite time setpoint #1 establishes the V/Hz level above which the
________ % protection operating time will be fixed at the definite time delay #1.

24DT #1 DELAY Delay time #1 establishes the operation time of the protection for all
________ Cycles V/Hz values above the level set by definite time setpoint #1.

24DT #2 PICKUP Definite time setpoint #2 could be programmed to alarm, alerting the
________ % operator to take proper control action to possibly avoid tripping.

24DT #2 DELAY Time to operation at any V/Hz value exceeding Definite time setting
________ Cycles #2.

24IT PICKUP The pickup value is the V/Hz value at which the chosen inverse
curve begins protective operation. Typical value is 105%.
________ %

24IT CURVE Allows the user to designate the appropriate curve family for this
crv#1 crv#2 crv#3 crv#4 protection application. These curves are shown in Appendix D, Inverse
Time Curves.

24IT TIME DIAL The appropriate curve in the family is designated by the associated
________ “K” value of the curve.

24IT RESET RATE The value entered here should be the time needed for the unit to
________ Seconds cool to normal operating temperature if the V/Hz excursion time
was just under the trip time.

2–18
 Application – 2

M-3425A Firmware Versions D-0114VXX.XX.XX After any V/Hz excursion, cooling time must also
and Earlier be taken into account. If the unit should again be
■ NOTE: When the inverse time element is subjected to high V/Hz before it has cooled to
enabled, the definite time element #1 normal operating levels, damage could be caused
must be enabled which will provide before the V/Hz trip point is reached. For this
definite minimum time setting for the reason, a linear reset characteristic, adjustable to
inverse time curve. take into account the cooling rate of the unit, is
provided. If a subsequent V/Hz excursion occurs
The following steps must be followed when setting before the reset characteristic has timed out, the
the inverse time element and definite time element time delay will pick up from the equivalent point (as
#1: a %) on the curve. The Reset Rate setting entered
1. The pickup of the inverse time element should be time needed for the unit to cool to normal
must be less than the pickup of the operating temperature if the V/Hz excursion time
definite time element #1 was just under the trip point.

2. The operating time of the inverse time

element at the definite time element #1 M-3425A Firmware Version D-0150V 01.00.34
pickup should be greater than the definite The inverse time element has a definite minimum
time element #1 time delay setting time of 30 cycles. Definite Time Element #1 is
(A2>A1 in Figure 2-15). independent, and has no effect on inverse time
elements.
3. When the inverse time element is
enabled, definite time element #1 should M-3425A Firmware Version D-0150V 01.04.00
not be used for alarm. Only definite time
The inverse time element has a definite minimum
element #2 can be used for alarm.
time of 60 cycles. Definite Time Element #1 is
independent, and has no effect on inverse time
elements.

1000

Generator Limit Curve

100
Transformer Limit Curve
on Generator Base

Inverse Square Curve

10 K=5
Time in Minutes

Inverse Time Delay at Definite Combined Protection

Time Pickup #1 (A2) Curve

A2
0.1 Definite Time Delay (A1)

Definite Time Pickup

A1
Inverse Time Pickup

0.01

100 105 110 115 120 125 130 135 140 145 150

Percentage Volts/Hz

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

2–19
M-3425A Instruction Book

? X

F24

(24) - VOLTS/HZ

Pickup: 100% 200% Def. Time #1

Delay: 30 Cycles 8160 Cycles
OUTPUTS @ Blocking Inputs
Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 100% 200% Def. Time #2

Delay: 30 Cycles 8160 Cycles
OUTPUTS @ Blocking Inputs
Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 100% 200% Inv. Time

Curves: #1 #2 #3 #4
Time Dial: 1 100
Reset Rate: 1 Sec 999 Secs

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

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

2–20
 Application – 2

25 Sync Check
■ NOTE: The 25 function cannot be enabled under Dead Line/Dead Bus Check
any one of the following conditions:
The Dead Volt Limit defines the Hot/Dead voltage
• 67N (Residual Directional Overcurrent) level used in Deadline/Dead Bus closing schemes.
is enabled and the polarizing quantity When the measured VX voltage is equal to or below
has been set to VX. the Dead Volt Limit, VX is considered dead. When
• 59D is enabled and the line side voltage the measured VX is above the Dead Volt Limit, VX
is set to VX. is considered hot. The opposite side of the breaker
uses the positive sequence voltage measurement
• 59X is connected for turn-to-turn fault
(V1) for 3-phase consideration in determining hot/
protection or bus ground protection.
dead detection. Different combinations of hot line/
The Synchronism (Sync) Check function (25) is dead bus closings may be selected, depending on
used to ensure that the voltage magnitude, phase how the buses are referenced. A logic diagram of
angle and frequency of the generator (V1) and the the Deadline/Dead Bus scheme is presented in
utility system (VX) are within acceptable limits before Figure 2-17.
the generator is synchronized with the system.
The Dead V1, Dead VX, and Dead V1 & VX enable
Generator voltage (V1) can be selected as A, B, or
are software switches used to enable the dead
C (line-to-ground and line-ground to line-line) or AB,
line/dead bus logic. Further conditioning can be
BC, or CA (line-to-line).
performed on the dead detection logic by selecting
The sync check function includes phase angle, one or more input contacts (Dead Input Enable) to
delta frequency, and delta voltage checks. control the enabled dead detection element. For
example, if INPUT2 (I2) is selected under the
Dead Input Enable screen, and both the Dead V1
Phase Angle Check and Dead VX elements are enabled, the dead check
The phase angle is considered acceptable when timer will start when INPUT2 is activated, and
the selected sync phase voltage (V1) and system either V1 dead/VX hot or V1 hot/VX dead. This
voltage (VX) are within the Upper Volt Limit and allows for external control of the desired dead
Lower Volt Limit window and the measured phase closing scheme. Dead Input Enable selections are
angle is within the phase angle window. common to all dead detection elements. If no
inputs are selected under the Dead Input Enable
Phase angle window is defined as twice the Phase
screen, and any dead element is enabled, the
Angle Limit setting. For example, if the Phase
dead check timer will start immediately when the
Angle Limit is set at 10 degrees, a phase angle
dead condition exists.
window of 20 degrees exists between –10 degrees
and +10 degrees. The logic diagram of the phase The 25S and 25D can be programmed to be sent to
angle check is shown in Figure 2-17. two different contacts, if desired.
■ NOTE: The 25 function does not produce a
Delta Voltage and Delta Frequency Check
target or LED and is accompanied by
Delta Voltage and Delta Frequency elements may the HMI message “F25 Function
be individually enabled or disabled, as desired. The Operated”.
Delta Voltage check will compare the absolute
difference between the selected sync phase voltage
(V1) and the measured system voltage (VX) with
the Delta Voltage Limit setting. Likewise, the Delta
Frequency measures the frequency difference
between V1 and VX voltage signals. The Phase
Angle Check, Delta Voltage and Delta Frequency
Check all combine through an appropriate timer
with the output directed to the programmed 25S
output contact. A logic diagram representing this
logic is presented in Figure 2-17.

2–21
M-3425A Instruction Book

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

Phase angle setting.
25S PHASE LIMIT
________ Degrees

Upper voltage limit for voltage acceptance.

25S UPPER VOLT LIMIT
________ Volts

25S LOWER VOLT LIMIT Lower voltage limit for voltage acceptance.
________ Volts

25S SYNC CHECK DELAY Sync check time delay.

________ Cycles

25S DELTA VOLT Delta voltage element.

disable ENABLE

25S DELTA VOLT LIMIT Delta voltage setting.

________ Volts

25S DELTA FREQUENCY Delta frequency element.

disable ENABLE

25S DELTA FREQ LIMIT Delta frequency setting.

________ Hz

25S SYNC-CHECK PHASE Selects the phase voltage on the generator side for Sync Check func-
a b c tions (A, B, or C for line-to-ground and line-ground to line-line, and AB,
BC, CA for line-to-line)

25D DEAD VOLT LIMIT Voltage less than this setting is defined as “DEAD”; above this setting
________ Volts as “HOT”.

25D DEAD V1 HOT VX Enables Dead V1/Hot VX setting.

disable ENABLE

25D DEAD VX HOT V1 Enables Hot V1/Dead VX setting.

disable ENABLE

25D DEAD V1 & VX Enables Dead V1/Dead VX closing.

DISABLE enable

25D DEAD INPUT ENABLE Externally controlled dead closing. Inputs IN7–IN14 must be set using
i6 i5 i4 I3 i2 i1 IPScom.

25D DEAD DELAY Dead delay timer setting.

________ Cycles

2–22
 Application – 2

Delta V and Delta F Check Logic

With Delta V AND Delta F Enabled
|V1 - V X | < Delta V Limit Only one Delta V and
AND Delta F Check Scheme
Delta V Is Enabled may be active at a time.
Phase Angle Check Logic
|F 1 - F X | < Delta F Limit
V1 > Lower Voltage Limit
AND AND
AND
AND
Delta F Is Enabled
V1 < Upper Voltage Limit

VX > Lower Voltage Limit Sync Check Timer

AND AND Phase Angle OK Output Seal-in Timer
VX < Upper Voltage Limit
25S
Output
Delta V and Delta F Check Logic Contact
Phase Angle < Phase Limit With Delta V OR Delta F Enabled
|V 1 - VX | < Delta V Limit
AND AND
OR
Delta V Is Enabled

Only one Delta V and

|F 1 - F X | < Delta F Limit
Delta F Check Scheme
AND
Delta F Is Enabled
may be active at a time.

Dead Line/ Dead Bus Check Logic

V1 pos < Dead Limit

VX > Dead Limit AND

Dead V1 Hot V X
Enabled

V1 pos > Dead Limit

VX < Dead Limit AND OR

Dead V X Hot V1 Enabled

V1 pos < Dead Limit

Dead Check Timer
VX < Dead Limit AND
Output Seal-in Timer
Dead V1 V X Enabled
OR
25D
Output
Dead Line/ Dead Bus Check Input Initiate Logic Contact
V1 pos < Dead Limit
VX > Dead Limit AND
Dead V1 Hot V X
Enabled
AND
OR
Dead Input Enable V1 pos > Dead Limit
Selected INPUT Is Activated
VX < Dead Limit AND

AND
Dead V X Hot V1 Enabled

User Software Setting

Measured Variable

Figure 2-17 Sync Check Logic Diagrams

2–23
M-3425A Instruction Book

? X

F25
(25) - SYNC CHECK
Phase Angle Window: 0o 90o 25S
Upper Voltage Limit: 60 V 140 V

Lower Voltage Limit: 40 V 120 V

Sync Check Delay: 1 Cycle 8160 Cycles

Delta Voltage: 1.0 V 50.0 V

Enable Disable

Delta Frequency: 0.001 Hz 0.500 Hz

Enable Disable

25S Sync Check Phase

Phase AB Phase BC Phase CA

OUTPUTS @ Blocking Inputs

Expanded I/Os
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Dead Voltage Limit: 0V 60 V 25D

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

Dead Time Delay: 1 Cycle 8160 Cycles

Dead Input Enable

Expanded I/P Initiate
6 5 4 3 2 1

OUTPUTS Blocking Inputs

Expanded I/Os
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, you have not selected an output!

Save Cancel

Figure 2-18 Sync Check (25) Setpoint Ranges

2–24
 Application – 2

27 Phase Undervoltage
The Phase Undervoltage function (27) may be used Magnitude measurement depends on the 59/27
to detect any condition causing long- or short-term Magnitude Select setting. (See Section 2.1,
undervoltage. This is a true three-phase function in Configuration, Relay System Setup.) When the RMS
that each phase has an independent timing element. calculation is selected, the magnitude calculation is
The ranges and increments are presented in Figure accurate over a wide frequency range (10 to 80 Hz)
2-19. and the accuracy of the time delay is +20 cycles. If
DFT calculation is selected, the magnitude
calculation is accurate near 50 or 60 Hz, and the
timer accuracy is &1 cycle.

27 #1 PICKUP 27 #2 and 27 #3 Screens are identical to 27 #1.

________ Volts

27 #1 DELAY
________ Cycles

? X

F27

(27) - PHASE UNDERVOLTAGE

Pickup: 5V 180 V #1
Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/Os
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 5V 180 V #2
Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/Os
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 5V 180 V #3
Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/Os
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING,You have not selected an output!

Save Cancel

Figure 2-19 Phase Undervoltage (27) Setpoint Ranges

2–25
M-3425A Instruction Book

27TN Third Harmonic Undervoltage, Neutral

For ground faults near the stator neutral, the Third before the unit synchronized, small current
Harmonic (180/150 Hz) Neutral undervoltage measurement errors cause the measured power
function (27TN) provides stator ground-fault to fluctuate (typically <0.2%.) This may result in
protection for high-impedance-grounded generator a measured power value that is negative (i.e.,
applications (See Figure 2-20). When used in –0.001 pu.) If the reverse power blocking is not
conjunction with the fundamental neutral enabled, the 27TN may be momentarily unblocked,
overvoltage (60/50Hz) function (59N), 100% stator resulting in a relay operation and nuisance generator
ground-fault protection can be provided. This is trip. It is highly recommended that if the Forward
illustrated in Figure 2-20. Power Blocking is used, both the Forward Power
Blocking and Reverse Power Blocking be enabled
The 27TN function can be supervised by the and set.
positive-sequence undervoltage element.
Undervoltage supervision can prevent tripping when In the majority of the cases, these blocking
the generator field is not energized or the unit is functions will be disabled, except for those operating
not yet synchronized. cases where the third harmonic neutral voltage
magnitude is less than 0.5 V. The settings for
In some generators, the third harmonic voltage the blocking functions should be set based on
can be very low, especially during light load field measurements. Blocking regions are
conditions. It is also observed in some generator illustrated in Figure 2-21.
installations that the third harmonic voltage is
considerably reduced for a specific range of power The 27TN setting depends on the actual third-
output (band). To prevent mis-operation during harmonic neutral voltage level seen during normal
these conditions, the 27TN function can be operation of the generator. The setting should
programmed to be supervised (blocked) by low be about 50% of the minimum third-harmonic
forward power, low reverse power, low Vars (lead voltage observed during various loading conditions.
and lag), low power factor (lead/lag), and when This can be most conveniently measured during
the forward power is inside a band. commissioning of the relay. Since the relay
measures the third harmonic voltage levels and
To properly handle pump storage operations, the will display those values directly, no additional
M-3425A forward power blocking algorithm is enable equipment is required. The undervoltage inhibit
from “zero per unit” to the forward power setpoint. setting should be about 80% to 90% of the nominal
During plant startup, after the field is flashed and voltage. The ranges and increments are presented
in Figure 2-22.
27TN #2 Screens are identical to 27TN #1.

27TN #1 PICKUP Relay volts are equal to the primary neutral voltage divided by the
________ Volts grounding transformer ratio. Generally set for approximately 50%
of the minimum third harmonic voltage observed during various loading
conditions.
27TN #1 POS SEQ VOLT BLK
disable ENABLE 27TH #1 REV POWER BLK
disable ENABLE

27TN #1 POS SEQ VOLT BLK

________ Volts 27TN #1 REV POWER BLK
________ PU

27TN #1 FWD POWER BLK

disable ENABLE 27TN #1 LEAD VAR BLK
disable ENABLE

27TN #1 FWD POWER BLK

________ PU 27TN #1 LEAD VAR BLK
________ PU

2–26
 Application – 2

27TN #1 LAG VAR BLK 27TN #1 BAND FWD PWR BLK

disable ENABLE disable enable

27TN #1 LAG VAR BLK

27TN#1 LO B FWD PWR BLK
________ PU
________ PU

27TN #1 LEAD PF BLK 27TN#1 HI B FWD PWR BLK

disable enable ________ PU

27TN #1 LEAD PF BLK

27TN #1 DELAY
________ LEAD
________ Cycles

27TN #1 LAG PF BLK

disable enable

27TN #1 LAG PF BLK

________ LAG

Fundamental (60/50 Hz) neutral

voltage during ground fault
Neutral Voltage

Third Harmonic (180/150 Hz) neutral

voltage during ground fault

Pre-fault third harmonic voltage level

27TN Setpoint
Pre-fault fundamental neutral voltage level
59N Setpoint (typically 5V)
Neutral End of Terminal End
Generator of Generator
0% 50% 100%
Fault Position
(% of stator winding measured
27TN from neutral end of generator)
Protection
provided by: 59N

5% - 10%

0-30%
Figure 2-20 Third Harmonic Undervoltage (27TN) Protection Characteristics

2–27
M-3425A Instruction Book

+Q Low Band Forward

Lag var Block Power Block

-P +P
Reverse Block Forward Block High Band
Power Power Forward
Block Block Power Block

Lead var Block

-Q
Figure 2-21 27TN Blocking Regions

2–28
 Application – 2

#1 #2
(27TN) - THIRD HARMONIC UNDERVOLTAGE, NEUTRAL

Pickup: 0.1 V 14.00 V #1

Pos. Seq. Voltage Block: 5V 180 V Enable Disable

Forward Power Block: 0.01 PU 1.00 PU Enable Disable

Reverse Power Block: -1.00 PU -0.01 PU Enable Disable

Lead var Block: -1.00 PU -0.01 PU Enable Disable

Lag var Block: 0.01 PU 1.00 PU Enable Disable

Lead Power Factor Block: 0.01 Lead 1.00 Lead Enable Disable

Lag Power Factor Block: 0.01 Lag 1.00 Lag

Enable Disable

Hi Band Forward Power Block: 0.01 PU 1.00 PU

Enable Disable
Lo Band Forward Power Block: 0.01 PU 1.00 PU

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

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

2–29
M-3425A Instruction Book

32 Directional Power
The Directional Power function (32) can provide valves are closed. In this case the Over/Under
protection against both generator motoring and power setting is set to Under and a positive pickup
overload. It provides three power setpoints, each setting is chosen. The relay will trip when the
with a magnitude setting and a time delay. The measured forward power is less than the pickup
Forward Power direction (power flow to system) is value. The function should be blocked when the
automatically chosen when the pickup setting is generator breaker is open (using contact input
positive and the Reverse Power direction (power blocking) otherwise the function will trip and prevent
flow to generator) is automatically chosen when the the generator from being brought online.
pickup setting is negative. The range, as shown is
from –3.000 PU to 3.000 PU where 1.0 PU is equal Protection from Generator Overload
to the generator MVA rating. Normalized PU power
flow measurements are based on Nominal Voltage Protection from generator overload is provided by
and Nominal Current setting, as shown in Section selecting a positive pickup setting with Over/Under
2.1, Configuration, Relay System Setup. Power setting set to Over. The relay will operate
when the measured real power is greater than the
pickup setting.
Protection from Generator Motoring
Protection against motoring is provided by selecting Protection from Excessive Reactive Power
a negative pickup with Over/Under power set to
Over. The relay will operate when the measured The directional power element #3 can be set to
real power is greater (more negative) than the pickup operate on either real power or reactive power.
setting in the reverse direction. When protection from excessive reactive power is
required the element #3 can be set to operate on
In some steam generator applications it is desirable reactive power. The relay will operate when the
to trip the generator when the forward power is less measured reactive power exceeds the pickup
than a small value. This is due to the fact that the setting.
trapped steam will cause the generator to supply a
small amount of power even though the steam Figures 2-23 through 2-26 show reverse power, low
forward power, over power, and over reactive power
applications.

32 #1 PICKUP The reverse power pickup setting should be based on the type of
________ PU prime mover and the losses when the generator is motoring.

32 #1 DELAY Reverse power relays should always be applied with a time delay in
________ Cycles order to prevent mis-operation during power swing conditions. Typical
time delay settings are 20 to 30 seconds.

32 #1 TARGET LED Target LED for the 32 Function elements can be individually enabled
disable enable or disabled.

32#1 UNDER/OVER POWER When Low Forward Power protection is desired, set this to Under
over under with a positive pickup setting. The relay will trip when the real power
measurement is less than or equal to the pickup setpoint.

If used, positive direction power settings can be used for overload

32 #2 PICKUP protection, providing either alarm or tripping or both, when power
________ PU equals or exceeds the setting. The pickup and time delay settings
should be based on the capability limit of the generator.

A second reverse power setting can be used for sequential tripping

32 #2 DELAY
of the generator in which case the associated time delay will be in
________ Cycles the range of 2 to 3 seconds.

2–30
 Application – 2

32 #2 TARGET LED
disable enable

32#2 UNDER/OVER POWER

over under

32 #3 PICKUP
________ PU

32 #3 DELAY
________ Cycles

32 #3 TARGET LED
disable enable

32#3 UNDER/OVER POWER

over under

Directional Power Sensing for Element #3 can be se-

32 #3 DIR POWER SENSING lected as Real or Reactive.
real reactive

Reverse
Power Flow Forward
Power Flow
PU
-1.0 PU 1.0 PU

TRIP
Pickup

Figure 2-23 Tripping on Reverse Power Flow (Over Power with Negative Pickup)

2–31
M-3425A Instruction Book

Reverse Forward
Power Flow Power Flow

PU
-1.0 PU 1.0 PU

TRIP
Pickup

Figure 2-24 Tripping on Low Forward Power (Under Power with Positive Pickup)

Reverse Forward
Power Flow Power Flow

PU
-1.0 PU 1.0 PU

TRIP
Pickup

Figure 2-25 Tripping on Overpower (Over Power with Positive Pickup)

2–32
 Application – 2

Reactive Power
Into System

TRIP
Pickup
Reverse Forward
Power Flow Power Flow

PU
-1.0 PU 1.0 PU

Reactive Power
Into Generator
Figure 2-26 Tripping on Over Reactive Power with Element #3 (Over Power, Positive Pickup and
Directional Power Sensing Set to Reactive)

2–33
M-3425A Instruction Book

? X
F32

(32) - DIRECTIONAL POWER

Pickup: -3.000 PU 3.000 PU #1

Delay: 1 Cycle 8160 Cycles

Overpower Underpower Target LED Enable

OUTPUTS @ Blocking Inputs

Expanded I/Os
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: -3.000 PU 3.000 PU #2

Delay: 1 Cycle 8160 Cycles

Overpower Underpower Target LED Enable

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/Os

Pickup: -3.000 PU 3.000 PU #3

Delay: 1 Cycle 8160 Cycles

Overpower Underpower Target LED Enable

Directional Power Sensing: Real Reactive

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1
Expanded I/Os

@ : WARNING, You have not selected an output!

Save Cancel

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

2–34
 Application – 2

40 Loss of Field
The Loss-of-Field function (40) provides protection not required). The directional unit’s angle setting
for a partial or complete loss of field. A variety of (ΘD) can be set from 0° to 20°.
possible settings make the M-3425A Generator
Protection Relay very flexible when applied to loss- The settings of the offset mho elements should be
of-field protection. Ranges and increments are such that the relay detects the loss-of-field condition
presented in Figure 2-30. for any loading while not mis-operating during power
swings and fault conditions. Two approaches are
The loss-of-field function is implemented with two widely used in the industry, both of which are
offset mho elements, an undervoltage element, supported by the M-3425A relay. Both approaches
and a directional element. The setting for each mho require knowledge of the reactances and other
element, diameter, offset, and time delay, are parameters of the generator. They are described in
adjusted individually. Each element has two time Figure 2-28, Loss of Field (40) — Protective
delay settings. The second time delay (delay with Approach I and Figure 2-29, Loss of Field (40) —
VC) is applicable with voltage control, and the timer Protective Approach II.
only starts if the positive sequence voltage is
below the voltage control setting. The function with Positive sequence impedance measurements are
voltage control and without voltage control can be used for the loss of field functions. All impedance
programmed to send to two different output contacts, settings are secondary relay quantities and can be
if desired. The delay with voltage control may be derived from the following formula:
enabled on each element but the voltage level Z SEC = ZPRI x (RC ÷ RV)
setting is common. The voltage control allows for
faster tripping when low voltage may be caused by where ZSEC = secondary reflected impedance, ZPRI
the VAr intake by the machine with loss of = primary impedance, RC = current transformer
excitation. A common directional unit is provided to ratio, and RV = voltage transformer ratio.
block the relay operation during slightly underexcited
conditions (since approach #1 with negative offset
is inherently directional, the directional element is

The first approach is shown in Figure 2-28,

40 #1 DIAMETER
Loss of Field (40) — Protective Approach I.
________ Ohms
Here, both of the offset mho elements (#1 and
l l
#2) are set with an offset of –X d÷2, where X d
40 #1 OFFSET is the (unsaturated) direct axis transient reac-
________ Ohms tance of the generator. The diameter of the smaller
circle (#1) is set at 1.0 pu impedance on the
machine base. This mho element detects loss-
40 #1 DELAY of-field from full load to about 30% load. A small
________ Cycles time delay provides fast protection.

The diameter of the larger circle (#2) is set equal

40VC #1 DELAY WITH VC to Xd, where Xd is the (unsaturated) direct axis
________ Cycles synchronous reactance of the machine. This mho
element can detect a loss-of-field condition from
almost no load to full load. A time delay of 30 to
60 cycles (#2) should be used in order to prevent
possible incorrect operation on stable swings.

The time delay with voltage control is typically

set shorter than the other time delay.

2–35
M-3425A Instruction Book

40 #2 DIAMETER The second approach is shown in Figure 2-29,

________ Ohms Loss of Field (40) – Protective Approach II. In
this approach, one of the mho elements is set
l l
with an offset of –X d ÷ 2, a diameter of 1.1 Xd-(X d
÷ 2), and a time delay of 10 to 30 cycles. The
second element is set to coordinate with the
generator minimum excitation limit and steady-
40 #2 OFFSET state stability limit.
________ Ohms
In order to obtain proper coordination, the offset
of this element must be adjusted to be positive.
Typically, the offset is set equal to the unit
transformer reactance (X T). The diameter is
40 #2 DELAY approximately equal to (1.1 Xd + XT). A time
________ Cycles delay of 30 to 60 cycles would prevent mis-
operation on stable swings.

40VC #2 DELAY WITH VC

________ Cycles

The following table provides suggested time settings

40 VOLTAGE CONTROL when time delay with VC is used in addition to
________ Volts standard time delay.

Typical setting is 13° (0.974 power factor). This

40 DIRECTIONAL ELEMENT setting is common to both element #1 and #2.
________ Degrees
Approach #1 can also be used for Zone #1, and
approach #2 for Zone #2, where better coordination
with AVR limiters, machine capability limits, and
steady state stability limits can be obtained.

Zone 1 Zone 2

80 to 90% of
Voltage Control Setting N/A
Nominal Voltage

Delay 15 Cycles 3,600 Cycles

Delay with VC Disable 60 Cycles

Table 2-3 Voltage Control Time Settings

2–36
 Application – 2

+X

Heavy Load Light Load

–X'd
2 QD
–R +R

1.0 pu Underexcited

Xd

Loss of Excitation
Final Impedance
Locus

Steady-State Stability Limit

Machine Capability

Minimum Exciter Limit

–X
Figure 2-28 Loss of Field (40)—Protective Approach 1

Directional Element +X

Block Direction
Heavy Load Light Load
Trip Direction
QD XT
–R +R
Directional –X'd
Element Angle 2
Setting
Underexcited

1.1 Xd

Loss of Excitation
Final Impedance
Locus

Steady-State Stability Limit

Machine Capability

Minimum Exciter Limit

–X
Figure 2-29 Loss of Field (40)—Protective Approach 2

2–37
M-3425A Instruction Book

F40
(40) - LOSS OF FIELD

Circle Diameter: 0.1 Ohm 100.0 Ohms #1

Offset: - 50.0 Ohms 50.0 Ohms

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Delay with VC: 1 Cycle 8160 Cycles VC#1

VC OUTPUTS @ VC Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Circle Diameter: 0.1 Ohm 100.0 Ohms #2

Offset: - 50.0 Ohms 50.0 Ohms

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Delay with VC: 1 Cycle 8160 Cycles VC#2

VC OUTPUTS @ VC Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

Voltage Control: 5V 180 V

Directional Element: 0° 20°

@ : WARNING, You have not selected an output!

Save Cancel

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.

2–38
 Application – 2

46 Negative Sequence Overcurrent

The Negative Sequence Overcurrent function (46) value, the trip timer takes four minutes to reset
provides protection against possible rotor from its 100% trip level. Figure 2-31, Negative
overheating and damage due to unbalanced faults Sequence Overcurrent Inverse Time Curves,
or other system conditions which can cause illustrates the inverse time characteristic of the
unbalanced three phase currents in the generator. negative sequence overcurrent function.
Ranges and increments are presented in Figure
Operating times are lower than shown in Figure
2-32.
2-31 when measured current values are greater
This function has a definite time element and an than 15 A (3 A for 1 A rated circuit).
inverse time element. The definite time pickup
The first task of setting this function is to determine
value and definite operating time are normally
the capabilities of the associated machine. As
associated with an alarm function. The inverse
established by ANSI standards, the machine limits
time element is usually associated with a trip
are expressed as (I2)2t = K. The value of K is
function and has a pickup and an operating time
established by the machine design and is generally
defined by an (I2)2 t = K, where K is the Time Dial
provided on test sheets of the machine. The relay
Setting and I2 is the per unit negative sequence
can accommodate any generator size because of
current.
the wide range of K settings from 1 to 95. Typical
The minimum delay for the inverse time function is values can be found in ANSI C50.13-1977.
factory set at 12 cycles to avoid nuisance tripping.
The negative sequence pickup range is from 3% to
A maximum time to trip can be set to reduce the
100% of the Nominal Current value input during
operating times for modest imbalances. An important
system setup (see Section 2.1, Configuration).
feature that helps protect the generator from damage
due to recurring imbalances is a linear reset This protection must not operate for system faults
characteristic. When I2 decreases below the pickup that will be cleared by system relaying. This requires
consideration of line protection, bus differential and
breaker failure backup protections.

46DT PICKUP The pickup setting is usually quite low (3–5%)

________ % and the output of this function is usually con-
nected to alarm only.

46DT DELAY Time delay should be set high enough to avoid

________ Cycles alarms on transients.

The 46 Inverse Time pickup setting should coincide

46IT PICKUP
with the continuous negative sequence current
________ %
capability of the generator operating at full output.

46IT MAX DELAY The maximum trip time is used to reduce the
________ Cycles longer trip times associated with low to moder-
ate imbalances to a preset time.

46IT RESET TIME

________ Seconds

The time dial setting corresponds to the K provided

46IT TIME DIAL by the generator manufacturer for the specific unit
________ being protected. See Figure 2-31 for the negative
sequence overcurrent inverse time curves.

2–39
M-3425A Instruction Book

Pickup Setting Range

1000
800
To 65,500 cycles
600

400

200

Definite Maximum
100
Time Setting Range
80
60

40
Time (Seconds)

20

10
8
6 I22t=K
4

K
95
1 50
25
0.6
10
0.4 5
2
Definite 1
* 0.2 Minimum
Time
0.1
4 5 6 8 10 20 40 60 80 100 150 200 300 400 500 600 800 1000 1000 2000 3000 4000

Negative Sequence Current (% of Nominal Value)

■ NOTE: When the phase current exceeds 3X I nominal, the operating times will be greater than those
shown.
* 0.24 seconds for 50 Hz units.
Figure 2-31 Negative Sequence Overcurrent Inverse Time Curves

? X
F46

(46) - NEGATIVE SEQUENCE OVERCURRENT

Pickup: 3% 100% Def. Time

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs
Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 3% 100% Inv. Time

Time Dial: 1 95
Maximum Time: 600 Cycles 65500 Cycles
Reset Time: 1 Second 600 Seconds

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-32 Negative Sequence Overcurrent (46) Setpoint Ranges

2–40
 Application – 2

49 Stator Overload Protection

The Stator Thermal Overload function (49) provides loaded with 80% of its rating power prior to overload,
protection against possible damage during overload then the current goes up to 2.0 times the maximum
conditions. The characteristic curves are based on current ((IL/Imax)=2.0). Selecting the curve P=0.8
IEC-255-8 standard, and represent both cold and (see Figure 2-28), we have t/τ =0.1133. If τ =30
hot curves. The function uses the thermal time minutes, then the time delay for this condition
constant of the generator and stator maximum would be: t = 0.1133 x 30 = 3.3999 minutes.
allowable continuous overload current (Imax) in
implementing the inverse time characteristic. The 49 function has two elements, one of which
can be used for trip and the other for alarm.

Where: t = time to trip

τ = thermal time constant
IL = load current
IPL = pre-load current
Imax = maximum allowed continuous overload current
Example: If we consider that the generator was

Current-Square

IL2
I2PL

Imax2

IL2
IL2
I2PL

t
t
Tripped Not Tripped
Figure 2-33 Time Constant, Function 49

49 #1 TIME CONSTANT Selects the time constant, ‘τ ’

________ Min

49#1 MAX OVERLOAD CURR Selects the maximum allowed continuous overload
________ Amps current.

49#2 Screens are identical to those for 49#1.

2–41
M-3425A Instruction Book

49 - Overload Curves

10

0.1
t/t

P=0.0
P=0.5
P=0.6 0.01
P=0.7
P=0.8

P=0.9

P=0.99
0.001
1 2 3 4 5 6 7 8 9
IL/Imax
IPL
where: P=
Imax
Figure 2-34 49 Function Overload Curves

2–42
 Application – 2

? X
F49

(49) - STATOR OVERLOAD

Time Constant: #1
1.0 min 999.9 min

1.00 A 10.00 A
Max. Overload Current:

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Time Constant: #2
1.0 min 999.9 min

1.00 A 10.00 A
Max. Overload Current:

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-35 Stator Thermal Protection (49) Setpoint Ranges

2–43
M-3425A Instruction Book

50/50N Instantaneous Overcurrent, Phase and

Neutral Circuits
The Instantaneous Phase (50) and Instantaneous automatically selects fundamental RMS or total
Neutral (50N) overcurrent functions provide fast RMS calculation based on the input frequency.
tripping for high fault currents. The settings of both When the generator frequency is within &5 Hz
functions must be set such that they will not pickup from the nominal frequency, it uses fundamental
for fault or conditions outside the immediate RMS calculation. Outside of this range, it uses
protective zone. If the neutral current input is total RMS calculation, which will provide protection
connected to a step-up transformer’s neutral CT, during offline down to a frequency of 8 Hz.
the 50N function can be used as a breaker flashover
protection when used in conjunction with external For providing off-line protection, one of the elements
breaker failure protection. Ranges and Increments can be supervised by a breaker ‘b’ contact, and the
are presented in Figures 2-36 and 2-37. The function element blocked when the breaker is closed. This
allows the function to be set sensitively (below full
load current).

The relay current (IR) is equal to the primary current (Ip) divided by
50#1 PICKUP
the appropriate CT ratio. These screens are repeated for 50#2 ele-
________ Amps
ment.

50#1 DELAY
________ Cycles

50N PICKUP
________ Amps

50N DELAY
________ Cycles

? X

F50

(50) - INSTANTANEOUS OVERCURRENT

Pickup: 0.1 A 240.0 A #1

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 0.1 A 240.0 A #2

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-36 Instantaneous Overcurrent (50) Setpoint Ranges

2–44
 Application – 2

? X

F50N

(50N) - INSTANTANEOUS NEUTRAL OVERCURRENT

Pickup: 0.1 A 240.0 A #1

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-37 Instantaneous Neutral Overcurrent (50N) Setpoint Ranges

2–45
M-3425A Instruction Book

50BF Generator Breaker Failure/HV Breaker

Flashover
The Generator Breaker Failure/HV Breaker Flashover Implementation of the generator breaker failure
function (50BF) is applicable when a generator function is illustrated in Figure 2-38. The breaker
breaker is present and line side generator CTs are failure timer will be started whenever any one of the
being used. The 50BF-Ph phase detector element designated output contacts or the external
(if enabled) is used for breaker failure and the programmed breaker failure initiate status input are
50BF-N (if enabled) provides breaker flashover operated. The timer continues to time if any one of
protection by providing an additional breaker failure the phase currents are above the 50BF-Ph pickup
initiate which is only active when the breaker is setting or if the 52b contact indicates the breaker is
open. For high impedance grounded applications, still closed; otherwise, the timer is reset.
the 50BF-N function is inapplicable and must be
disabled. Ranges and increments are presented in Since current in the generator high side CT which
Figure 2-39. energizes the 50BF protection (IA, IB, IC) might not
extinguish concurrently with the breaker opening for
50BF-Ph Generator Breaker Failure: When the faults between the CT location and the generator
M-3425A Generator Protection Relay detects an breaker, a possible area of mis-operation exists.
internal fault or an abnormal operating condition, it Usually the risk of faults in this limited area is small
closes an output contact to trip the generator breaker enough to be ignored but should be considered.
or the unit HV breaker. When a generator breaker is
used, protection is available for the instance where 50BF-Neutral Element: This instantaneous
it fails to clear the fault or abnormal condition. Such overcurrent relay is energized from the generator
generator breaker failure protection output contacts neutral CT (See Figure 2-5, One-Line Functional
must be connected to trip the additional necessary Diagram). This function is internally in series with a
breakers to isolate the generator from the system. breaker “b” contact (IN1) to provide logic for the
breaker flashover protection (see Figure 2-38).
The breaker-failure condition is usually detected by
the continued presence of current in any one or HV Breaker Failure (limited) The breaker failure
more of the phases after a trip has been sent to the function may be used for a unit breaker rather than
breaker. However, the current detector (50BF-Ph) a generator breaker. It is limited in that it has no
may not always give the correct status of the fault detector associated with the unit breaker. Output
breaker, especially for generator breakers. This is contact operation would occur if any of the initiate
because faults and abnormal operating conditions contacts close and the 52b contact indicated a
such as ground faults, overexcitation, over/under closed breaker after the set time delay.
frequency, and reverse power may not produce
enough current to operate the current detectors. For This operation is chosen by disabling the neutral
this reason, the breaker status input 52b contact element, disabling the phase element, and
must be used, in addition to the 50BF-Ph, to provide designating initiating inputs and outputs and a time
adequate breaker status indication. delay setting.

2–46
 Application – 2

50BF PHASE ELEMENT If generator breaker failure function is used in this application, ENABLE
disable enable here.

50BF PICKUP PHASE Set phase pickup amps.

________ Amps

50BF NEUTRAL ELEMENT If the breaker flashover protection is to be used with the generator
disable enable breaker failure function of the relay, set ENABLE (enable phase
element also for this application.)

50BF PICKUP NEUTRAL Set the neutral pickup amps.

________ Amps

50BF INPUT INITIATE Designate the status inputs which will initiate the breaker failure
i6 i5 i4 i3 i2 i1 timer. Inputs IN7–IN14 must be set using IPScom®.

50BF OUTPUT INITIATE Designate the outputs that will initiate the breaker failure timer. Outputs
o8 o7 o6 o5 o4 o3 o2 o1 OUT9–OUT23 must be set using IPScom.

50BF DELAY For generator breaker failure protection, the time delay should be set to
________ Cycles allow for breaker operating time plus margin.

50BF-Ph
Overcurrent
I>P.U. AND
OR
Phase Initiate Enable

IN1 (52b)
NOT
Logic high when breaker closed
Logic high
when breaker open

50BF-N
Overcurrent
I>P.U.
AND
Programmed
Neutral Initiate Enable
OR
AND DELAY
TIME
Output
Contacts
Output Initiate
Input Initiate

Figure 2-38 Breaker Failure Logic Diagram

2–47
M-3425A Instruction Book

? X
F50BF

(50BF) - BREAKER FAILURE

Phase Current: 0.10 A 10.00 A 50BF

Enable Disable

Neutral Current: 0.10 A 10.00 A

Enable Disable

Delay: 1 Cycle 8160 Cycles

Output Initiate Input Initiate

Expanded I/O Initiate
8 7 6 5 4 3 2 1 6 5 4 3 2 1

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-39 Breaker Failure (50BF) Setpoint Ranges

2–48
 Application – 2

50DT Definite Time Overcurrent (for split-phase

differential)
The Definite Time Overcurrent (50DT) function can ■ NOTE: When 50DT function is used for split-
be applied in two different configurations based on phase differential, 50BF, 87 and 87GD
the CT connections. When CT configuration shown functions must be disabled.
in Figure 2-5, One Line Functional Diagram is used,
the 50DT function is used as a definite time phase Refer to Section 2.1, Configuration, Relay System
overcurrent function to provide protection for external Setup for a description of the 50DT Split-Phase
and internal faults in the generator. When the CTs Operate setting, and Section 2.2, System Diagrams.
are connected to measure the split phase differential
In some cases, the generators may be run with a
current (shown in Figure 2-6, Alternative One Line faulted turn shorted until the generator winding is
Functional Diagram), the 50DT function can be repaired. To prevent mis-operation under these
used as a split-phase differential relay.
conditions, the pickup setting of the faulted phase
should be set higher than the other phases. To
accommodate this function, individual pickup
settings are available for each phase. Ranges and
50DT #1 PICKUP PHASE A increments are presented in Figure 2-40
________ Amps

50DT #1 PICKUP PHASE B

________ Amps

50DT #1 PICKUP PHASE C

________ Amps

50DT #1 DELAY 50DT #2 screens are identical to 50DT #1.

________ Cycles

? X
F50DT

(50DT) - DEFINITE TIME OVERCURRENT

Pickup (A): 0.20 A 240.0 A #1

Pickup (B): 0.20 A 240.0 A

Pickup (C): 0.20 A 240.0 A

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup (A): 0.20 A 240.0 A #2

Pickup (B): 0.20 A 240.0 A

Pickup (C): 0.20 A 240.0 A

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-40 Definite Time Overcurrent (50DT) Setpoint Ranges

2–49
M-3425A Instruction Book

50/27 Inadvertent Energizing

The Inadvertent Energizing function (50/27) of the in a matter of seconds. Voltage supervised
relay is an overcurrent function supervised by overcurrent logic is designed to provide this
generator terminal bus voltage. Inadvertent or protection. (See Figure 2-41, Inadvertent Energizing
accidental energizing of off-line generators has Function Logic Diagram)
occurred frequently enough to warrant the use of
dedicated protection logic to detect this condition. An undervoltage element (all three phase voltages
Operating errors, breaker flashovers, control circuit must be below pickup) with adjustable pickup and
malfunctions or a combination of these causes dropout time delay supervises instantaneous
have resulted in generators being accidentally overcurrent tripping. The undervoltage detectors
energized while off-line. The problem is particularly automatically arm the overcurrent tripping when the
prevalent on large generators connected through a generator is taken off-line. This undervoltage detector
high voltage disconnect switch to either a ring bus will disable or disarm the overcurrent operation
or breaker-and-a-half bus configuration. When a when the machine is put back in service. Ranges
generator is accidentally energized from the power and increments are presented in Figure 2-42.
system, it will accelerate like an induction motor.
While the machine is accelerating, high currents
induced into the rotor can cause significant damage

50/27 PICKUP Typical pickup setting is 0.5 amps. No coordination is required with other
________ Amps protection since this function is only operational when the generator is
off-line.

50/27 VOLTAGE CONTROL The purpose of the undervoltage detector is to determine whether the unit
________ Volts is connected to the system. The voltage level during this accidental
energization depends on the system strength. Typical setting is 50%–
70% of rated voltage (in some cases, it may be set as low as 20%.)

50/27 PICKUP DELAY The pickup time delay is the time for the undervoltage unit to operate to
________ Cycles arm the protection. It must coordinate with other protection for conditions
which cause low voltages (typically longer than 21 and 51V time delay
settings.)

The dropout time delay is the time for the unit to operate to disarm the
50/27 DROPOUT DELAY
protection when the voltage is increased above the pickup value or the
________ Cycles
generator is brought on-line.

2–50
 Application – 2

50
Overcurrent
I>PU
Programmed
Timer AND Output
Contacts
Pickup
27 Delay
Undervoltage*
V<PU Dropout
Delay

* On All Three Phases Simultaneously

Figure 2-41 Inadvertent Energizing Function Logic Diagram

? X

F50/27

(50/27) - INADVERTENT ENERGIZING

(50) - OVERCURRENT 50/27
Pickup: 0.50 A 15.00 A

(27) - UNDERVOLTAGE
Pickup: 5V 130 V

Pick-up Delay: 1 Cycle 8160 Cycles

Drop-out Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-42 Inadvertent Energizing (50/27) Setpoint Ranges

2–51
M-3425A Instruction Book

51N Inverse Time Neutral Overcurrent

The Inverse Time Neutral Overcurrent function (51N) one cycle time delay should be added to these
provides protection against ground faults. Since no curves in order to obtain the relay operating time.
zero sequence or ground current is usually present Inverse time curves saturate beyond 20 times
during normal operation, this function can be set for pickup. For currents in excess of 20 times pickup,
greater sensitivity than the phase overcurrent operating times are fixed at the 20 times pickup
protection. If the 51N and 50N functions are not level.
used at the generator neutral, they can be used to
The function automatically selects fundamental
detect system ground faults by being energized by RMS or total RMS calculation based on the input
the step-up transformer neutral CTs. Ranges and frequency. When the generator frequency is within
increments are presented in Figure 2-43. &5 Hz from the nominal frequency, it uses
The curves available for use are shown in Appendix fundamental RMS calculation. Outside of this range,
it uses total RMS calculation, which will provide
D, Inverse Time Curves. They cover a range from
protection during offline down to a frequency of 8
1.5 to 20 times the pickup setting. An additional
Hz.

51N PICKUP The relay current (IR) is equal to the primary current (IP) divided by the
________ Amps appropriate CT ratio. IR = IP ÷ CT ratio

Select one of the time curves shown in Appendix D, Inverse Time

51N CURVE
Curves. The appropriate curve in the selected family is designated
bedef beinv bevinv
here.
Appropriate Time Dial for coordination with “downstream” relay
51N TIME DIAL protection chosen from the time curve above.
________

? X

F51N

(51N) - INVERSE TIME NEUTRAL OVERCURRENT

#1
Pickup: 0.25 A 12.00 A

Time Dial: 0.5 11.0

Curves
Beco Definite Time Beco Inverse Beco Very Inverse Beco Extremely Inverse

IECI IECVI IECEI IECLTI

IEEE Moderately Inverse IEEE Very Inverse IEEE Extremely Inverse

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-43 Inverse Time Neutral Overcurrent (51N) Setpoint Ranges

2–52
 Application – 2

51V Inverse Time Phase Overcurrent with 51V is a true three-phase function, in that the relay
Voltage Control/Restraint incorporates separate integrating timers on each
Time-overcurrent relays, one per phase, are used phase.
to trip circuits selectively and to time-coordinate
with other up- or downstream relays. For this The inverse time overcurrent function can be voltage
function, eight complete series of inverse time controlled (VC), voltage restrained (VR), or neither.
tripping characteristics are included. The same For voltage-controlled operation, the function is not
descriptions and nomenclature which are traditionally active unless the voltage is below the voltage
used with electromechanical relays are used in the control setpoint. This philosophy is used to confirm
relay. Thus, user may choose from four BECO that the overcurrent is due to system fault. When
curves (BEDEF, BEINV, BEVINV, and BEEINV), applied, most users will set voltage control limits in
four IEC curves (IECI, IECVI, IECEI, and IECLT), the range of 0.7 to 0.9 per unit RMS voltage. When
and three IEEE curves (MINV, VINV, EINV.) Within voltage restraint is selected (See Figure 2-44,
each family, the operator selects time dial setting Voltage Restraint (51VR) Characteristic), the pickup
and pickup (tap) setting, just as with setting is continuously modified in proportion to the
electromechanical relays. Ranges and increments collapsing terminal voltage. The voltage restraint
are presented in Figure 2-45. function is well-suited to small generators with
relatively short time constants.
The curves available for use are shown in Appendix
D, Inverse Time Curves. They cover a range from ■ NOTE: The 51V function should be blocked by
1.5 to 20 times the pickup setting. An additional fuse loss if in the voltage control mode
one cycle time delay should be added to these only. Fuse loss blocking is not desirable
for voltage restraint mode because the
curves in order to obtain the relay operating time.
pickup is automatically held at 100%
Inverse time curves saturate beyond 20 times
pickup during fuse loss conditions, and
pickup. For currents in excess of 20 times pickup, operation will continue as normal.
operating times are fixed at the 20 time pickup
level. The particular settings will be made by The internally derived voltage used to realize the
information from short-circuit fault studies and voltage control or restraint feature depends on the
knowledge of the coordination requirements with configured VT configuration and the Delta-Y
other devices in the system that respond to time Transform setting (see Section 2.1, Configuration,
overcurrent. Relay System Setup). Table 2-4, Delta/Wye
Transformer Voltage-Current Pairs describes the
calculation for the various system VT configurations.

51V PICKUP The pickup of the 51V is set in relay amps.

________ Amps (Relay amps = primary amps ÷ CT ratio)

Selects one of the time curves as shown in Appendix D, Inverse

51V CURVE
Time Curves. The appropriate curve in the selected family of curves
bedef beinv bevinv
is designated here.

51V TIME DIAL

________

51V VOLTAGE CONTROL Disable if neither voltage control nor voltage restraint is desired. If
disable V_CNTL v_rstrnt voltage restraint is designated, the tap setting is modified as shown in
Figure 2-43. If voltage control is designated, the 51V will only operate
when the voltage is less than the 51V voltage control setting specified
51V VOLTAGE CONTROL below. When applied, the voltage control is usually set in the range of
________ Volts 70% to 90% of the nominal voltage.

2–53
M-3425A Instruction Book

100

75

Tap Setting as %
of Tap Setting at 50
Rated Voltage

25

0 25 50 75 100

Input Voltage (% of rated voltage)

Figure 2-44 Voltage Restraint (51VR) Characteristic

Generator Connected Through

Generator Directly Connected
Delta AB/Wye or Delta AC/Wye Transformer
Voltage Control or Restraint Voltage Control or Restraint
Current Current
L-G L-L or L-G to L-L L-G L-L or L-G to L-L
Ia (VA " VC)/S3 VAB Ia VA (VAB " VCA)/S3
Ib (VB " VA)/S3 VBC Ib VB (VBC " VAB)/S3
Ic (VC " VB)/S3 VCA Ic VC (VCA " VBC)/S3

Table 2-4 Delta/Wye Transformer Voltage-Current Pairs

? X

F51V

(51V) - INVERSE TIME OVERCURRENT WITH VOLTAGE CONTROL OR VOLTAGE RESTRAINT

#1
Pickup: 0.50 A 12.00 A
Time Dial: 0.5 11.0

Curves
Beco Definite Time Beco Inverse Beco Very Inverse Beco Extremely Inverse

IECI IECVI IECEI IECLTI

IEEE Moderately Inverse IEEE Very Inverse IEEE Extremely Inverse

Voltage Control: 5V 180 V

Disable Voltage Control Voltage Restraint

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-45 Inverse Time Overcurrent with Voltage Control/Voltage Restraint (51VC/VR)
Setpoint Ranges

2–54
 Application – 2

59 Phase Overvoltage
The Phase Overvoltage function (59) may be used Magnitude measurement depends on the 59/27
to provide overvoltage protection for the generator. Magnitude Select setting (See Section 2.1,
The relay provides overvoltage protection functions Configuration, Relay System Setup). When the
with three voltage levels and three definite-time RMS option is selected, the magnitude calculation
setpoints, any one or more of which can be is accurate over a wide frequency range (10 to 80
programmed to trip the unit or send an alarm. This Hz) and the accuracy of the time delay is +20
is a true 3-phase function in that each phase has an cycles. If DFT option is selected, the magnitude
independent timing element. calculation is accurate near 50 or 60 Hz, and the
timer accuracy is &1 cycle. When the input voltage
The 59 function can be programmed to use phase select is set to positive sequence voltage, the 59
voltage (any one of the three phases) or positive functions uses DFT to measure the positive
sequence voltage as input. sequence voltage, irrespective of DFT/RMS
selection. Ranges and increments are presented in
Figure 2-46.

59 #1 INPUT VOLTAGE SEL. Generator capability is generally 105% of rated voltage.

phase_volt pos_seq_volt
59 #2 and 59 #3 screens are identical to 59 #1.

59 #1 PICKUP
________ Volts

59 #1 DELAY
________ Cycles

? X
F59
(59) - PHASE OVERVOLTAGE

Input Voltage Select: Phase Voltage Positive Sequence Voltage

#1
Pickup: 5V 180 V

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Input Voltage Select: Phase Voltage Positive Sequence Voltage #2

Pickup: 5V 180 V
Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

Input Voltage Select: Phase Voltage Positive Sequence Voltage

#3

Pickup: 5V 180 V

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, Function DISABLED until output selected!

Save Cancel

Figure 2-46 Phase Overvoltage (59) Setpoint Ranges

2–55
M-3425A Instruction Book

59D Third Harmonic Voltage Differential (Ratio)

This scheme, when used in conjunction with 59N operation of the differential relay (see Figure 2-20).
function may provide 100% Stator Ground fault The generator terminal voltage (Line Side Voltage)
protection. can be selected as 3V0 (Calculated by the relay
from VA, VB and VC) or VX (broken delta VT input
Figure 2-47 illustrates a third harmonic voltage connected at the VX input.) Positive sequence
differential scheme. This scheme compares the undervoltage blocking will prevent the function from
third harmonic voltage appearing at the neutral to misoperating when the generator is offline (the
that which appears at the generator terminals. The terminal voltage is below the set value).
ratio of these third harmonic voltages is relatively
constant for all load conditions. A stator phase-to-
ground fault will disrupt this balance, causing

59D RATIO The ratio (or third harmonic) voltage measured at the generator
________ terminals to the third harmonic voltage measured at neutral. This
setting requires field measurements of third-harmonic voltage. Take
measurements at various loadings and use smallest ratio:
V3N
= Ratio
V3X
Ratio/2 = Setpoint (50% margin)

Selection of VX will give better accuracy and sensitivity than 3V0. If

59D LINE SIDE VOLTAGE
3V0 is selected, VT configuration must be set to Line-Ground. If the
3v0 VX
nominal third harmonic voltage is <1 V, 3V0 line side voltage selection
is not recommended, because noise in the 3V0 and VN can cause 59D
misoperation.

This setting is typically enabled.

59D POS SEQ VOLT BLK
disable ENABLE

59D POS SEQ VOLT BLK

________ Volts

59D DELAY
________ Cycles

2–56
 Application – 2

M-3425A

V 3N V 3X

The ratio V3x > Pickup

V3N
Where: V3x 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) Scheme for Generator Ground Fault
Protection

? X

F59D

(59D) - THIRD HARMONIC VOLTAGE DIFFERENTIAL

Line Side Voltage: 3V0 VX #1

Ratio (VX/VN): 0.1 5.0

Delay: 1 Cycle 8160 Cycles

Pos Seq Voltage Block: 5V 180 V

Enable Disable

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-48 Third Harmonic Voltage Differential (59D) Setpoint Ranges

2–57
M-3425A Instruction Book

59N Overvoltage, Neutral Circuit or Zero

Sequence
The Neutral Overvoltage function (59N) provides The 59N function provides three setpoints, and
stator ground fault protection for high impedance responds only to the fundamental frequency
grounded generators. The 59N function can provide component, rejecting all other harmonic components.
ground fault protection for 90–95% of the stator Ranges and increments are presented in Figure
winding (measured from the terminal end). 2-50.
With typical grounding transformer ratios and a typical minimum setting of 5
59N #1 PICKUP
volts, this protection is capable of detecting ground faults in about 95% of the
________ Volts 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 the
59N #1 DELAY transformer secondary winding. If relay time delay for coordination is not
acceptable, the coordination problem can be alleviated by grounding one of
________ Cycles
the secondary phase conductors instead of the secondary neutral. When this
technique is used, the coordination problem still exists for ground faults on the
59N 20HZ INJECTION MODE secondary neutral conductor. Thus, its usefulness is limited to those applications
where the exposure to ground faults on the secondary neutral is small.
disable ENABLE
Since system ground faults can induce zero sequence voltages at the generator
due to transformer capacitance coupling, this relay must coordinate with the
system ground fault relaying. It is possible to set 59N#1, 59N#2, and 59N#3 to
59N #2 and 59N #3 screens coordinate with the PT secondary fuses, and also coordinate with worst case
are identical to 59N #1. capacitive coupling interference voltage from system ground faults (high side
of the GSU).)
For applications where the M-3425A relay (where the 64S function is purchased
or not) is used with 100% Stator Ground protection with 20 Hz injection schemes,
the 59N 20 Hz injection mode must be enabled in order to calculate the voltage
magnitude accurately for the 59N function, due to the 20 Hz injection voltage.
The time delay accuracy of the function is –1 to +5 cycles when the 20 Hz
injection mode is enabled.

? X

59N

(59N) - NEUTRAL OVERVOLTAGE

Pickup: 5.0 V 180.0 V #1

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

Pickup: 5.0 V 180.0 V #2

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 5.0 V 180.0 V #3

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

20 Hz Injection Mode: o Enable o Disable

@ : WARNING,You have not selected an output!

Save Cancel

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

2–58
 Application – 2

59X Multipurpose Overvoltage (Turn-to-Turn

Stator Fault Protection or Bus Ground
Protection)
For generators where the stator-winding configuration faults. The relay will, however, operate for turn-to-
does not allow the application of split-phase turn faults, which increase the 3V0 voltage above
differential, a neutral voltage method can be used to low normal levels. Installation requires the cable
detect turn-to-turn stator winding faults. Figure 2-50 from the neutral of the VT to generator neutral be
illustrates this method. Three VTs are connected in insulated for the system line-to-ground voltage and
wye and the primary ground lead is tied to the the relay to be tuned to fundamental (60/50 Hz)
generator neutral. The secondary is connected in a frequency components of the voltage since some
“broken delta” with an overvoltage relay connected third-harmonic frequency component of the voltage
across its open delta to measure 3V0 voltage. In will be present across the broken delta VT input.
High Impedance grounded generators, connecting
the primary ground lead to the generator neutral, Alternatively, this function can be used to detect
bus ground faults, when connected as shown in
makes this element insensitive to stator ground
Figure 2-10.

59X #1 PICKUP When used for Turn-to-Turn fault protection the pickup should be set
________ Volts above the normal zero sequence voltage level. Typically the pickup
is set to 5 V.
When used for Bus Ground protection it is again set above the normal
zero sequence voltage seen at the bus. Typical setting is between 10
and 20 Volts to provide sensitive protection.
The Time Delay for Turn-to-Turn faults should be set to approximately
59X #1 DELAY
5 cycles. For bus ground fault protection application the time delay
________ Cycles
should coordinate with other ground fault relaying and VT fuses.
59X #2 screens are identical to 59X #1.

GENERATOR

See Note Below VT

R 3V 0

59X

■ NOTE: Installation requires the cable from the neutral of the VT to generator neutral be insulated for the
system line-to-ground voltage.

Figure 2-50 Turn-to-Turn Stator Winding Fault Protection

2–59
M-3425A Instruction Book

? X

F59X

(59X) - MULTIPURPOSE OVERVOLTAGE

Pickup: 5V 180 V #1
Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 5V 180 V #2
Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

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Figure 2-51 (59X) Multi-purpose Overvoltage Setpoint Ranges

2–60
 Application – 2

60FL VT Fuse Loss

Some functions may operate inadvertently when a The 60FL function does not have to be enabled in
VT fuse is blown or an event causes a loss of one, order to use the FL as a blocking input in the relay
two, or all three potentials to the relay. Provisions configuration menu.
are incorporated for both internal and external
potential loss detection and blocking of user defined
functions. The logic scheme and options are External Fuse-Loss Function
illustrated in Figure 2-52. For the specific application where the preceding
logic cannot be considered reliable (such as when
Internal Fuse Loss Detection Logic current inputs to the relay are not connected, or
The internal logic scheme available will detect a sustained positive sequence current during fault
loss of one, two, and all three potentials. conditions is minimal), an external fuse failure
function can be used as an input to the relay. The
For the loss of one or two potentials, positive and external 60 FL Function contact is connected across
negative sequence quantities are compared. The any control/status input. The relay protection
presence of negative sequence voltage in the functions are then blocked by an assertion of the
absence of negative sequence current is considered control/status input (INx), as a blocking function in
to be a fuse loss condition. An additional each function’s respective setting screen.
supervising condition includes a minimum positive
sequence voltage to assure voltage is being applied
to the relay. 60FL VT Fuse Loss Alarm Function
The 60FL alarm function is enabled by the internal
For the loss of all three phase potentials, a logic by selecting the “FL” option in the 60 FL
comparison of the three phase voltages is made to function setup screen. It is enable by the external
the three phase currents. If all three potentials are logic by selecting the appropriate control/status
under 0.05 Vnom, and all three currents are below input (INx) in the 60FL function setup screen.
1.25 Inom combined with I1 > 0.33A, a three phase
potential loss is declared. A seal in circuit is A timer associated with the fuse loss alarm logic is
provided to ensure a three phase fuse loss condition available. This timer is to assure proper coordination
is not declared during a three phase fault if the fault for conditions that may appear as a fuse loss, such
current decays below the 1.25 Inom pickup setting. as secondary VT circuit faults that will be cleared
by local low voltage circuit action (fuses or circuit
Protection functions in the relay may be blocked breakers). Ranges and increments are presented in
by an assertion of the fuse failure logic (FL), in Figure 2-53.
each function’s respective setting screen. Typical
functions to block on a loss of potential event are
21, 27, 32, 40, 51V (for Voltage Control only), 67,
67N, 78 and 81.

60FL INPUT INITIATE The initiating control/status inputs are user-designated. The clos-
FL i6 i5 i4 i3 i2 i1 ing of any of the externally connected contacts (across these in-
puts) will start the associated time delay to the 60FL function op-
60FL 3 PHASE DETECT eration. In order to use internal fuse loss logic for 60FL function,
disable enable “FL” must be checked. Externally initiated fuse loss detection may
be input to other status inputs. Inputs IN7–IN14 must be set using
IPScom®.

60FL DELAY The time delay is set to coordinate for conditions which may appear
________ Cycles as a fuse loss but will be corrected by other protection (such as a
secondary VT circuit fault which will be cleared by local low voltage
circuit action). This delay does not affect internal FL blocking op-
tion.

2–61
2–62
External Fuse
INx Loss Function Protection Function Block
External
Signal by INx from External FL
"FL" Function

60FL Alarm Function initiate by

T 60FL Alarm Signal
internal "FL" or Status Input Contact INx

Internal 60FL Logic: 1 & 2 Phase Loss of Potential FL Protection Function Block
M-3425A Instruction Book

Signal by Internal FL Logic

V1 > 12.8 V OR
AND
V1 Verifies VT voltage is applied
V2 > 0.33 V1 V2 Provides indication of blown fuse
AND I2 Prevents operation during phase-phase faults
I1 Prevents output contacts from chattering when
I2 > 0.167 I1
a fuse blows during no load operation.
OR
I1 > 0.33 A
* Values in parentheses apply to a 1 A CT secondary
(.067A)* rating.

Disable Enable
AND

IA > 1.25 IN
I1 Verifies On-line condition
OR AND
IB > 1.25 IN OR VA,B,C Indication of 3-phase loss of potential
IA,B,C Prevents operation during faults
IC > 1.25 IN
Seal-in circuit ensures logic doesn't produce an
output during 3-phase fault when current decays
VA < 0.05 VN below1.25IN

VB < 0.05 VN AND

VC < 0.05 VN
Internal 60FL Logic: 3 Phase Loss of Potential

Figure 2-52 Fuse Loss (60FL) Function Logic

 Application – 2

? X

F60FL

(60FL) - VT FUSE-LOSS DETECTION

Delay: 1 Cycle 8160 Cycles 60FL

Input Initiate
Expanded Input Initiate
FL 6 5 4 3 2 1

Three Phase Fuse Loss Detection: Enable: Disable:

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-53 Fuse Loss (60FL) Setpoint Ranges

2–63
M-3425A Instruction Book

64B/F Field Ground Protection cabling between the coupler and relay exceeds 100
64F Field Ground Detection feet, provisions should be made for in circuit
A typical connection diagram for Field Ground calibration to nullify the effects of cabling
Protection is given in Figure 2-54. This function capacitance. See Section 6.4, Auto Calibration, for
requires the connection of an external coupler calibration procedure.
(M-3921). To improve accuracy and minimize the The Field Ground function provides detection of
effects of stray capacitance, the M-3921 Field insulation breakdown between the excitation field
Ground Coupler should be mounted close to the winding and the ground. There are two pickup and
exciter. Connections from the coupler to the relay time delay settings, and one adjustable injection
should use low capacitance shielded cable, and be frequency setting for the 64F function. The adjustable
as short as possible. Cable shield should be frequency is provided to compensate for the amount
terminated at the relay end to the Relay Ground of capacitance across the field winding and the
Stud (See Figure 5-9, External Connections). If ground so that the function accuracy is improved.
Ranges and increments are presented in Figure
2-55.
64F #1 PICKUP
________ kOhm

64F #1 DELAY
________ Cycles

64F #2 PICKUP
________ kOhm

64F #2 DELAY
________ Cycles

PROTECTION RELAY
M-3425A

PROCESSOR

SUPPLY
VOLTAGE

Rear Terminal
Field Ground Block Pin No.
Brushes
Detection

TB3
Squarewave Vout
Generator 37 TB5 Gen.
Rotor
35 TB4 TB2

Signal COUPLING
Measurement Vf NETWORK Rf.Cf
and Processing (M-3921)

Shaft
36 TB1 TB1 Ground
Shield Brush

Relay Ground Stud

Ground/Machine Frame

Figure 2-54 M-3921 Field Ground Coupler

2–64
 Application – 2

The following Table gives typical frequency settings 8 WARNING: Machine should be off-line and
based on the rotor capacitance. The rotor field excitation should be off during the
capacitance can be measured with a capacitance capacitance measurement.
meter by connecting the meter across the field
winding to ground. ■ NOTE: Field breaker should be closed for the
capacitance measurements.

Fie ld Winding to
Typical Fre que ncy Se tting
Ground Capacitance

1 to 2 µF 0.52 Hz

2 to 3 µF 0.49 Hz

3 to 4 µF 0.46 Hz

4 to 5 µF 0.43 Hz

5 to 6 µF 0.39 Hz

6 to 7 µF 0.35 Hz

7 to 8 µF 0.32 Hz

8 to 9 µF 0.30 Hz

9 to 10 µF 0.28 Hz

>10 µF 0.26 Hz

Table 2-5 Typical Frequency Settings

? X
F64F/B

(64F/B) - FIELD GROUND PROTECTION

Pickup: 5 KOhms 100 KOhms 64F#1

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 5 KOhms 100 KOhms 64F#2

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 0 mV 5000 mV 64B

Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Frequency: 0.10 Hz 1.00 Hz

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-55 Field Ground Protection (64B/F) Setpoint Ranges

2–65
M-3425A Instruction Book

64B Brush Lift-Off Detection

Brush Lift-Off Detection (64B) provides detection of ■ NOTE: Field breaker should be closed for the
open brushes of the rotor shaft. This function works capacitance measurements.
in conjunction with the 64F Field Ground Detection
function, and requires the M-3921 Field Ground 1. After installation has been completed,
Coupler. determine the rotor capacitance, as
outlined for the 64F function.
When 64B operates, indicating open brush
2. With the machine still off-line, apply
conditions, the 64F Function cannot detect a field power to the relay and set the 64B/F
ground. For most generators, when the brushes of operating frequency in accordance with
the rotor shaft are lifted, the capacitance across the the value listed in Table 2-5, Typical
field winding and the ground significantly reduces to Frequency Settings.
less than 0.15 µF. The 64B Function analyzes this
capacitance-related signal, and initiates an output 3. Introduce a brush-open condition by
contact when it detects an open brush condition. disconnecting the rotor brushes or lifting
Typically, this output is used to alert operating the brushes from their ground. Observe
personnel of an open brush condition. Ranges and the 64B voltage value displayed by
increments are presented in Figure 2-58. The typical IPScom or the relay. The displayed value
is the actual measured operating value
pickup setting is listed in Table 2-6, Typical Brush
of the 64B function.
Lift-Off Pickup Settings.
4. To ensure correct operation and prevent
In order to assure correct setting, it is recommended erroneous trips, the Pickup Setting for
that the actual operating value be predetermined the 64B Lift-off condition should be set
during the final stage of the relay installation. By at 80–90% of the actual operating value.
introducing a brush-open condition, the actual value
can be easily obtained from the relay. The following The 64B/F Frequency is a shared setting common
procedure can be used to obtain the actual operating to both the 64B and 64F Functions. If either function
value of the 64B during an open brush condition: is enabled, this setpoint is available, and should be
8 WARNING: Machine should be off-line and set to compensate for the amount of capacitance
field excitation should be off during the across the field winding and ground, so that the
capacitance measurement. measurement accuracy is improved.

64B PICKUP
________ mV

64B DELAY
________ cycles

64B/F FREQUENCY To minimize measurement errors, the 64B/F frequency

________ Hz should be set according to the amount of capacitance
across the field winding and the ground. Table 2-5 in-
cludes typical settings of the frequency for capacitance,
ranging from 1 µF to 10 µF.

Typical Brus h Lift-Off

Equivale nt Brus h Lift-Off Capacitance
Pickup Se tting

0.05~0.25 µF 2500 mV

Table 2-6 Typical Brush Lift-Off Pickup Setting

2–66
 Application – 2

64S 100% Stator Ground Protection by Low The expected 20 Hz current during no fault condition
Frequency Signal Injection is given by:
■ NOTE: The Stator Ground Protection function
(64S) must be selected when the V20 • N2
INF =
M-3425A is initially ordered.
XCS
The 100% stator ground fault protection is provided
Where V20 is the 20 Hz voltage measured across
by injecting an external 20 Hz signal into the neutral
the load resistor RL and XCS is the capacitive
of the generator. The protection is provided when
reactance of the gnereator stator winding and unit
the machine is on-line as well as off-line (provided
transformer referred to the grounding transformer
that the 20 Hz generator and relay are powered on.)
secondary. N is the turn ratio of the grounded
This scheme requires the following external
transformer. The pickup setting should be based on
components in addition to M-3425A protection
the required insulation resistance setting. In order
system:
to detect a fault of 5,000 Ohms on the generator
• 20 Hz Signal-generator (BECO Part No. stator, the pickup current should be set at:
430-00426)
• Band-pass filter. (BECO Part No.
430-00427) V20 N2
IPICKUP =
• 20 Hz Measuring Current Transformer, 50002 + XCS2
400/5 A CT (BECO Part No. 430-00428)
20 Hz CT Ratio
The voltage signal generated by the 20 Hz signal-
generator is injected into the secondary of the When the generator is operating normally (no ground
generator neutral grounding transformer through a fault) only a small amount of 20 Hz current will flow
band-pass filter. The band-pass filter passes the 20 as a result of the stator capacitance to ground.
Hz signal and rejects out-of-band signals. The output When a ground fault occurs anywhere on the
of the 20 Hz band-pass filter is connected to the VN generator stator windings the 20 Hz current will
input of the M-3425A relay through a suitable voltage increase. The 64S function will issue a trip signal
divider, that limits the M-3425A to O 200 V ac (the after a set time delay when the measured 20 Hz
voltage generator may be bypassed if the expected current exceeds the pickup current as illustrated in
50/60 Hz voltage during a phase-to-ground fault of Figure 2-57.
the generator is O 200 V.) The 20Hz current is also
connected to the IN input of the M-3425A, through The 64S protection can be blocked by Undervoltage
the 20Hz current transformer. Inhibit. If the 20 Hz voltage (nominal 25 V) is less
than the Undervoltage Inhibit setting (and
Undervoltage Inhibit is enabled), the 64S function
64S PICKUP will be blocked. For cases where the Load Resistor
mAmps (RL) is small, the Undervoltage Inhibit should not
be enabled, as the voltage will be small.
64S VOLT INHIBIT The 59N function (90 to 95%) should also be used
disable ENABLE in conjunction with 64S protection to provide backup.
▲ CAUTION: Dangerous high voltages may be
64S VOLT INHIBIT present at the generator terminals if the 20 Hz
injection voltage is not removed when the generator
________ Volts
is taken out of service.
If the 20 Hz injection voltage generator receives
64S DELAY power from the generator terminal voltage, then the
________ Cycles 20 Hz injection voltage generator will be
automatically switched off whenever the generator
terminal voltage is not present.

2–67
 M-3425A Instruction Book

20 Hz
Supply
Generator Voltage
20 Hz DC AC
Band Pass 430- 1A1 +V Aux V A(L1)

Filter 00426 1A2 -V Aux V B(L2)

1A3 V C(L3)
1B1 1B4 4A1
2A1
430-00427 Bl
External
2A3 Block
1A1
3A2 Device
Neutral 400A
RL 59N 1A3 1A4 Wiring Operative
Grounding 5A 3A3
L K Shielded
Transformer 4A3 3A1
l k High
400/5 A Voltage
430-00428 20 Hz CT

M-3425A
Low Max. 200 V
Voltage 44 45
V N

52 53
I N

Figure 2-56 64S Function Component Connection Diagram

Measured 20 Hz Current

140 %
64S
Pickup
Current
TRIP
I20

60 %

0V 5V 10 V 15 V 20 V 25 V 30 V 35 V 40 V 45 V
20 Hz Injection Voltage

Figure 2-57 64S Function Time Delay Pickup Current Correlation

2–68
 Application – 2

? X

F64S

(64S) - 100% STATOR GROUND

#1
Pickup: 2 mA 40 mA

Delay: 1 Cycle 8160 Cycles

Undervoltage Inhibit: Enable Disable
5V 30 V

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-58 100% Stator Ground Protection (64S) Setpoint Ranges

2–69
M-3425A Instruction Book

67N Residual Directional Overcurrent

The Residual Directional Overcurrent function (67N) provides both definite time and inverse time
provides protection from ground faults. The 67N elements. The inverse time element provides several
function can provide generator ground fault curves. The curves available for use are shown in
protection. It can also provide directional Appendix D, Inverse Time Curves. They cover a
discrimination when multiple generators are bused range from 1.5 to 20 times the pickup setting. An
together. The 67N Function is subject to the following additional one cycle time delay should be added to
configuration limitations: these curves in order to obtain the relay operating
• VX polarization cannot be selected if 25 time. Inverse time curves saturate beyond 20 times
(Sync) function is enabled. pickup. For currents in excess of 20 times pickup,
operating times are fixed at the 20 time pickup
• 3V0 polarization can only be used with level.
Line-Ground VT configuration.
• 67N Function is not available if 87GD is
To obtain maximum sensitivity for fault currents,
enabled.
the directional element is provided with a maximum
sensitivity angle adjustment (MSA). This setting is
The 67N Function operates on the residual current common to both the 67NDT and 67NIT elements.
either from internal calculation (3I0) using IA, IB and The pickup sensitivity of the relay remains constant
IC or using a residual current input from IN input of for 90° either side of the so-called Maximum
the relay (this is preferred compared to 3I0). The Sensitivity Angle (MSA). At angles over 90° from
relay can be polarized with the neutral voltage (VN), MSA, the relay operation is blocked. Typical MSA
broken delta voltage connected at VX input or 3V0 setting for a generator internal ground fault protector
calculated using VA, VB and VC inputs. The function is approximately 150°.

Figure 2-59 Residual Directional Overcurrent (67N) Trip Characteristics

2–70
 Application – 2

67NDT PICKUP Pickup value for the 67N element.

________ Amps

67NDT DIR ELEMENT Directional discrimination enable. When disabled, this function
disable ENABLE will work like a 50N.

67NDT DELAY Time Delay setting.

________ Cycles

67NIT PICKUP Inverse Time Pickup

________ Amps

67NIT DIR ELEMENT Directional discrimination enabled. When disabled, this function
disable ENABLE will operate like 51N.

67NIT CURVE Select the inverse time curve.

bdef binv bvinv beinv

67NIT TIME DIAL Time dial setting

________

67N MAX SENSITIVITY ANGLE See Figure 2-59 for Max Sensitivity Angle (MSA) settings.
________ Degrees

67N OPERATING CURRENT Select the operating current.

3I0 in

67N POLARIZING QUANTITY Select the polarization voltage. If 3V0 is selected, VT configura-
3V0 vn vx tion must be set to Line-Ground.

2–71
M-3425A Instruction Book

? X
F67N
(67N) - RESIDUAL DIRECTIONAL OVERCURRENT
Pickup: 0.5 A 240.0 A
Def. Time
Delay: 1 Cycle 8160 Cycles

Directional Element: Enable Disable

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

Pickup: 0.25 A 12.00 A

Inv. Time
Time Dial: 0.5 11.0

Curves
BECO Definite Time BECO Inverse BECO Very Inverse BECO Extremely Inverse IECI IECVI

IECEI IECLTI IEEE Moderately Inv. IEEE Very Inverse IEEE Extremely InverseI

Directional Element: Enable Disable

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Max Sensitivity Angle: 0o 359o

Operating Current: 3I0 IN

Polarizing Quantity: 3V0 (Calculated) VN VX

@ : WARNING, You have not selected an output!

Note: VX cannot be selected if 25 (Sync) function is enabled.

3V0 can only be used with Line-Ground VT configuration.

Save Cancel

Figure 2-60 Residual Directional Overcurrent (67N) Setpoint Ranges

2–72
 Application – 2

78 Out-of-Step
The Out-of-Step function (78) is used to protect the Consider, for example, Figure 2-62. If the Out-of-
generator from out-of-step or pole slip conditions. step swing progresses to impedance Z0(t0), the
This function uses one set of blinders, along with a MHO element and the blinder A element will both
supervisory MHO element. Ranges and increments pick up. As the swing proceeds and crosses blinder
are presented in Figure 2-63. B at Z1(t1), blinder B will pick up. When the swing
reaches Z2(t2), blinder A will drop out. If TRIP ON
The pickup area is restricted to the shaded area in MHO EXIT option is disabled and the timer has
Figure 2-61, Out-of-Step Relay Characteristics, expired (t2–t1>time delay), then the trip circuit is
defined by the inner region of the MHO circle, the complete. If the TRIP ON MHO EXIT option is
region to the right of the blinder A and the region to enabled and the timer has expired, then for the trip
the left of blinder B. For operation of the blinder to occur the swing must progress and cross the
scheme, the operating point (positive sequence MHO circle at Z3(t3) where the MHO element drops
impedance) must originate outside either blinder A out. Note the timer is active only in the pickup
or B, and swing through the pickup area for a time region (shaded area). If the TRIP ON MHO EXIT
greater than or equal to the time delay setting and option is enabled, a more favorable tripping angle is
progress to the opposite blinder from where the achieved, which reduces the breaker tripping duty.
swing had originated. When this scenario happens, The relay can also be set with a Pole Slip Counter.
the tripping logic is complete. The contact will The relay will operate when the number of pole slips
remain closed for the amount of time set by the are greater than the setting, provided the Pole Slip
seal-in timer delay. Reset Time was not expired. Typically, the Pole
XT = Transformer Reactance Slip Counter is set to 1, in which case the Pole Slip
Reset Time is not applicable.
XS = System Reactance
Xd’= Transient Reactance of the Generator

78 DIAMETER Typical setting is (1.5XT+2Xd’)

________ Ohms

78 OFFSET Typical setting is –2Xd’.

________ Ohms

78 BLINDER IMPEDANCE Typical setting is (1/2) (Xd’+ XT + XS) tan(Θ–(δ/2)). Typical

________ Ohms value for δ is 120°.

78 IMPEDANCE ANGLE Typical setting for Θ is 90°.

________ Degrees

78 DELAY The time delay should be set based on the stability study. In
________ Cycles the absence of such a study, it can be set between 3 and 6
cycles.

78 TRIP ON MHO EXIT This setting is typically enabled.

disable enable

78 POLE SLIP COUNT Typical setting is 1 pole slip.

________ slips

78 POLE SLIP RESET TIME Typical setting is 120 cycles.

________ Cycles

2–73
M-3425A Instruction Book

A B

Z3(t3)

Z0(t0)

Z1(t1)
Z2(t2)

Figure 2-61 Out-of-Step Relay Characteristics

D
A B

SYSTEM
XS

O
1.5 X T

TRANS
XT
P G
N δ F R
M
H

d SWING
LOCUS
GEN
(X 'd) MHO
ELEMENT

2X d'

BLINDER
ELEMENTS

Figure 2-62 Out-of-Step Protection Settings

2–74
 Application – 2

? X
F78

(78) - OUT OF STEP

Circle Diameter: 0.1 Ohm 100.0 Ohms #1

Offset: - 100.0 Ohms 100.0 Ohms

Blinder Impedance: 0.1 Ohm 50.0 Ohms

Impedance Angle: 0° 90°

Pole Slip Counter: 1 20

Pole Slip Reset Time: 1 Cycle 8160 Cycles

Delay: 1 Cycle 8160 Cycles

Trip on MHO Exit: Enable Disable

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING,You have not selected an output!

Save Cancel

Figure 2-63 Out-of-Step (78) Setpoint Ranges

2–75
M-3425A Instruction Book

81 Frequency
The Frequency function (81) provides either Sample settings of the 81 function are shown in
overfrequency or underfrequency protection of the Figure 2-64. The frequency functions are
generator. It has four independent pickup and time automatically disabled when the input voltage
delay settings. The overfrequency mode is (positive sequence) is very low (typically between
automatically selected when the frequency setpoint 2.5 V and 15 V, based on the frequency.)
is programmed higher than the base frequency (50
or 60 Hz), and the underfrequency mode selected The 81 function should be disabled using breaker
when the setpoint is programmed below the base contact when the unit is offline.
frequency. Ranges and increments are presented
in Figure 2-65.
The steam turbine is usually considered to be more
restrictive than the generator at reduced frequencies
because of possible natural mechanical resonance
in the many stages of the turbine blades. If the
generator speed is close to the natural frequency of
any of the blades, there will be an increase in
vibration. Cumulative damage due to this vibration
can lead to cracking of the blade structure.

81 #1 PICKUP These magnitude and time settings describe a curve (as shown in
________ Hz Figure 2-64, Example of Frequency (81) Trip Characteristics) which is
to be coordinated with the capability curves of the turbine and
generator as well as the system underfrequency load-shedding
81 #1 DELAY program. These capabilities are given by a description of areas of
________ Cycles prohibited operation, restricted time operation, and continuous
allowable operation.
The underfrequency function is usually connected to trip the machine
81 #2 PICKUP whereas the overfrequency function is generally connected to an
________ Hz alarm.
In order to prevent mis–operation during switching transients, the
81 #2 DELAY time delay should be set to greater than five (5) cycles.
________ Cycles

81 #3 PICKUP
________ Hz

81 #3 DELAY
________ Cycles

81 #4 PICKUP
________ Hz

81 #4 DELAY
________ Cycles

2–76
 Application – 2

Over Frequency
Magnitude #1 Trip
61.0
Over Frequency (Hz) 60.8
60.6
81

60.4 Over Frequency

Magnitude #2
60.2 Over Frequency Over Frequency
Time Delay #1 Time Delay #2
60.0 Time (cycles)
Under Frequency Under Frequency
Time Delay #4 Time Delay #3
Under Frequency (Hz)

59.8
Under Frequency
Magnitude #3
59.6
81

59.4
59.2
Under Frequency
59.0
Magnitude #4 Trip

Figure 2-64 Example of Frequency (81) Trip Characteristics

? X

F81
(81) - FREQUENCY

Pickup: 50.00 Hz 67.00 Hz #1

Delay: 3 Cycles 65500 Cycles

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 50.00 Hz 67.00 Hz #2

Delay: 3 Cycles 65500 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 50.00 Hz 67.00 Hz #3

Delay: 3 Cycles 65500 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 50.00 Hz 67.00 Hz #4

Delay: 3 Cycles 65500 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-65 Frequency (81) Setpoint Ranges

2–77
M-3425A Instruction Book

81A Frequency Accumulator for the next band, i.e., Low Band #2 is the upper
Frequency Accumulation feature (81A) provides an limit for Band #3, and so forth. Frequency bands
indication of the amount of off frequency operation must be used in sequential order, 1 to 6. Band #1
accumulated. must be enabled to use Bands #2–#6. If any band is
disabled, all following bands are disabled.
Turbine blades are designed and tuned to operate at
rated frequencies, operating at frequencies different When frequency is within an enabled band limit,
than rated can result in blade resonance and fatigue accumulation time starts (there is an internal ten
damage. In 60 Hz machines, the typical operating cycle delay prior to accumulation), this allows the
frequency range for 18 to 25 inch blades is 58.5 to underfrequency blade resonance to be established
61.5 Hz and for 25 to 44 inch blades is between 59.5 to avoid unnecessary accumulation of time. When
and 60.5 Hz. Accumulated operation, for the life of accumulated duration is greater than set delay,
the machine, of not more than 10 minutes for then the 81A function operated the programmed
frequencies between 56 and 58.5 Hz and not more output contact. The contact can be used to alert the
than 60 minutes for frequencies between 58.5 and operator or trip the machine.
59.5 Hz is acceptable on typical machines.
The accumulator status can be set to preserve the
The 81A function can be configured to track off accumulated information from previous devices.
nominal frequency operation by either set point or This allows the relay to begin accumulating
when the frequency is within a frequency band. information at a pre-defined value. This setpoint is
only available through IPScom® Communications
When using multiple frequency bands, the lower Software.
limit of the previous band becomes the upper limit

81A #1 HIGH BAND PICKUP 81A #4 LOW BAND PICKUP

________ Hz ________ Hz

81A #1 LOW BAND PICKUP 81A #4 DELAY

________ Hz ________ Cycles

81A #1 DELAY
81A #5 LOW BAND PICKUP
________ Cycles
________ Hz

81A #2 LOW BAND PICKUP

81A #5 DELAY
________ Hz
________ Cycles

81A #2 DELAY
81A #6 LOW BAND PICKUP
________ Cycles
________ Hz

81A #3 LOW BAND PICKUP

81A #6 DELAY
________ Hz
________ Cycles

81A #3 DELAY
________ Cycles

2–78
 Application – 2

Example- Band
Fn

81-1 HB

#1 Band

81-1 LB

#2 Band

81-2 LB

#3 Band

81-3 LB

#4 Band

81-4 LB

#5 Band

0 5 10 15
Time (mins)

Figure 2-66 Frequency Accumulator (81A) Example Bands

? X

F81A

(81A) FREQUENCY ACCUMULATOR

High Pickup: #2
50.00 Hz 67.00 Hz #1
Low Pickup: 50.00 Hz 67.00 Hz
Low Pickup: 50.00 Hz 67.00 Hz Delay: 3 Cycles 360000 Cycles
Delay: 3 Cycles 360000 Cycles Reset Reset
Acc. Status: 0 Cycle 360000 Cycles
Acc. Status: 0 Cycle 360000 Cycles
OUTPUTS @ Blocking Inputs Expanded I/O’s OUTPUTS @ Blocking Inputs Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Low Pickup: 50.00 Hz 67.00 Hz #3 Low Pickup: 50.00 Hz #4

67.00 Hz
Delay: 3 Cycles 360000 Cycles Delay: 3 Cycles 360000 Cycles
Reset Reset
Acc. Status: 0 Cycle 360000 Cycles Acc. Status: 0 Cycle 360000 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s OUTPUTS Blocking Inputs

@ Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Low Pickup: 50.00 Hz #5

67.00 Hz Low Pickup: 50.00 Hz 67.00 Hz #6

Delay: 3 Cycles 360000 Cycles Delay: 3 Cycles 360000 Cycles

Reset Reset
Acc. Status: 0 Cycle 360000 Cycles Acc. Status: 0 Cycle 360000 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s OUTPUTS Blocking Inputs

@ Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-67 Frequency Accumulator (81A) Setpoint Ranges

2–79
M-3425A Instruction Book

81R Rate of Change of Frequency

The Rate of Change of Frequency function (81R) The function also has an automatic disable feature
can be used for load shedding or tripping which disables 81R function during unbalanced
applications. faults and other system disturbances. This feature
uses negative sequence voltage to block the 81R
function. When the measured negative sequence
voltage exceeds the inhibit setting, the function
81R and metering are blocked. The time delay and
magnitude settings of 81R should be based on
81R #1 PICKUP simulation studies. The ranges and increments are
________ Hz/s presented in Figure 2-68.

81R #1 DELAY
________ Cycles

81R #2 PICKUP
________ Hz/s

81R #2 DELAY
________ Cycles

81R NEG SEQ VOLT INHIBIT

________ %

? X

F81R

(81R) - RATE OF CHANGE OF FREQUENCY

Pickup: 0.10 Hz/S 20.0 Hz/S #1

Delay: 3 Cycles 8160 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Pickup: 0.10 Hz/S 20.0 Hz/S #2

Delay: 3 Cycles 8160 Cycles

OUTPUTS @ Blocking Inputs Expanded I/O’s

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

Neg Seq.
Volt Inhibit: 0% 99%

@ : WARNING, You have selected an output!

Save Cancel

Figure 2-68 Rate of Change of Frequency (81R) Setpoint Ranges

2–80
 Application – 2

87 Phase Differential
The Phase Differential function (87) is a percentage For very high currents in large generators, the
differential with an adjustable slope of 1–100%. proximity of CTs and leads in different phases can
Although this protection is used to protect the cause unbalanced currents to flow in the
machine from all internal winding faults, single- secondaries. These currents must be less than the
phase to ground faults in machines with high minimum sensitivity of the relay.
impedance grounding may have currents less than
the sensitivity of the differential relay (typically There are two elements in this function. Element #2
between 3 and 30 primary amps). Ranges and is intended to provide phase differential protection
increments are presented in Figure 2-70. for SFC (Static Frequency Converter) starting gas
turbine generator applications. Element #1 should
Turn-to-turn faults are not detected by differential be disabled with a contact blocking input during a
relays because the current into the generator equals converter start operation (generator off-line), since
the current out (see functions 50DT and 59X for the current is carried by only neutral side CTs and
turn-to-turn fault protection.) Even though the the resulting differential current may mis-operate
percentage differential relay is more tolerant of CT 87#1 function. The 87#2 element, which is set with
errors, all CTs should have the same characteristics a higher current pickup, will still provide protection
and accuracies. for this condition.
To provide restraint for CT saturation at high offset
currents, the slope is automatically adjusted (at a
restraining current equal to two times nominal
current) to four times the slope setting, see Figure
2-69.

87 #1 PICKUP A typical setting is 0.3 amps.

________ Amps

87 #1 SLOPE A typical setting is 10%.

________ %

A typical setting is one cycle. Typical settings given above assume

87 #1 DELAY
matched current transformer performance, and that transformer in-
________ Cycles rush of the unit transformer does not cause dc saturation of the gen-
erator CTs. If there is a significant difference in current transformer
ratings (C800 vs C200, for example), or if saturation of the generator
87 #2 PICKUP CTs is expected during energizing of the step up transformer, more
________ Amps appropriate settings might be 0.5 A pick up, 20% slope, and a delay of
5 to 8 cycles.
87 #2 SLOPE
________ %

87 #2 DELAY
________ Cycles

If line side and neutral side CTs do not have the same ratio, the ratio
87 PHASE CT CORRECTION error can be corrected (the line side measured current is multiplied by
________ the phase CT correction settings.)

Line Side CTR

Phase CT Correction =
Neutral Side CTR

2–81
M-3425A Instruction Book

SLOPE
TRIP (4xset)
((IA x CTC)-Ia),
((IB x CTC)-Ib),
((IC x CTC)-Ic) BLOCK

SLOPE
(set)
MIN PU @ IRES=2xINOM
Restraint Current
((IA x CTC)+Ia)/2, ((IB x CTC)+Ib)/2, ((IC x CTC)+Ic)/2
Where IA and Ia are generator high side and neutral side currents respectively, and CTC is the
CT Phase correction.
Figure 2-69 Differential Relay (87) Operating Characteristics

? X
F87

(87) - PHASE DIFFERENTIAL CURRENT

Pickup: 0.20 A 3.00 A #1

Delay: 1 Cycle 8160 Cycles

Percent Slope: 1% 100%

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

#2

Pickup: 0.20 A 3.00 A

Delay: 1 Cycle 8160 Cycles

Percent Slope: 1% 100%

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

Phase CT Correction: 0.50 2.00

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-70 Phase Differential (87) Setpoint Ranges

2–82
 Application – 2

87GD Ground (Zero Sequence) Differential The advantage of directional supervision is the
The Zero Sequence Differential function (87GD) security against ratio errors and CT saturation during
provides ground fault protection for low impedance faults external to the protected generator.
grounded generator applications. High sensitivity
The directional element is inoperative if the residual
and fast operation can be obtained using this
current (3I0 ) is approximately less than 0.2 A, in
function. Ranges and increments are presented in
which case the algorithm automatically disables the
Figure 2-71.
directional element and the 87GD function becomes
The relay provides a CT Ratio Correction Factor non-directional differential. The pickup quantity is
(RC) which removes the need for auxiliary CTs when then calculated as the difference between the
the phase and neutral CT ratios are different. corrected triple zero-sequence current (RC3I0) and
the neutral current (IN). The magnitude of the
When the system can supply zero sequence current difference (RC3I0–IN) is compared to the relay pickup.
to the ground fault (such as when several generators
are bussed together), the 87GD function operates For security purposes during external high phase-
directionally. The directional element calculates the fault currents causing CT saturation, this function is
product (–3I0INCosØ) for directional indication. The disabled any time the value of IN is less than
relay will operate only if I0 (Zero sequence current approximately 0.20 amps.
derived from phase CTs) and IN (Neutral current
from Neutral CT) have the opposite polarity, which ■ NOTE: When 87GD is enabled, 67N function is
is the case for internal generator faults. not available.

A typical setting is 0.2 amps. (Relay amps = primary amps

87GD PICKUP ÷ CT ratio.) For higher values of RC, noise may create
________ Amps substantial differential current making higher pickup settings
desirable.

87GD DELAY In order to prevent mis-operation during external faults with

________ Cycles CT saturation conditions, a time delay of 6 cycles or higher
is recommended.

87GD C.T. RATIO CORRECT CT Ratio Correction Factor = (Phase CT Ratio)/(Neutral CT

________ Ratio)

? X
F87GD

(87GD) - GROUND DIFFERENTIAL

0.20 A 10.00 A #1
Pickup:
Delay: 1 Cycle 8160 Cycles
CT Ratio Corr: 0.10 7.99

OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-71 Ground Differential (87GD) Setpoint Ranges

2–83
M-3425A Instruction Book

Breaker Monitoring
The Breaker Monitoring feature calculates an estimate the relay can operate a programmable output contact.
of the per-phase wear on the breaker contacts by The accumulated value for each phase can be
measuring and integrating the current (IT) or current displayed as an actual value. The accumulation starts
squared (I2T) passing through the breaker contacts after a set time delay from the trip initiate command to
during the interruption period. The per-phase values account for the time it takes for the breaker to start
are added to an accumulated total for each phase, opening its contacts. The accumulation continues
and then compared to a user-programmed threshold until the current drops below 10% of the nominal
value. When the threshold is exceeded in any phase, current setting or 10 cycles, whichever occurs first.

BM PICKUP ■ NOTE: Preset Accumulator Setpoints are only

__________ kA-cycles available through IPScom®.

BM INPUT INITIATE Expanded Inputs IN7–IN14 (if equipped) must be set us-
i6 i5 i4 i3 i2 i1 ing IPScom.

BM OUTPUT INITIATE Expanded Outputs OUT9–OUT23 (if equipped) must be

08 07 06 05 04 03 02 01 set using IPScom.

BM DELAY
________ Cycles

BM TIMING METHOD
it i2t

? X

FBM

(BM) - BREAKER MONITOR

#1
Pickup: 0 KA 50000 KA

Delay: 0.1 Cycle 4095.9 Cycles

Timing Method Select: IT I^2T

Preset Accumulators
Phase A: 0 KA Cycles 50000 KA Cycles

Phase B: 0 KA Cycles 50000 KA Cycles

Phase C: 0 KA Cycles 50000 KA Cycles

Output Initiate Input Initiate

8 7 6 5 4 3 2 1 6 5 4 3 2 1 Expanded I/O Initiate

OUTPUTS Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-72 Breaker Monitor (BM) Setpoint Ranges

2–84
 Application – 2

Trip Circuit Monitoring no current flows and the Trip Circuit Monitoring
External connections for the Trip Circuit Monitoring Input is deactivated. An Output Contact that is
function are shown in Figure 2-73. The default Trip welded closed would also cause the Trip Circuit
Circuit Monitor input voltage is 250 V dc. See Monitoring Input to deactivate, indicating failure of
Section 5.5, Circuit Board Switches and Jumpers, the Output Contact.
Table 5-3 for other available trip circuit input voltage
When the Output Contact is closed, no current
selections. flows in the Trip Circuit Monitoring Input. If the
This function should be programmed to block when M-3425A has issued a trip command to close the
the breaker is open, as indicated by 52b contact Output Contact and Trip Circuit Monitoring Input
input (IN1). If the TCM is monitoring a lockout remains activated, this is an indication that the
relay, a 86 contact input (INx) should be used to Output Contact failed to close.
block when the lockout relay is tripped. The output of the Trip Circuit Monitoring function
When the Output Contact is open, and continuity can be programmed as an alarm to alert
exists in the Trip Circuit, a small current flows that maintenance personnel.
activates the Trip Circuit Monitoring Input. If the
Trip Circuit is open, and the output contact is open,

TCM DELAY
________ Cycles

M-3425A

52b or 86

Station
2 Battery
Trip Circuit
+
Monitoring Input 1 Aux Input

Output Other
Contact Contacts

52a

52 or 86
Trip Coil

-
Figure 2-73 Trip Circuit Monitoring Input

2–85
M-3425A Instruction Book

? X

FTC

(TC) - TRIP CIRCUIT MONITOR

TC
Delay: 1 Cycle 8160 Cycles

OUTPUTS @ Blocking Inputs

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1 Expanded I/O’s

@ : WARNING, You have not selected an output!

Save Cancel

Figure 2-74 Trip Circuit Monitor (TC) Setpoint Ranges

2–86
 Application – 2

IPSlogic™
The relay provides six logic functions and associated Programming the IPSlogic can only be implemented
IPSlogic. The logic functions can be used to allow through IPScom® Communications Software. The
external devices to trip through the relay, providing IPSlogic cannot be programmed using the Human-
additional target information for the external device. Machine Interface (HMI).
More importantly, these functions can be used in
conjunction with IPSlogic to expand the capability
of the relay by allowing the user to define customized
operating logic.

IPS LOGIC
USE IPSCOM TO CONFIGURE

2–87
2–88
Initiating Outputs
This section of the IPSlogic
used to activate the desired Output
Programmable This section of the IPSlogic
Outputs 1-8 initiates the Function Output
* Outputs 9-23

Selectable And/Or Programmed

Prolile Setting
Group 1-4
M-3425A Instruction Book

Initiating Function Trip

includes external elements
Programmable function(s)
Timed Out

Picked Up Programmed
Programmed
Outputs 1-8
Time Delay
*Outputs 9-23
Selectable And/Or/Nor/Nand

Selectable And/Or
1-65,500 cycles
Initiating Inputs (1091sec)

Programmable
Inputs 1-6 Log Target
* 7 -14

Selectable And/Or

Initiate Via
Communication
Point IPSlogic
Activated

Blocking Inputs
This section of the IPSlogic used
to Block the Function Output
Programmable
Inputs 1-6 Log Pickup
* 7 -14

Selectable And/Or
Block Via
Communication
Point

* For units with Expanded I/O

Figure 2-75 IPSlogic™ Function Setup

 Application – 2

Settings and Logic Applicable when The IPSlogic Function can be programmed to
IPSlogic™ Function(s) programmed using perform any or all of the following tasks:
IPScom®
• Change the Active Setting Profile
There are four initiating input sources: Initiating
Outputs, Initiating Function Trips, Function Pickup • Close an Output Contact
(including the IPSlogic Functions themselves), • Be activated for use as an input to another
Initiating Inputs, and initiation using the External Function
Communication Port. The only limitation is that an
IPSlogic Function may not be used to initiate itself. Since there are six IPSlogic Functions per setting
There are two blocking input sources: Blocking profile, depending on the number of different relay
Inputs and blocking using the Communication Port. settings defined, the scheme may provide up to 24
The activation state of the input function selected different logic schemes. The IPScom IPSlogic
in the Initiating Function can be either timeout Function programming screen is shown in Figure
(Trip) or pickup. The desired time delay for security 2-76.
considerations can be obtained in the IPSlogic
Function time delay setting.

(IPS) IPSLogic ? X

#1 #2 #3 #4 #5 #6
Initiating Outputs
8 7 6 5 4 3 2 1
1 #1
OR
Expanded Initiating Outputs OR
Initiating Function Timeout 2
OR
Initiating Function Pickup
Initiate via Communication Point OR

Initiating Inputs OR AND

OR
1
6 5 4 3 2 1
Expanded Initiating Inputs
Blocking Inputs
OR
1
FL 6 5 4 3 2 1
Expanded Blocking Inputs
NOR
Block via Communication Point

Profile
Delay: 1 Cycle 8160 Cycles NA #1 #2 #3 #4

IPS #1
DO/RST Delay: 0 Cycle 65500 Cycles Activated
Dropout (DO) Timer Reset (RST) Timer

OUTPUTS @
@ : WARNING, You have not selected an output! Expanded Outputs 8 7 6 5 4 3 2 1

Save Cancel

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

2–89
M-3425A Instruction Book

Initiating Function Timeout X

o F21 #1 o F27TN #1 o F40 #1 o F50BF o F51V o F59X_1

o F21 #2 o F27TN #2 o F40 #2 o F50 #1 o F59 #1 o F59X_2
o F21 #3 o F27 #1 o F40VC1 o F50 #2 o F59 #2 o F60FL
o F24DT #1 o F27 #2 o F40VC2 o F50N o F59 #3 o F64F #1
o F24DT #2 o F27 #3 o F46DT o F50DT #1 o F59D o F64F #2
o F24IT o F32 #1 o F46IT o F50DT #2 o F59N #1 o F64B
o F25S o F32 #2 o F49 #1 o F5027 o F59N #2 o F64S
o F25D o F32 #3 o F49 #2 o F51N o F59N #3 OK

o F67NDT o F81A #1 o F87 #1 o FBM Cancel

o F67NIT o F81A #2 o F87 #2 o FTC
o F78 o F81A #3 o F87GD
o F81 #1 o F81A #4 o IPSL #1
o F81 #2 o F81A #5 o IPSL #2
o F81 #3 o F81A #6 o IPSL #3
o F81 #4 o F81R #1 o IPSL #4
o F81R #2 o IPSL #5
o IPSL #6

Figure 2-77 Selection Screen for Initiating Function Timeout

Initiating Function Pickup X

o F21 #1 o F27TN #1 o F40 #1 o F50BF o F51V o F59X_1

o F21 #2 o F27TN #2 o F40 #2 o F50 #1 o F59 #1 o F59X_2
o F21 #3 o F27 #1 o F40VC1 o F50 #2 o F59 #2 o F60FL
o F24DT #1 o F27 #2 o F40VC2 o F50N o F59 #3 o F64F #1
o F24DT #2 o F27 #3 o F46DT o F50DT #1 o F59D o F64F #2
o F24IT o F32 #1 o F46IT o F50DT #2 o F59N #1 o F64B
o F25S o F32 #2 o F49 #1 o F5027 o F59N #2 o F64S
o F25D o F32 #3 o F49 #2 o F51N o F59N #3 OK

o F67NDT o F81A #1 o F87 #1 o FBM Cancel

o F67NIT o F81A #2 o F87 #2 o FTC
o F78 o F81A #3 o F87GD
o F81 #1 o F81A #4 o IPSL #1
o F81 #2 o F81A #5 o IPSL #2
o F81 #3 o F81A #6 o IPSL #3
o F81 #4 o F81R #1 o IPSL #4
o F81R #2 o IPSL #5
o IPSL #6

Figure 2-78 Selection Screen for Initiating Function Pickup

2–90
 Application – 2

DO/RST (Dropout/Reset) Timer Feature

The DO/RST timer can be set as either Dropout or Reset mode. The operation of the Dropout Delay Timer
and the Reset Delay Timer are described below.
Dropout Delay Timer
The Dropout Delay Timer logic is presented in Figure 2-79. The Dropout Delay Timer feature allows the user
to affect an output time delay that starts when the IPSlogic PU Status drops out (A) and can hold the Output
(D) status true beyound the Output Seal 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 than the Seal In Delay time (E).

Dropout Delay Timer

25 35
Cycles

IPSlogic Functions (1 - 6)
PU Status

PU Time Delay
Setting (30) Seal in Delay

Seal in Delay E
PU Time Delay Timing Dropout Delay

B
Output
A C D

Figure 2-79 Dropout Delay Timer Logic Diagram

Reset Delay Timer

The Reset Delay Timer logic is presented in Figure 2-80. The Reset Delay Timer feature allows the user to
delay the reset of the PU Time Delay Timer and hold the accumulated timer value (A) for the duration of the
Reset Time Delay time period (B). The Reset Delay Timer starts when the IPSlogic PU Status drops out (C).
If the IPSlogic PU Status remains dropped out (D) after the reset delay has timed out, then the IPSlogic PU
timer value will be reset to zero (E).
If the IPSlogic PU Status reasserts (F) while the Reset Delay Timer is still timing, then the PU Timer Delay
begins timing from the accumulated value (G).

Reset Delay Timer

25 12 25 8 5 10
Cycles

IPSlogic Functions (1 - 6) D
C F
PU Status
Reset Delay
10 Cycles B Reset
Delay
Reset
Delay
PU Time Delay
Setting (30)
A G
Seal In
PU Time Delay Timing Timer

E
Output

Figure 2-80 Reset Delay Timer Logic Diagram

2–91
M-3425A Instruction Book

This Page Left Intentionally Blank

2–92
 Operation – 3

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

This chapter contains information that describes Arrow Pushbuttons

the operation of the M-3931 Human Machine Interface The left and right arrow pushbuttons are used to
Module (HMI) and the M-3925A Target module. It choose among the displayed menu selections. When
further describes the direct setting and configuration entering values, the left and right arrow pushbuttons
procedures for entering all required data to the relay. are used to select the digit (by moving the cursor) of
Included in this chapter is a description of the the displayed setpoint that will be increased or
process necessary for review of setpoints and timing, decreased by the use of the up and down
monitoring function status and metering quantities, pushbuttons.
viewing the target history, and setup of the
oscillograph recorder. The up and down arrow pushbuttons increase or
decrease input values or change between upper
and lower case inputs. If the up or down pushbutton
3.1 Front Panel Controls is pressed when adjusting numerical values, the
speed of increment or decrement is increased.
The relay has been designed to be set and
interrogated locally with the optional HMI panel. An EXIT Pushbutton
integral part of this design is the layout and function The EXIT pushbutton is used to exit from a displayed
of the front panel indicators and controls, illustrated screen and move up the menu tree. Any changed
in Figure 3-1. setpoint in the displayed screen will not be saved if
the selection is aborted using the EXIT pushbutton.
Alphanumeric Display
To assist the operator in setting and interrogating ENTER Pushbutton
the relay locally, the HMI displays menus which The ENTER pushbutton is used to choose a
guide the operator to the desired function or setpoint highlighted menu selection, to replace a setpoint or
value. These menus consist of two lines. The bottom other programmable value with the currently displayed
line lists lower case abbreviations of each menu value, or to move down within the menu tree.
selection with the chosen menu selection shown in
uppercase. The top menu line provides a description
Target & Status Indicators and Controls
of the chosen menu selection.
The target/status indicators and controls consist of
Screen Blanking the POWER SUPPLY (2) LEDs, RELAY OK LED,
The display will automatically blank after exiting the OSCILLOGRAPH TRIG LED, BREAKER
from the Main Menu, or from any screen after five CLOSED LED, TARGET LED, DIAGNOSTIC LED
(5) minutes of unattended operation. To wake up the and TIME SYNC LED.
display, the user must press any key except EXIT.

3–1
M-3425A Instruction Book

Power Supply #1 (#2) LED Diagnostic LED

The green PS LED indicator will remain illuminated The diagnostic DIAG LED will flash when a self-test
for the appropriate power supply whenever power is error is detected. The LED will flash the Error Code
applied to the unit and the power supply is operating number; for example, for Error Code 32, the LED
correctly. A second power supply is available as an will flash 3 times, followed by a short pause, and
option, for units without expanded I/O. then flash 2 times, followed by a long pause, then
repeat LED flash sequence. For units equipped with
Relay OK LED the HMI, the Error Code number is also displayed
on the screen.
The green RELAY OK LED is controlled by the
relay's microprocessor. A flashing RELAY OK LED
indicates proper program cycling. The LED can also Accessing Screens
be programmed to be continuously illuminated. To prevent unauthorized access to relay functions,
the unit includes a provision for assigning access
Oscillograph Triggered LED codes. If access codes have been assigned, the
access code entry screen will be displayed after
The red OSC TRIG LED will illuminate to indicate ENTER is pressed from the default message screen.
that oscillographic data has been recorded in the
unit’s memory and is available for download.
Default Message Screens
Breaker Closed LED When power is applied to the unit, the relay performs
a number of self-tests to ensure that it is operating
The red BRKR CLOSED LED will illuminate to correctly. During the self-tests, the screen displays
indicate when the breaker status input IN1 (52b) is an “X” for each test successfully executed.
open.
If all self-tests are executed successfully, the relay
Target Indicators and Target Reset will briefly display the word PASS and then a series
of status screens that include:
When a condition exists that causes the operation
of outputs 1 through 8 (1 through 23 for units with • Model Number
expanded I/O), the TARGET LED will illuminate,
• Software Version Number
indicating a relay operation. The TARGET LED will
remain illuminated until the condition causing the • Serial Number
trip is cleared, and the operator presses the TARGET • Date and time as set in the system clock
RESET pushbutton. For units equipped with the
optional M-3925A Target Module, additional targeting • User Logo Screen
information is available. The Target module includes
an additional 24 target LEDs, and 8 output status If a test fails, an error code will be displayed and the
LEDs. LEDs corresponding to the particular operated relay will not allow operation to proceed. In such a
function as well as the present state of the outputs case, the error code should be noted and the factory
are available. Pressing and holding the TARGET contacted. A list of error codes and their descriptions
RESET pushbutton will display the present pickup are provided in Appendix C, Error Codes.
status of all functions available on the target module.
This is a valuable diagnostic tool which may be When the relay has power applied and is unattended,
used during commissioning and testing. the user logo lines are blanked.
If a function has operated and the targets have not
Time Sync LED been reset, the screen will display the time and date
The green TIME SYNC LED will illuminate to indicate of the operation and automatically cycle through
that the IRIG-B time signal is received and the screens for each applicable target (see Figure 3-2).
internal clock is synchronized with the IRIG-B time Pressing the ENTER pushbutton will enter local
signal. IRIG-B time information is used to accurately mode operation, displaying the access code entry
tag target and oscillograph events. screen or, if access codes have been disabled, the
first level menu.
Figure 3-3 presents the software menu flow map for
HMI-equipped units. This map can be used as a
quick reference guide to aid in navigating the relay's
menus.

3–2
 Operation – 3

Figure 3-1 M-3425A Front Panel

Self-Tests

POWER ON SELFTESTS
XXXXXXXX TARGET
BECKWITH ELECTRIC CO.
01-Jan-2003 01:05:20.000
53rd St. Substation

LED Test TARGET

03 01
Default Message Screens
POWER ON SELFTESTS
PASS TARGET
27 #1 Phase Undervoltage
Model Number

Beckwith Electric Co.

M-3425A
Trip Target Screens

Software Version

Beckwith Electric Co.

D - 0150V01.02.03 1269

Serial Number
ENTER ACCESS CODE ACCESS DENIED!
5-minute
Beckwith Electric Co. 0
access
SERIAL NUMBER 137 lockout

System Date and Time LEVEL 1 ACCESS GRANTED!

Beckwith Electric Co.

01-Jan-2003 15:24:32
Access Screens (optional)
User Logo

Beckwith Electric Co.

53rd St. Substation

Power-On Self-Test VOLTAGE RELAY

and Status Screens VOLT curr freq v/hz Þ pwr lof fuse...

Power-On
27 PHASE UNDERVOLTAGE
PHASE_UNDER ÞÞ nutrl_under phase_over...

27 #1 PICKUP
108 Volts
Main Menu Flow
Local Mode

Figure 3-2 Screen Message Menu Flow

3–3
M-3425A Instruction Book

VOLTAGE RELAY SYNC CHECK RELAY STATUS

VOLT curr freq v/hz field stator SYNC config sys STAT
• 27 Phase Undervoltage • 25S Sync Check • Voltage Status
• 59 Phase Overvoltage • 25D Dead Volt • Current Status
• 27TN Neutrl Undervolt • Frequency Status
• 59X Overvoltage BREAKER MONITOR • V/Hz Status
• 59N Neutral Overvoltage BRKR trpckt ipslog • Power Status
• 59D Volt. Diff. 3rd Har. • Impedance Status
• Set Breaker Monitoring • Sync Check Status
CURRENT RELAY • Preset Accumulators • Breaker Mon Acc Status
volt CURR freq v/Hz • Clear Accumulators • 81A Accumulators Status
• In/Out Status
• 46 Neg Seq Overcurrent TRIP CIRCUIT MONITOR • Timer Status
• 50 Inst Overcurrent brkr TRPCKT ipslog • Relay Temperature
• 50/27 Inadvertent Energing • Counters
• 50BF Breaker Failure • Trip Circuit Monitor • Time of Last Power Up
• 50DT Def. Time Overcurr • Error Codes
• 50N Inst Overcurrent
IPS LOGIC • Checksums
• 51N Inv Time Overcurrent
brkr trpckt IPSLOG
• 49 Stator Overload VIEW TARGET HISTORY
• 51V Inv Time Overcurrent • IPS Logic TARGETS osc_rec comm
• 87 Differential Overcurr
• 87GD Gnd Diff Overcurr CONFIGURE RELAY • View Target History
• 67N Res Dir Overcurr CONFIG sys stat • Clear Target History

FREQUENCY RELAY • Voltage Relay OSCILLOGRAPH RECORDER

volt curr FREQ v/hz • Current Relay targets OSC_REC comm
• Frequency Relay
• 81 Frequency • View Record Status
• Volts per Hertz Relay
• 81R Rate of Change Freq • Clear Records
• Power Relay
• 81A Frequency Accum. • Recorder Setup
• Loss of Field Relay
• V.T. Fuse Loss Relay
VOLTS PER HERTZ RELAY COMMUNICATION
• Phase Distance Relay
volt curr freq V/HZ • Field Gnd Relay targets osc_rec COMM
• Stator Gnd Relay
• 24 Def Time Volts/Hertz • COM1 Setup
• Sync Check Relay
• 24 Inv Time Volts/Hertz • COM2 Setup
• Breaker Mon Relay
• COM3 Setup
• Trip Ckt Mon Relay
POWER RELAY • Communication Address
• IPSLogic Relay
PWR lof fuse dist • Response Time Delay
SETUP SYSTEM • Comm Access Code
• 32 Directional Power • Ethernet Setup
config SYS stat
• Ethernet IP Address
LOSS OF FIELD RELAY • Input Activated Profiles
pwr LOF fuse dist • Active Setpoint Profile SETUP UNIT
• 40 Loss of Field
• Copy Active Profile SETUP exit
• Nominal Voltage
• Nominal Current • Software Version
V. T. FUSE LOSS RELAY • V. T. Configuration • Serial Number
pwr los FUSE dist • Delta-Y Transform • Alter Access Codes
• Phase Rotation • User Control Number
• 60FL V. T. Fuse Loss
• 59/27 Magnitude Select • User Logo Line 1
• 50DT Split-phase Diff. • User Logo Line 2
PHASE DISTANCE RELAY • Clear Output Counters
• Pulse Relay
pwr lof fuse DIST • Latched Outputs • Clear Alarm Counter
• 21 Phase Distance • Relay Seal-in Time • Date & Time
• Active Input State • Clear Error Codes
• 78 Out of Step
• V.T. Phase Ratio • Ethernet Firmware Ver.
• Diagnostic Mode
FIELD GROUND RELAY • V.T. Neutral Ratio
• V.T. VX Ratio
FIELD stator sync • C.T. Phase Ratio EXIT LOCAL MODE
• 64B/F Field Ground • C.T. Neutral Ratio setup EXIT

STATOR GROUND RELAY

field STATOR sync ■ NOTE: Depending on which functions are purchased, some
menus may not appear.
• 64S Stator Ground
Figure 3-3 Main Menu Flow
3–4
 Operation – 3

3.2 Initial Setup Procedure/ 3.3 Setup Unit Data

Settings
■ NOTE: Please see Figure 3-3, Main Menu Flow,
The M-3425A Generator Protection Relay is shipped for a list of submenus associated with
from the factory with all functions disabled (user will the SETUP UNIT menu.
only be able to enable purchased functions).
To access the SETUP UNIT menu proceed as
The Setup Procedure provided below is a suggested follows:
setup procedure for initially entering settings into
1. Press the ENTER pushbutton to display
the relay. While it is written for HMI-equipped units, the main menu.
the same procedure is applicable when setting the
relay through remote communication utilizing 2. Press the right arrow pushbutton until
M-3820D IPScom® Communications Software. SETUP UNIT is displayed on the top
line of the screen.
Following the Setup Procedure are several sections
which provide additional detail concerning the 3. Press the ENTER pushbutton to access
the SETUP UNIT menu.
settings required for proper commissioning.

Setup Procedure SETUP UNIT

■ NOTE: Configuration Record forms are available SETUP exit
in Appendix A, Configuration Record
Forms, to record settings for future 4. Press the ENTER pushbutton to move
reference. down within the SETUP UNIT menu to
the desired category. To exit a specific
1. Enter the Setup Unit data. This is general category and continue to the next menu
information required including altering category, press the EXIT pushbutton.
access codes, setting date and time,
defining user logos, and other
adjustments. See Section 3.3, Setup Setup Unit Data Entry
Unit Data. The general information required to complete the
2. Configure the Setup System data. This entry of Setup Unit Data includes:
is the general system and equipment Access Codes: The relay includes three levels of
information required for operation, access codes. Depending on their assigned code,
including such items as CT and VT ratios, users have varying levels of access to the installed
VT configuration, and Nominal values.
functions.
See Section 3.4, Setup System Data
subsection. 1. Level 1 Access = Read setpoints,
3. Enable the desired functions and monitor status, view target history.
elements. See Section 3.4, Configure 2. Level 2 Access = All of level 1
Relay Data subsection. privileges, plus read & change
4. Enter the desired setpoints for the setpoints, target history, set time
enabled functions. See Section 3.4, clock.
Setpoints and Time Settings subsection. 3. Level 3 Access = All of level 2
5. Enter configuration information for the privileges, plus access to all
oscillograph recorder. See Section 3.4, configuration functions and settings.
Oscillograph Recorder Data subsection.
Each access code is a user-defined one- to four-
6. If remote communication is used, set digit number. Access codes can only be altered by
the parameters as needed. See Section a level 3 user.
3.4, Communications Settings
subsection, or in Chapter 4, Remote If the level 3 access code is set to 9999, the
Operation. access code feature is disabled. When access
codes are disabled, the access screens are
bypassed, and all users have full access to all the
relay menus. The relay is shipped from the factory
with the access code feature disabled.

3–5
M-3425A Instruction Book

User Control Number: This is a user-defined value

which can be used for inventory or identification. 3.4 Setup System Data
The relay does not use this value, but it can be
accessed through the HMI or the communications ■ NOTE: Please see Figure 3-3, Main Menu Flow,
interface, and can be read remotely. for a list of submenus associated with
the SETUP SYSTEM menu.
User Logo: The user logo is a programmable, two-
line by 24-character string, which can be used to To access the SETUP SYSTEM menu proceed as
identify the relay, and which is displayed locally follows:
when the relay is idle. This information is also
available remotely. 1. Press the ENTER pushbutton to display
the main menu.
Date and Time: This screen is used to view and set 2. Press the right arrow pushbutton until
the relay's internal clock. The clock is used to time SETUP SYSTEM is displayed on the
stamp system events such as trip and oscillograph top line of the screen.
operations.
3. Press the ENTER pushbutton to access
The clock is disabled when shipped from the factory the SETUP SYSTEM menu.
(indicated by “80” seconds appearing on the clock)
to preserve battery life. If the relay is to be SETUP SYSTEM
unpowered for an extended length of time, the clock config SYS stat
should be stopped (see Diagnostic Mode). If the
IRIG-B interface is used, the hours, minutes, and
seconds information in the clock will be To input the data, access the menu as follows:
synchronized with IRIG-B time information every 1. Press the ENTER pushbutton to display
hour. the main menu.

The relay can accept a modulated IRIG-B signal 2. Press the right arrow pushbutton until
using the rear panel BNC connector, or a SETUP SYSTEM is displayed on the
demodulated TTL level signal using extra pins on top line of the screen.
the rear panel COM2 RS-232 interface connector 3. Press the ENTER pushbutton to access
(see Figure B-4 for COM2 pinout.) If the TTL signal the SETUP SYSTEM menu and begin
is to be used, then Jumper 5 will be required to be the data input.
positioned (see Section 5.5, Circuit Board Switches
System setup data is required for proper operation
and Jumpers).
of the relay. Information needed to complete this
section includes: Nominal Voltage, Nominal Current,
Setup Unit Features That Do Not Require Data VT Configuration, and other system-related
Entry information. See Section 2.1, Configuration, Relay
The Setup Unit menu categories that provide the System Setup subsection for a more detailed
user with read only information are Software description of the settings required.
Version, Serial Number and Ethernet Firmware
Ver..
The Setup Unit menu also contains features that
provide the user with the ability to Clear Output
Counters, Clear Alarm Counter, Clear Error
Codes and access the Diagnostic Mode. The error
codes are described in Appendix C, Self Test Error
Codes. Note that while the relay is in Diagnostic
Mode, all protective functions are inoperative.

3–6
 Operation – 3

Configure Relay Data Setpoints and Time Settings

■ NOTE: Please see Figure 3-3, Main Menu Flow, ■ NOTE: Please see Figure 3-3, Main Menu Flow,
for a list of submenus associated with for a list of submenus and specific
the CONFIGURE RELAY menu. elements associated with the Setpoints
and Time Setting menus.
To input the data, access the CONFIGURE RELAY
menu as follows: To input the data, access these menus as follows:
1. Press the ENTER pushbutton to display 1. Press the ENTER pushbutton to display
the main menu. the main menu.
2. Press the right arrow pushbutton until 2. Press the right arrow pushbutton until
CONFIGURE RELAY is displayed on VOLTAGE RELAY, the first of the
the top line of the screen. setpoint and time setting menus, is
displayed on the top line of the screen.
3. Press ENTER to access the
CONFIGURE RELAY menu and begin ■ NOTE: Some menus are dynamic, and do not
the data input. appear if the function is not purchased
or is unavailable.
CONFIGURE RELAY
CONFIG sys stat 3. Press ENTER to begin the data input for
this menu, or continue pressing the right
The general information required to complete the arrow pushbutton until the desired
input data in this section includes: setpoint and time setting menu is
displayed, then press ENTER to begin
• enable/disable the data input.
• output choices (OUT1–OUT8; for units
with expanded I/O, OUT9–OUT23 may The general information required to complete the
only be set through IPScom®) input data in this section includes individual relay
function:
• input blocking choices (IN1–IN6; for units
with expanded I/O, IN7–IN14 may only be • pickup settings (converted to relay
set through IPScom), plus fuse loss quantities)
blocking • time delay settings
Each of the purchased functions within the relay • frequency settings
may be individually enabled or disabled. In addition, • time dials
many functions have more than one element which
may also be enabled or disabled. Unused functions • power level settings (in percent rated)
and elements should be disabled to avoid nuisance • impedance diameter in relay ohms for
tripping and speed up HMI response time. distance and offset settings

After enabling a function/element, the user is Settings should be programmed based on system
presented with two additional screens for selection analysis as described in Chapter 2, Application. A
of input blocking and output contact designations. complete description of the individual function as
Any combination of the control/status inputs or the well as guidelines for settings are explained therein.
internally generated VT fuse loss logic can be
selected 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 expanded
I/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). Output
contacts 1–4 contain special circuitry for high-speed
operation and pick up approximately 4 ms faster
than other contacts.
See Section 2.1, Configuration, for more information.

3–7
M-3425A Instruction Book

Oscillograph Recorder Data • Post-Trigger Delay: A post-trigger delay

■ NOTE: Please see Figure 3-3, Main Menu Flow, of 5% to 95% must be specified. After
for a list of submenus associated with triggering, the recorder will continue to
the OSCILLOGRAPH RECORDER store data for the programmed portion of
menu. the total record before re-arming for the
next record. For example, a setting of
To input the data, access the OSCILLOGRAPH 80% will result in a record with 20%
RECORDER menu as follows: pretrigger data, and 80% post-trigger data.
1. Press the ENTER pushbutton to display
the main menu.
Numbe r of Numbe r of Cycle s
2. Press the right arrow pushbutton until
Partitions pe r Each Partition
OSCILLOGRAPH RECORDER is
displayed on the top line of the screen. 1 416 Cycles
3. Press the ENTER pushbutton to access
the OSCILLOGRAPH RECORDER menu 2 280 Cycles
and begin the data input.
3 208 Cycles

OSCILLOGRAPH RECORDER 4 168 Cycles

targets OSC_REC comm
5 136 Cycles

The Oscillograph Recorder provides comprehensive 6 120 Cycles

data recording (voltage, current, and status input/
output signals) for all monitored waveforms (at 16 7 104 Cycles
samples per cycle). Oscillograph data can be
8 88 Cycles
downloaded using the communications ports to any
IBM compatible personal computer running the 9 80 Cycles
M-3820D IPScom® Communications Software. Once
downloaded, the waveform data can be examined 10 72 Cycles
and printed using the optional M-3801D IPSplot®
PLUS Oscillograph Data Analysis Software. 11 64 Cycles
The general information required to complete the 12 64 Cycles
input data of this section includes:
13 56 Cycles
• Recorder Partitions: When untriggered,
the recorder continuously records 14 56 Cycles
waveform data, keeping the data in a
buffer memory. The recorder's memory 15 48 Cycles
may be partitioned into 1 to 16 partitions.
16 48 Cycles
When triggered, the time stamp is
recorded, and the recorder continues Table 3-1 Recorder Partitions
recording for a user-defined period. The
snapshot of the waveform is stored in Communications Settings
memory for later retrieval using IPScom
Communications Software. The OSC TRIG To enter the communications settings, access the
LED on the front panel will indicate a COMMUNICATION menu as follows:
recorder operation (data is available for 1. Press the ENTER pushbutton to access
downloading). the main menu.
• Trigger Inputs and Outputs: The recorder 2. Press the right arrow pushbutton until
can be triggered remotely through serial COMMUNICATION is displayed on the
communications using IPScom, or top line of the screen.
automatically using programmed status
inputs or outputs.

3–8
 Operation – 3

3. Press the ENTER pushbutton to access 3. Press the ENTER pushbutton to access
the COMMUNICATION menu and begin the STATUS menu.
the data entry.
STATUS
COMMUNICATION config sys STAT
targets osc_rec COMM
■ NOTE: Some menus are dynamic, and do not
The general information required to complete the appear if the function is not purchased
communications settings entry of this section or is unavailable.
include:
• Baud rate for COM1 and COM2 4. Press the ENTER pushbutton to move
communication ports. The COM3 port does down within the STATUS menu to the
not have a separate baud rate setting but desired category. To exit a specific
uses the setting of COM2 (or COM1: see category and continue to the next menu
Section 5.5 Circuit Board Switches and category, press the EXIT pushbutton.
Jumpers).
The menu categories for monitored values are:
• Communications address is used to
access multiple relays using a multidrop • Voltage Status: phase voltages, neutral
or network communication line. voltage, positive sequence voltage,
negative sequence voltage, zero sequence
• Communications access code is used for
voltage, third harmonic neutral voltage,
communication system security (entering
field ground measurement circuit, stator
an access code of 9999 disables the low frequency injection voltage
communication security).
• Current Status: phase currents (A–B–C/
• Communication protocol and dead sync
a-b-c), differential current, neutral current,
time for COM2 and COM3.
ground differential current, positive
• Parity for COM2 or COM3 if MODBUS or sequence current, negative sequence
MODBUS over TCP/IP protocol is used. current, zero sequence current, stator low
• Response Time Delay frequency injection current
• IP Address, Net Mask and Gateway • Frequency Status: frequency, rate of
Address are required if the ethernet port is change of frequency
utilized and the network does not support • Volts/Hz Status: volts per hertz
the DHCP protocol. • Power Status: real power, reactive power,
Detailed information concerning setup and operation apparent power, power factor
of the communication ports is described in Chapter • Impedance Status: impedance (Zab, Zbc,
4, Remote Operation. Zca), positive sequence impedance, field
ground resistance
• Sync Check Status: 25S Sync Check
3.5 Status/Metering and 25D Dead Volt
• BRKR Monitor
Monitor Status/Metering
• 81A Accum. Status
■ NOTE: Please see Figure 3-3, Main Menu Flow,
for a list of submenus associated with • IN/OUT Status: Status of input and output
the STATUS menu. contacts
• Timer: 51V Delay Timer, 51N Delay Timer,
To access the STATUS menu and begin monitoring, 46IT Delay Timer, 24IT Delay Timer
proceed as follows: • Relay Temperature
1. Press the ENTER pushbutton to display • Counters: output, alarm counter
the main menu. • Time of Last Power up
2. Press the right arrow pushbutton until • Error Codes
STATUS is displayed on the top line of • Checksums: setpoints, calibration, ROM
the screen.

3–9
M-3425A Instruction Book

When a target is triggered, the front panel TARGET

3.6 Target History LED will light, indicating a recent event. If the
optional M-3925A Target Module is present, the
The M-3425A Generator Protection Relay includes corresponding function LED will be lit. If the optional
the ability to store the last 32 target conditions in a M-3931 HMI module is available, a series of screens
nonvolatile memory. A target is triggered whenever will be presented, describing the most recent
an output is operated. A second function attempting operation. This information is also available remotely
to operate an output (which is already operated) will by using the IPScom® Communication Software.
not trigger a new target, since no new output has
been operated or closed. If the second function To access the TARGET HISTORY menu perform
operation closes a different, unoperated output, a the following:
new target will be triggered. A target includes: 1. Press the ENTER pushbutton to access
• an indication which function(s) have the main menu.
operated, and timers expired (operated), 2. Press the right arrow pushbutton until
• status information which indicates any TARGET HISTORY is displayed on the
function that is timing (picked up), top line of the screen.
• individual phase element information at
the time of the trigger, if the operating To view Target History records proceed as follows:
function was a three phase function, 1. Ensure that the View Target History
• phase currents at the time of operation Menu is selected to TRGT (upper case).
• neutral current at the time of operation,
• input and output status, and VIEW TARGET HISTORY
TRGT clear
• a date/time tag.

If TRGT is not selected (Upper Case),

then use the Right/Left arrow pushbuttons
to select TRGT.
2. Press ENTER, the following will be
displayed:

VIEW TARGET HISTORY

1 Target number

Detailed descriptions for each View Target

History screen are presented on the
following page.

3–10
 Operation – 3

VIEW TARGET HISTORY This screen gives access to the target history, and also allows
TRGT clear the user to clear the target history record from memory.

Using up and down buttons, user may select which particular

VIEW TARGET HISTORY target to view from the last 24 recorded triggers.
1 Target number

TARGET 1 This screen gives the date and time tag of the selected target.
01-JAN-2001 12:27:35.125

TARGET 1 This screen displays operated outputs.

08 05 01

TARGET 1 This screen displays operated inputs at time of trip.

I3 I1

TARGET 1 The following screens display the timed out or “operate” func-
-OPERATE TARGETS- tions.

TARGET 1 This screen displays the specific function which timed out and
27#1 PHASE UNDERVOLTAGE triggered the target.

TARGET 1 This screen displays the phase information for the displayed
PHASE A=X B= C= function at time out.

The following screens display the timing on “picked up” func-

TARGET 1
tions when the target was recorded.
-PICKUP TARGETS-

TARGET 1
27#1 PHASE UNDERVOLTAGE

TARGET 1 This display gives the phase pickup information for the specific
PHASE A=X B=X C=X function.

TARGET 1
-CURRENT STATUS-

TARGET 1 This screen displays the phase current at the time the target
a=0.02 b=0.03 c=0.04 operated.

TARGET 1 This screen displays the neutral current at the time the target
N=0.50 AMPS operated.

3–11
M-3425A Instruction Book

This Page Left Intentionally Blank

3–12
 Remote Operation – 4

4 Remote Operation
1
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 group Serial Port (RS-485)
3
responsible for the remote operation and setting of COM3 located on the rear terminal block of the
the relay using the M-3820D IPScom M-3425A is an RS-485, 2-wire connection. Appendix
Communications Software or other means. B, Figure B-3 illustrates a 2-wire RS-485 network.
Individual remote addressing also allows for
4.1 Remote Operation communications through a serial multidrop network.
Up to 32 relays can be connected using the same
The M-3425A Generator Protection Relay provides
three serial communication ports and one ethernet
2-wire RS-485 communications line.
A
port. Optional Ethernet Port
The M-3425A when equipped with the optional
Serial Ports (RS-232) Ethernet Port can be accessed from a local network.
Two serial interface ports, COM1 and COM2, are When the ethernet port is enabled the COM2 serial
standard 9-pin, RS-232, DTE-configured ports. The port (RS-232) is unavailable for use. Although the
front-panel port, COM1, can be used to locally set ethernet connection speed is faster than the RS-232
and interrogate the relay using a temporary
connection to a PC or laptop computer. The second
RS-232 port, COM2, is provided at the rear of the
port (can be up to 10 Mbps), the ethernet module
connects internally through the COM2 serial
connection and is therefore limited to connection
B
unit. COM2 is unavailable for use when the optional speeds up to 9600 bps.
ethernet port is enabled.
The individual addressing capability of IPScom and Either COM2, COM3 or Ethernet port may be used
the relay allows multiple systems to share a direct to remotely set and interrogate the relay using a
or modem connection when connected through local area network, modem or other direct serial
COM2 using a communications-line splitter (see connection. Equipment such as RTU’s, data
Figure 4-1). One such device enables 2 to 6 units to
share one communications line. Appendix B, Figure
concentrators, modems, or computers can be
interfaced for direct, on-line, real time data
acquisition and control. Generally, all data available
C
B-2 illustrates a setup of RS-232 Fiber Optic network.
to the operator through the front panel of the relay
with the optional M-3931 HMI module is accessible
remotely through the BECO 2200, MODBUS, BECO
2200 over TCP/IP or MODBUS over TCP/IP data
exchange protocols.

4–1
 M-3425A Instruction Book

The communication protocols are used to fulfill the When fabricating communication cables, every effort
following communications functions: should be made to keep cabling as short as possible.
• Real-time monitoring of line status Low capacitance cable is recommended. The RS-232
standard specifies a maximum cable length of 50
• Interrogation and modification of setpoints
1 • Downloading of recorded oscillograph data
• Reconfiguration of all relay functions
feet for RS-232 connections. If over 50 feet of cable
length is required, other technologies should be
investigated.

Protocol documents are available directly from Other communication topologies are possible using
Beckwith Electric or from our website the M-3425A Generator Protection Relay. An
www.beckwithelectric.com. Application Note, “Serial Communication with
Direct Connection
Beckwith Electric’s Integrated Protection System
Relays” is available from the factory or from our
In order for IPScom to communicate with the relay website at www.beckwithelectric.com.
using direct serial connection, a serial “null modem”
cable is required, with a 9-pin connector (DB9P) for
the system, and an applicable connector for the
computer (usually DB9S or DB25S). Pin-outs for a
null modem adapter are provided in Appendix B,
Communications.
An optional 10 foot null modem cable (M-0423) is
available from the factory, for direct connection
between a PC and the relay’s front panel COM port,
3 or the rear COM2 port.

Null Modem Cable for

A Direct RS-232 Connection

IBM-Compatible PC

B Master Port

Communications-Line Splitter

C Address 6

Address 5

Address 4
Address 1
Address 3 Up to six controls
Integrated Protection can be used with a
System Address 2 communications-line splitter.

Figure 4-1 Multiple Systems Addressing Using Communications-Line Splitter

4–2
 Remote Operation – 4

Setting Up the M-3425A Generator Protection Communication Access Code: If additional link
Relay for Communication security is desired, a communication access code
The initial setup of the relay for communication can be programmed. Like the user access codes, if
must be completed by utilizing the optional M-3931 the communication access code is set to 9999
HMI Module or using direct serial connection.
For units shipped without the optional HMI Module,
(default), communication security is disabled.
Individual relay communication addresses should
1
the communication parameters may be altered by be between 1 and 200. The dead sync time, while
first establishing communication using the default not critical for most communication networks, should
parameters and the IPSutil™ program. be programmed to match the communications
channels baud rate (see Table 4-1, below).
IPSutil is an auxiliary program shipped on the same
disk with the IPScom ® program. It is used
exclusively for altering communication and setup
parameters on units shipped without the M-3931 Baud Rate De ad-Sync Time
HMI Module.
9600 4 ms
Serial Communication Settings 4800 8 ms
The following parameters must be set for proper
serial communication: 2400 16 ms
COM1 Baud Rate: Standard baud rates from 300 to
9600 are available. 1200 32 ms
COM2 Baud Rate: Standard baud rates from 300 to
9600 are available. COM2 and COM3 share the
Table 4-1 Dead-Sync Time 3
same baud rate (see Section 5.5, Circuit Board Ethernet Communication Settings
Switches and Jumpers).
The RJ45 ethernet port can be enabled utilizing
COM2 Dead Sync Time: This delay establishes either IPSutil™ from the Ethernet Settings menu or
the line idle time to re-sync packet communication. from the HMI Communication menu. When the
Dead sync time should be programmed based on ethernet port is enabled the COM2 Serial Port is not
the channel’s baud rate. available for use.
COM2 Protocol: BECO 2200 or MODBUS protocol
is supported on COM2.
The following parameters must be set for proper
ethernet communication:
A
COM2 Parity: None, odd or even parity is available DHCP Protocol
if MODBUS protocol is selected.
ENABLE: If the network server supports the DHCP
COM2 Stop Bits: One or two stop bits available if protocol the network server will assign the IP
MODBUS protocol is selected.
Address, Net Mask and Gateway Address.
COM3 Dead Sync Time: This delay establishes
the line idle time to re-sync packet communication.
Dead sync time should be programmed based on
the channel’s baud rate.
DISABLE: If the network server does not support
the DHCP protocol or the user chooses to manually
input ethernet settings, then obtain the IP Address,
B
Net Mask and Gateway address from the Network
COM3 Protocol: BECO 2200 or MODBUS protocol Administrator and enter the settings.
is supported on COM3.
COM3 Parity: None, odd or even parity is available ETHERNET Protocols
if MODBUS protocol is selected. SERCONV:To utilize the BECO2200 protocol over
a TCP/IP connection select the SERCONV
COM3 Stop Bits: One or two stop bits available if
MODBUS protocol is selected.
(BECO2200 TCP/IP) protocol. The IP Address of
the relay must be entered in the IPScom
Communication screen. Also, ensure that the COM2
C
Communications Address: For multidrop networks,
protocol is selected to BECO2200 and the baud
each device must have a unique address.
rate is set to 9600 bps.
Response Time Delay: The extra time delay may
be added while the relay is sending the response. If
set to 0, the response of the relay will be equal to
the time required to process the incoming packet
(usually 20–80 ms.)
4–3
 M-3425A Instruction Book

The Standard Port Number for the BECO2200 over 6. Ensure that TCP is selected (Upper Case).
TCP/IP protocol is 8800. The master device may
If TCP is not selected (Upper Case), then
require the entry of the Standard Port Number.
use the Right/Left arrow pushbuttons to
MODBUS:To utilize the MODBUS protocol over a select TCP.
1 TCP/IP connection select the MODBUS (MODBUS
over TCP/IP) protocol. The IP Address of the relay
7. Press ENTER, the following will be
displayed:
must be entered in the IPScom® Communication
screen. Also, ensure that the COM2 protocol is DHCP PROTOCOL
selected to MODBUS, baud rate is set to 9600 bps, DISABLE enable
1 stop bit and no parity selected.
8. If the network does not support the DHCP
The Standard Port Number for the MODBUS over
protocol, then go to Manual Configuration
TCP/IP protocol is 502. The master device may
of Ethernet Board (following page) to
require the entry of the Standard Port Number. manually configure the ethernet board.
9. If the DHCP Protocol is to be enabled, then
Ethernet Port Setup
use the Right/Left arrow pushbutton to select
Enabling the ethernet port and selecting the required ENABLE (Upper Case), then press ENTER,
support settings can be accomplished using either the following will be displayed:
the HMI or IPSutil™. Both methods are presented
below. TCP/IP SETTINGS
TCP prot
HMI Ethernet Port Setup

3 1. Ensure that the Communication Menu is

selected to COMM (upper case).
10. Ensure that PROT is selected (Upper Case).
If PROT is not selected (Upper Case), then
COMMUNICATION use the Right arrow pushbutton to select
targets osc_rec COMM PROT.
11. Press ENTER, the following will be
If COMM is not selected (Upper Case), displayed:
then use the Right/Left arrow pushbuttons
to select COMM. SELECT PROTOCOL
modbus serconv
A 2. Press ENTER, the following will be
displayed:
12. Use the Right/Left arrow pushbuttons to
COM1 SETUP select the desired protocol (Upper Case),
COM1 com2 com3 com_adr then press ENTER, the following will be
displayed:
3. Use the Right arrow pushbutton to select TCP/IP SETTINGS
ETH (Upper Case). tcp PROT
ETHERNET SETUP
13. Press EXIT, the ethernet board will
B 4.
access ETH eth_ip

Press ENTER, the following will be

reconfigure and the following will be
displayed:
displayed: CONFIGURING ETH...
ETHERNET
DISABLE enable
If the ethernet board successfully obtains
5. Use the Right arrow pushbutton to select an IP Address the following will be displayed
ENABLE (Upper Case), then press ENTER, for approximately 2 seconds:

C the following will be displayed:

TCP/IP SETTINGS
ETHERNET IP ADDRESS
XX.XX.XX.XX
TCP prot
The ethernet board is now configured for
use and may be accessed through a
network.

4–4
 Remote Operation – 4

Then the display will return to the following: 8. Use the Right/Left arrow pushbuttons to
select the desired protocol (Upper Case),
ETHERNET SETUP
then press ENTER, the following will be
access ETH eth_ip displayed:

If the ethernet board fails to obtain an IP

Address within 15 seconds the following
TCP/IP SETTINGS
tcp PROT
1
will be displayed (for approximately 2
9. Press EXIT, the ethernet board will
seconds):
reconfigure and the following will be
CONFIGURING ETH... displayed:
ETH BOARD ERROR CONFIGURING ETH...
Contact the Network Administrator to
determine the cause of the configuration
failure. If the ethernet board is successfully
configured, then the entered IP Address
Manual Configuration of Ethernet Board will be displayed for approximately 2
1. Ensure that DISABLE is selected (Upper seconds:
Case). ETHERNET IP ADDRESS
If DISABLE is not selected (Upper Case), XX.XX.XX.XX
then use the Left arrow pushbutton to select
DISABLE. The ethernet board is now configured for
2. Press ENTER, the following will be
displayed:
use and may be accessed through a
network. 3
IP ADDRESS
IPSutilTM Ethernet Port Setup with DHCP
XX.XX.XX.XX
1. Connect the appropriate RS232 cable from
3. Enter the desired IP Address, then press the PC hosting IPSutil to the target relay.
ENTER, the following will be displayed: 2. Launch IPSutil, then select Ethernet from
NET MASK the menu bar. IPSutil will display the Ethernet
XX.XX.XX.XX
3.
Settings screen Figure 4-43.
From the Ethernet Settings screen select
A
4. Enter the desired Net Mask, then press Ethernet Enable.
ENTER, the following will be displayed:
4. Select DHCP Protocol Enable.
GATEWAY 5. Select the desired protocol.
XX.XX.XX.XX
6. Select Save, IPSutil will respond with the
5. Enter the desired Gateway, then press Advance Setup dialog box stating “It will
ENTER, the following will be displayed:
TCP/IP SETTINGS
take about 15 seconds to reset Ethernet
board to allow the menu of the unit to
reflect the change.”
B
tcp prot
7. Select OK, IPSutil will configure the ethernet
board, then close the Ethernet Settings
6. Ensure that PROT is selected (Upper Case).
screen. The ethernet board is now
If PROT is not selected (Upper Case), then configured for use and may be accessed
use the Right arrow pushbutton to select through a network.
PROT.
7. Press ENTER, the following will be
displayed:
IPSutilTM Ethernet Port Setup without DHCP
1. Connect the appropriate RS232 cable from
C
SELECT PROTOCOL the PC hosting IPSutil to the target relay.
modbus serconv 2. Launch IPSutil, then select Ethernet from
the menu bar. IPSutil will display the Ethernet
Settings screen Figure 4-43.

4–5
 M-3425A Instruction Book

IPScom
File Comm Relay Window Help
A:1 M-3425

1 Window User Logo Lines Relay Type

File Cascade / Unit Identifier
Unit Address
New Tile
Open... Arrange Icons
Close Close All
Save
Save As...
Print
Help
Printer Setup
Print Summary Contents
Exit Alt+F4 Using Help
About...
Profile Info
Comm

Choosing the Comm menu sends you

3 directly to the Communication dialog box.

Setup System
Relay Setpoints
Set Date/Time
Primary Status

A Display
Reset LED
Secondary Status
Accumulator Status
Phase Distance
Setup Clear History Loss of Field
Retrieve Out of Step
Trigger Switching Method
Phasor Diagram
Clear Active Profile
Sync Scope
Setup Copy Profile
Function Status
Retrieve

B View
Clear

Figure 4-2 IPScom® Menu Selections

■ NOTE: Greyed-out menu items are for future release, and are not currently available.

4–6
 Remote Operation – 4

3. From the Ethernet Settings screen select b. The modem must be attached to (if
Ethernet Enable. external) or assigned to (if internal) the
same serial port as assigned in IPScom.
4. Select DHCP Protocol Disable. While IPScom can use any of the four
5. Enter values for IP Address, Net Mask and
Gateway.
serial ports (COM1 through COM4),
most computers support only COM1
and COM2.
1
6. Select the desired protocol.
c. Connect the modem to the telephone
7. Select Save, IPSutil will respond with the line and power up.
Advance Setup dialog box stating “It will
take about 15 seconds to reset Ethernet 2. Connecting the Modem to the Relay:
board to allow the menu of the unit to Setup of the modem attached to the relay
reflect the change.” may be slightly complicated. It involves
programming the parameters (using the AT
8. Select OK, IPSutil will configure the ethernet command set), and storing this profile in
board, then close the Ethernet Settings the modem’s nonvolatile memory.
screen. The ethernet board is now
configured for use and may be accessed After programming, the modem will power
through a network. up in the proper state for communicating
with the relay. Programming may be
accomplished by using “Hyperterminal” or
Installing the Modems
other terminal software. Refer to your modem
Using IPScom to interrogate, set or monitor the manual for further information.
relay using a modem requires both a remote modem
connected at the relay location and a local modem
connected to the computer with IPScom installed.
■ NOTE: The relay does not issue or understand
any modem commands. It will not adjust
the baud rate and should be considered
3
In order to use IPScom to communicate with the a “dumb” peripheral. It communicates
relay using a modem, the following must be provided with 1 start, 8 data, and 1 stop bit.
with the unit:
a. Connect the unit to an external modem
• An external modem (1200 baud or higher), by attaching a standard RS-232 modem
capable of understanding standard AT cable to the appropriate serial
commands. communications port on both the unit
• Serial modem cable with 9-pin connector
for the unit and the applicable connector
for the modem.
b.
and the modem.
Connect the modem to the telephone
line and power up.
A
■ NOTE: Any compatible modem may be used; The modem attached to the unit must have the
however, the unit only communicates at following AT command configuration:
1200 to 9600 baud.
E0 No Echo
Similarly, the computer running IPScom must also Q1 Don’t return result code
have access to an internal or external compatible &D3 On to OFF DTR, hang-up and reset
modem.
The local modem can be initialized, using IPScom,
&S0
&C1
DSR always on
DCD ON when detected
B
by connecting the modem to the computer, and S0=2 Answer on second ring
selecting the COMM menu in IPScom. Select
MODEM, enter the required information, and finally The following commands may also be required at
select INITIALIZE from the expanded the modem:
Communications dialog box. The following steps
outline the initialized modem setup procedure. &Q6 Constant DTE to DCE
N0 Answer only at specified speed
1. Connecting the modem to the computer:
a. If the computer has an external modem,
use a standard straight-through RS-232
W
\Q3
Disable serial data rate adjust
Bi-directional RTS/CTS relay
C
modem cable to connect the computer &B1 Fixed serial port rate
and modem (M-3933). If the computer S37 Desired line connection speed
has an internal modem, refer to the
modem’s instruction book to determine There are some variations in the AT commands
which communications port should be supported by modem manufacturers. Refer to the
selected. hardware user documentation for a list of supported
AT commands and direction on issuing these
commands.
4–7
 M-3425A Instruction Book

4.2 Installation and Setup (IPScom)

IPScom runs with the Microsoft Windows® 95

1 operating system or later. IPScom® only supports

communication using the BECO 2200 protocol.
Figure 4-3 IPScom Program Icon
IPScom is available on CD-ROM, or it my be
downloaded from our website at Installing IPSutil™
www.beckwithelectric.com
IPSutil is utility software used to program system-
The M-3820D IPScom Communications Software level parameters for units shipped without the M-3931
package is not copy-protected and can be copied to HMI Module. The IPSutil.exe file is automatically
a hard disk. For more information on your specific installed in the Becoware folder, along with the
rights and responsibilities, see the licensing IPScom files, and does not require separate
agreement enclosed with your software or contact installation.
Beckwith Electric.

Hardware Requirements 4.3 Operation

IPScom will run on any IBM PC-compatible computer
that provides at least the following: Activating Communications
• 8 MB of RAM After the relay has been set up, the modems
• Microsoft Windows 95 or later initialized, and IPScom installed, communication is
3 • CD-ROM drive
• one serial (RS-232) communication port
activated as follows:
1. Choose the IPScom icon from the
Becoware folder.
• pointing device (mouse)
2. The IPScom splash screen is displayed
briefly, providing the software version
Installing IPScom number and copyright information. This
1. Insert software CD-ROM into your drive. information is also available by choosing
An Auto-Install program will establish a the About... command from the Help menu.

A program folder (Becoware) and subdirectory

(IPScom). After installation, the IPScom
program item icon (see Figure 4-3) is
3. Choose the COMM menu selection.
Complete the appropriate information on
the window for the relay to be addressed.
located in Becoware. The default location a. If communication is through a modem,
for the application files is on drive C:, in the choose the Modem command button
new subdirectory “IPScom” to expand the communications dialog
(C:\Becoware\Ipscom). box. Choose the desired relay location
2. If the Auto-Install program does not launch and choose Dial button. This action
when the CD-ROM is inserted into the drive establishes contact and automatically

B then proceed as follows:

a. Select Run from the Start Menu.
opens communication to the relay.
b. If computer is connected through the
front port, choose the Open COM
b. In the Run dialog box, locate the button. This action establishes
installation file contained on the communications.
installation disk
(sfi_m3425Acom_V______.exe). 4. Enter any valid IPScom command(s) as
desired.
c. Select Run to start the installation
process. 5. To end communication when

C communicating by modem, choose the Hang

Up command button from the expanded
Communication dialog box. To close the
communication channel when connected
locally, choose the Close COM command
button.

4–8
 Remote Operation – 4

Overview Path: File menu / New command

When IPScom® is run, a menu and status bar is COMMAND BUTTONS
displayed, as shown in Figure 4-2. This section OK Saves the currently displayed
describes each IPScom menu selection and explains information.
each IPScom command in the same order as they
are displayed in the software program. For detailed
information regarding each dialog box field (function),
Cancel Returns you to the IPScom main window;
any changes to the displayed
1
information are lost.
refer to Chapter 2, Application.
The Save and Save As... commands allow re-
When starting IPScom, the initial menu choices are saving a file or renaming a file, respectively. The
the File menu or the Comm menu. The choice Open command allows opening a previously created
specifies whether the operator desires to write to a data file. With an opened data file, use the Relay...
data file or to communicate directly with the relay. Setup... menu items to access the setpoint
windows.
File Menu
If communication can be established with a relay, it
File is always safer to use the Read Data From Relay
command to update the PC’s data file with the
New
relay data. This file now contains the proper system
Open...
type information, eliminating the need to set the
Close
information manually.
Save
Save As... The Print and Printer Setup commands allow user
to select printer options and print out all setpoint
Print
Printer Setup
Exit Alt+F4
data from the data file or directly from the relay, if a
relay is communicating with the PC.
3
The File menu enables the user to create a new The Exit command quits the IPScom program.
data file, open a previously created data file, close,
print, and save the file. The IPScom program can Comm Menu
also be exited through the File menu.
File Comm Relay Window Help
Since IPScom can be used with several Beckwith
protection systems in addition to the M-3425A
Generator Protection Relay, the format and contents
of a file must be established depending on which
The Communication dialog box (see Figure 4-5)
allows setup of the IPScom communication data to
coordinate with the relay and by choosing the
A
protective system is being addressed. When not Modem button, to establish contact for remote
connected to one of the protection systems, using locations. When communicating by way of a fiber
the New command, a new file is established with optic loop network, echo cancelling is available by
the New Device Profile dialog box (see Figure 4-4). checking the Echo Cancel box. This command
Choosing the OK command button allows the new masks the sender’s returned echo.
data file to be named by using the Save or Save
As... commands. If the modem was not used to establish

■ NOTE: By choosing the NEW command, unit

and setpoint configuration values are
communication (direct connection), press the Open
COM button to start. If the relay has a default
communication access code of 9999, a message
B
based on factory settings specified for window will be displayed showing Access Level #3
the profiled protection system. was granted. Otherwise, another dialog box will
appear to prompt the user to enter the access code
in order to establish the communication. Close
System Type X
COM discontinues communication.
Unit Type: M-3425A

Nominal Frequency: 50 Hz 60 Hz
OK
C
C.T. Secondary Rating: 1A 5A Cancel

Phase Rotation: ABC ACB

Figure 4-4 New Device Profile Dialog Box

4–9
 M-3425A Instruction Book

Communication X Edit Displays the Add/Edit dialog box,

allowing you to review and change the
PC Port Baud Rate Open COM user lines (unit identifier), phone
COM1
1200 2400 Close COM
number, and communication address of
Echo Cancel
a selected entry.
1 Access Code
Relay
4800

Address
9600
TCP IP

Modem
Delete
Save
Deletes a selected entry.
Saves any changes to the displayed
Cancel
information
Open TCP_IP
TCP IP ADDRESS: Initialize Allows the user to send special setup or
Close TCP_IP other AT commands directly to the
Modem
modem.
Bring up terminal window after dialing
Phone Number: Dial Dials the entry selected from the
directory.

Add Hang Up Ends modem communication, allowing

the user to dial again.
Edit

Delete
Relay Menu
Save

Initialize Dial Hang Up

Relay

Setup

3 Figure 4-5
Path: Comm menu
Communication Dialog Box
Monitor
Target

COMMAND BUTTONS Sequence of Events

Oscillograph
Open COM Initiates contact withthe protective
system, either by direct serial or modem Profile
communication.
Write File to Relay
Close COM Breaks communication with the Read Data From Relay
protective system, for both direct serial

A TCP_IP
or modem communication.
Opens the ethernet applicable
communication screen selections to
The Relay menu provides access to the windows
used to set, monitor, or interrogate the relay. Six
submenus are provided: Setup, Monitor, Target ,
allow user to enter a TCP_IP address (if Sequence of Events, Oscillograph and Profile
necessary), and opening and closing as well as two commands, Write File to Relay, and
communication with the target relay.
Read Data From Relay.
Modem Displays the expanded Communication
dialog box.
Relay
Cancel Returns you to the IPScom main window;

B any changes to the displayed

information are lost.
Setup
Monitor
Target
Setup System
Setpoints
Set Date and Time
Open TCP_IP Initiates contact with the protective
Sequence of Events
system by ethernet connection.
Oscillograph
Close TCP_IP Closes Ethernet connection. Profile

Bring Up When selected, following connection to Write File to Relay

Terminal the target modem, allows the user to Read Data From Relay
Window send commands to the modem.
After The Setup submenu provides three commands:
C Dialing
Add Displays the Add/Edit dialog box,
Setup System, Setpoints, and Set Date/Time.
The Setup System command displays the Setup
allowing you to type a protective System dialog box (Figure 4-6) allowing the input of
system’s unit identifier, phone number, the pertinent information regarding the system on
and communication address. which the protective relay is applied (see Section
2.1, Configuration, Relay System Setup).

4–10
 Remote Operation – 4

SETUP

SETUP SYSTEM

Nominal Frequency: 60 Hz C.T. Secondary Rating: 5A 1

Nominal Voltage: 120 50.0 V 140.0 V
Delta-Y Transform

Nominal Current: 5.00 0.50 A 6.00 A Disable Delta-AB Delta-AC

Input Active State: 6 5 4 3 2 1

Input Active State Expanded
Open Open Open Open Open Open
Close Close Close Close Close Close

V.T. Configuration: Line to Ground Line to Line Line-Ground to Line-Line

59/27 Mag. Select: RMS 50DT Enable Relay Seal-In Time Relay Seal-In Time Expanded
DFT
Split Phase
Phase Rotation: ABC AC B Differential: Disable OUT 1: 30 8160 OUT 9: 30 8160 30 OUT 17
cycles cycles
V.T. Phase Ratio: :1 1.0 2: 30 10: 30 30 18
1.0 6550.0
3: 30 11: 30 30 19
V.T. Neutral Ratio: 1.0 :1 1.0 6550.0
4: 30 12: 30 30 20
V.T. VX Ratio 1.0 :1 1.0 6550.0
5: 30 13: 30 30 21
C.T. Phase Ratio: 10 :1 1 65500 6: 30 14: 30 30 22
C.T. Neutral Ratio: 10 :1 1 65500 7: 30 15: 30 30 23
2 2
Pulse Relay
Outputs: 1

Latched Outputs
Outputs: 1
2 3

2
4

3
5

4 5
6

6
7

7
8

8
8: 30 cycles

Pulse Relay Expanded Outputs

16: 30 cycles
3
Injection Frequency for F64S: 20 Hz Latch Relay Expanded Outputs

Note: Pulse/Latched Relay Outputs should be selected in 2 steps

i)Deselect Latched/Pulse Relay Outputs and Save
ii) Select Pulse/Latched Outputs and Save

Save Cancel A
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 Active
State
Expanded
State screen (Figure 4-7), to allow the selection of Expanded Inputs 7 through 14. B
Pulse/Latch When the unit is equipped with expanded I/O, this command opens the Pulse/Latch
Relay screen (Figures 4-8 and 4-9) to allow the selection of expanded outputs 9 through 23.
Expanded
Outputs
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 by
an opening rather than a closing external contact.
C

4–11
 M-3425A Instruction Book

? X
Expanded Input Active State

1 7

8
Open

Open
Close

Close
11

12
Open

Open
Close

Close
OK

Cancel
9 Open Close 13 Open Close

10 Open Close 14 Open Close

Figure 4-7 Expanded Input Active State

? X

Pulse Relay Expanded Outputs

OUTPUT9 OUTPUT17

OUTPUT10 OUTPUT18

OUTPUT11 OUTPUT19

3 OUTPUT12

OUTPUT13
OUTPUT20

OUTPUT21
OK

Cancel
OUTPUT14 OUTPUT22

OUTPUT15 OUTPUT23
OUTPUT16

A Figure 4-8 Pulse Relay Expanded Output Screen

? X

Latch Relay Expanded Outputs

OUTPUT9 OUTPUT17

OUTPUT10 OUTPUT18

B OUTPUT11

OUTPUT12
OUTPUT19

OUTPUT20 OK
OUTPUT13 OUTPUT21
Cancel
OUTPUT14 OUTPUT22

OUTPUT15 OUTPUT23

OUTPUT16

C
Figure 4-9 Latch Relay Expanded Output Screen

4–12
 Remote Operation – 4

The Setpoints command displays the Relay feature hotspots which allows the user to jump from
Setpoints dialog box (see Figure 4-10) from which a scrolling dialog box to an individual relay function
the individual relay function dialog boxes can be dialog box and return to the scrolling dialog box
accessed. Choosing a Relay function button will again. All available parameters can be reviewed or
display the corresponding function dialog box (see
Figure 4-11 for example).
changed when jumping to a relay configuration dialog
box from either scrolling dialog box. 1
? X

M3425A Relay Setpoints X F46

(46) - NEGATIVE SEQUENCE OVERCURRENT

21 49 59 78
Pickup: 3% 100% Def. Time
Phase
Phase Distance Stator Overload Overvoltage Out of Step
Delay: 1 Cycle 8160 Cycles

24 50BF 59D 81 OUTPUTS @ Blocking Inputs

Expanded I/O’s
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1
Third Harmonic Frequency
Volts/Hz Breaker Failure Voltage Diff.
81A
25 Pickup: 3% 100% Inv. Time
50 59N Freq. Accum.
Instan. Phase Neutral Time Dial: 1 95
Sync Check Overcurr. Overvoltage 81R
Maximum Time: 600 Cycles 65500 Cycles
ROCOF
27TN 50N 59X Reset Time: 1 Second 600 Seconds
Third Harmonic Instan. Neutral Multipurpose 87
Overcurrent OUTPUTS @ Blocking Inputs
Overvoltage Overvoltage Expanded I/O’s
Phase Differential 8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1
27 50DT 60FL Current
Phase Definite Time VT Fuse-Loss 87GD @ : WARNING, You have not selected an output!
Undervoltage Overcurrent Detection Ground
Differential Save Cancel
32 50/27 64F/B
Inadvertent Field Ground IPS
Directional Power Energizing Protection IPS Logic
40 51N 64S BM Figure 4-11 Typical Setpoint Dialog Box
Inv. Time Neu. 100% Stator
Loss of Field Overcurrent Ground Breaker Monitor
Path: Relay menu / Setup submenu / Setpoints window/ 46

3
46 51V 67N TC
Neg. Seq. Inv. Time Residual Dir. Trip Circuit command button OR 46 jump hotspot within All Setpoints
Overcurrent Monitor
Overcurrent Overcurrent Table or Configure dialog box
FUNCTIONS FUNCTIONS
21 -- 51V 59 -- TC
COMMAND BUTTONS
Configure Configure
Save When connected to a protection system,
OUTPUTS 1-8 OUTPUTS 9-23
Exit
sends the currently displayed
INPUTS 1-FL INPUTS 7-14 information to the unit. Otherwise, saves
the currently displayed information and
Figure 4-10 Relay Setpoints Dialog Box returns you to the Relay Setpoints, All
Setpoints Table, or Configure dialog
Path:

COMMAND BUTTONS
Relay menu / Setup submenu / Setpoints window
Cancel
box.
Returns the user to the Relay Setpoints,
A
All Setpoints Table, or Configure dialog
Functions Opens the All Setpoints Table dialog box box; any changes to the displayed
for the specified range of functions. information are lost.
Configure Opens the Configure dialog box. Expanded When the unit is equipped with expanded
I/O’s I/O, this selection allows the user to select
Exit Saves the currently displayed expanded outputs 9–23 and expanded
information and returns you to the inputs 7–14.
IPScom® main window.
The Relay Setpoints dialog box gives access to two
additional dialog boxes: All Setpoints Table and
? X B
Expanded Output Initiate Expanded Input
Configure. Initiate
OUTPUT9 OUTPUT17 Input 7

Choosing either of the Functions command buttons OUTPUT10 OUTPUT18 Input 8

(either 21–51V or 59–TC) displays an All Setpoints OUTPUT11 OUTPUT19 Input 9 OK

Table dialog box for the specified range of setpoints OUTPUT12 OUTPUT20 Input 10
Cancel
(see Fig. 4-13). This dialog box contains a list of OUTPUT13 OUTPUT21 Input 11

settings for each relay within a single window to OUTPUT14 OUTPUT22 Input 12

allow scrolling through all relay setpoint configuration

values. Choosing the Configure command button
displays the Configure dialog box (see Fig. 4-14),
OUTPUT15
OUTPUT16
OUTPUT23 Input 13

Input 14 C
which contains a chart of programmed input and
output contacts, in order to allow scrolling through Figure 4-12 Expanded I/O Initiate
all relay output and blocking input configurations.
Both dialog boxes (All Setpoint Table and Configure),

4–13
 M-3425A Instruction Book

All Setpoints Table X

SETUP SYSTEM F64S Frequency: Seal-In Time (Cycles) Seal-In Time Expanded
Nominal Voltage: V.T. Configuration: OUT1: OUT5:
OUT9-15:

1 Nominal Current: V.T. Phase Ratio: OUT2: OUT6:

Nominal Frequency: V.T. Neutral Ratio: OUT3: OUT7:
Phase Rotation: OUT4: OUT8:
V.T. VX Ratio:
C.T. Secondary Rating: C.T. Phase Ratio: Latch Relay Expanded Outputs
59/27 Mag. Select: C.T. Neutral Ratio
Delta-Y Transform: 50DT Split Phase: Pulse Relay Expanded Outputs
Latch Relay Outputs: Fuse Relay Outputs:
(21)- PHASE DISTANCE Circle Diameter:
Circle Diameter: Circle Diameter: Offset:
Offset: Offset: Impedance Angle:
Impedance Angle: Impedance Angle: Load Encr. Angle:
Load Encr. Angle: Load Encr. Angle: Load R Reach:
Load R Reach: Load R Reach: Delay:
Delay: Delay: Out of Step Delay:
Overcurrent SV: Overcurrent SV: Overcurrent SV:
Out of Step Block En: Out of Step Block En: Out of Step Block En:
Load Encr. En: Load Encr. En: Load Encr. En:
OC Supervision En: OC Supervision En: OC Supervision En:

(24)- VOLTS/HZ Inverse Time (25)- SYNC CHECK

Definite Time Ph. Ang. Window: Dead Volt Limit:
Pickup #1: Pickup:
Upper Volt. Limit: Dead V1 Hot V2:

3 Delay #1:

Pickup #2:
Time Dial:

Curves #:
25S Lower Volt Limit:
Sync Check Delay:
Delta Voltage:
25D
Hot V1 Dead V2:
Dead V1 Dead V2:
Dead Delay:
Delay #2: Reset Rate: Delta Frequency: Input Initiate:
25S Sync Check:

(27TN)- UNDERVOLTAGE, NEUTRAL (27)- PHASE UNDERVOLTAGE

Pickup: Pickup: Pickup #1:
Pos. Seq. Volt. Block: Pos. Seq. Volt. Block: Delay #1:
Forward Power Block: Forward Power Block:

A Reverse Power Block:

Lead VAR Block:
Reverse Power Block:
Lead VAR Block:
Pickup #2:

Delay #2:

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 and

B the 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.

4–14
 Remote Operation – 4

Configure X

O U T P U T S Blocking Inputs
8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1
1
#1
21 #2
#3

Def. Time #1
24 Def. Time #2
Inverse Time
25 Sync
Dead
27TN #1
#2
#1
27 #2
#3

32
#1 3
#2
#3
#1
40 #2
VC#1
VC#2

46
Def. Time
Inv. Time
A
50BF
#1
50
#2
50N

50DT
#1
#2 B
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
C
Close Returns you to the Relay Setpoints dialog box.
Move Allows you to reposition the dialog box.

4–15
 M-3425A Instruction Book

Configure X

E x p a n d e d O U T P U T S Expanded Blocking Inputs

23 22 21 20 19 18 17 16 15 14 13 12 11 10 9 14 13 12 11 10 9 8 7
1 #1
21 #2
#3

Def. Time #1
24 Def. Time #2
Inverse Time
25 Sync
Dead
27TN #1
#2
#1
27 #2
#3
#1
32 #2
#3

3 40
#1
#2
VC#1
VC#2
Def. Time
46
Inv. Time
50BF
#1
50
#2

A 50N

50DT
#1
#2

Figure 4-15 Configure Dialog Partial (Shown with Expanded Input/Outputs)

Path: Relay menu / Setup submenu / Setpoints window/ Configure command button

JUMP HOTSPOTS

B 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
Close Returns you to the Relay Setpoints dialog box.
Move Allows you to reposition the dialog box.

4–16
 Remote Operation – 4

The Set Date/Time command (see Figure 4-16) The Monitor submenu provides access for reviewing
allows the system date and time to be set, or the present status of the relay's measured and
system clock to be stopped. This dialog box also calculated values, other real-time parameters and
displays an LED mimic to identify when the Time conditions as well as examining real-time and
Sync is in use (preventing date/time from being
changed by user).
historical demand metering information (see Section
4.4, Checkout Status/Metering). A cascading menu
appears, providing several command options as
1
shown below.
■ NOTE: Displayed parameters in status screens
will vary depending on unit configuration.

Relay

Setup
Monitor Primary Status
Target Secondary Status
Sequence of Events Accumulator Status
Oscillograph Phase Distance
Profile Loss of Field

Write File to Relay Out of Step

Read Data From Relay Phasor Diagram

3
Sync Scope
Figure 4-16 Unit Date/Time Dialog Box Function Status

Path: Relay menu/ Setup submenu/ Set Date/Time

Command The Targets submenu provides three command
There is a blue Time Sync LED mimic in this dialog options: Display, Reset LED, and Clear History.
box (the LED is displayed as different shading on a The Display command displays the Target Dialog.
monochrome monitor). When this LED is blue, the This dialog box (see Figure 4-17) provides detailed
relay is synchronized with the IRIG-B signal and the data on target events, including time, date, function
Time field is grayed out, indicating that this field status, phase current values, and IN/OUT contact
can’t be changed. But the Date field can be changed
(by editing and pressing Save).
status at the time of trip. Individually recorded
events may be selected within the dialog box and A
saved into a text file, or be printed out with optional
When the LED is not blue, the relay is not time- added comments. The Reset LED is similar to
synchronized and therefore, both the Date and Time pushing the Target Reset button on the relay’s front
fields can be changed. panel, resetting current target(s) displayed on the
relay. This command does not reset any target
The time field in the dialog box is not updated
history.
continuously. The time at which the dialog box was
opened is the time that is displayed and remains as
such. This is true whether the relay is synchronized
with the IRIG-B signal or not.
Relay

Setup
B
Monitor
Target Display
COMMAND BUTTONS
Sequence of Events Reset LED
Stop Clock This toggles between start/stop, the relay Oscillograph Clear History
clock. ‘Stop’ pauses, ‘Start’ resumes.
Profile
Save Saves Time and Date settings to the

C
Write File to Relay
relay when applicable.
Read Data From Relay
Cancel Returns you to the IPScom ® main
window. Any changes to the displayed
information is lost.
The Clear History command clears all stored target
data.

4–17
 M-3425A Instruction Book

Target List X Target X

01. 01-Jan-2000 01:01:80.000
02. 01-Jan-2000 01:01:80.000 FL 6 5 4 3 2 1
Inputs:
03. 01-Jan-2000 01:01:80.000
04. 01-Jan-2000 01:01:80.000
14 13 12 11 10 9 8 7

1
Expanded Inputs:

Outputs: 8 7 6 5 4 3 2 1

16 15 14 13 12 11 10 9
Expanded Outputs

23 22 21 20 19 18 17

Phase a Phase b Phase c Phase N

Currents:

-326.99 A -326.99 A -326.99 A 109.90 mA

Function # Status

Comment Print Save Close

Figure 4-17 Target Dialog Box

Path: Relay menu / Targets submenu / Display window

3 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.

A Sequence of Events
The Sequence of Events function provides a time View the pararmeters captured at the time of the
stamped history of the Pickup (PU), Trip (TR) or event and Clear the event recorder.
Dropout (DR) for each element, input or output
selected in the Event Trigger Setup screen. The Setup menu item displays the Event Trigger
Setup screen Figure 4-18. Protective function Pickup,
During each event the voltage, current, impedance, Trip, Dropout and/or Output/Input Pickup or Dropout
frequency, input and output status and Volts/Hz are are selected to trigger the Sequence of Events
recorded. Up to 512 events are logged before the Recorder.
buffer begins to write over the oldest event. If multiple
B events occur, then the log entries are recorded with
one millisecond resolution within each event.
The Retrieve command downloads the events from
the currently connected relay (events must be
retrieved from the relay and stored in a file in order to
view them.)
Relay

Setup View permits the user to see a detailed list of past

Monitor events and their corresponding captured parameters
Target (real power, reactive power, differential current, delta
Sequence of Events Setup voltage, delta frequency, phase angle, 59D ratio, V
brush (64B), field insulation resistance (64F), Vstator
C Oscillograph Retrieve

Profile
View (20 Hz), and Istator (20 Hz) which are displayed in
Clear
the Event Log Viewer screen Figure 4-19.
Write File to Relay
Read Data From Relay The event log viewer screen includes the commands
Open, Close, Print Summary, and Print Detail.
The Sequence of Events submenu allows the user Open opens a saved sequence of events file. Close
to Setup the events that trigger the Sequence of closes the print file. Print Summary prints an event
Events recorder, Retrieve events from the relay, summary, and Print Detail prints the detailed event
report. Clear deletes event history from the control.

4–18
 Remote Operation – 4

Elements trigger on Trip, Drop Out and Pickup

Event Trigger Setup X

Pickup Drop

1
Functions

PU TR DR PU TR DR PU TR DR PU TR DR PU TR DR o input7 o input7
o o o F21 #1 o o o F32 #3 o o o F50N o o o F64F #2 o o o F81r #1 o input8 o input8
o o o F21 #2 o o o F40 #1 o o o F51N o o o F64S o o o F81R #2 o input9 o input9
o o o F21 #3 o o o F40 #2 o o o F51V o o o F67NDT o o o F87 #1 o input10 o input10
o input11 o input11
o o o F24DT #1 o o o F40VC #1 o o o F59 #1 o o o F67NIT o o o F87 #2
o input12 o input12
o o o F24DT #2 o o o F40VC #2 o o o F59 #2 o o o F78 o o o F87GD
o input13 o input13
o o o F24IT o o o F46DT o o o F59 #3 o o o F81 #1 o o o FBM o input14
o input14
o o o F25S o o o F46IT o o o F59D o o o F81 #2 o o o FTC o output9 o output9
o o o F25D o o o F49 #1 o o o F59N #1 o o o F81 #3 o o o IPSL #1 o output10 o output10
o o o F27 #1 o o o F49 #2 o o o F59N #2 o o o F81 #4 o o o IPSL #2 o output11 o output11
o o o F27 #2 o o o F50 #1 o o o F59N #3 o o o F81A #1 o o o IPSL #3 o output13 o output13
o o o F27 #3 o o o F50 #2 o o o F59X #1 o o o F81A #2 o o o IPSL #4 o output14 o output14
o output15 o output15
o o o F27TN #1 o o o F50/27 o o o F59X #2 o o o F81A #3 o o o IPSL #5
o output16 o output16
o o o F27TN #2 o o o F50BF o o o F60FL o o o F81A #4 o o o IPSL #6
o output17 o output17
o o o F32 #1 o o o F50DT #1 o o o F64B o o o F81A #5 o output18
o output18
o o o F32 #2 o o o F50DT #2 o o o F64F #1 o o o F81A #6 o output19 o output19
o output20 o output20
o output21 o output21
Outputs Inputs o output22
o output22
Expanded IO<<
PU 1 2 3 4 5 6 7 8 PU 1 2 3 4 5 6 o output23 o output23
DR 1 2 3 4 5 6 7 8 DR 1 2 3 4 5 6

Note: PU -- Pickup TR -- Trip DR -- Drop Save Cancel

I/O triggers on Pickup, Drop Out

3
Figure 4-18 Trigger Events Screen with Expanded I/O

Impedance, Sync Information

Pickup, Dropout, Trip Event #, Date, Time

Event Log Viewer X

A
Open Close Print Summary Print Detail

Event Record 1
No. Event Summary
Voltages (V) Impedance (Ohm)
1 09/01/2004, 15:01:33.007
F27 #1: Pickup [A ]/Trip [A ] VA 99.9 VB 120.5 VC 119.9 Rab 110.68 Xab 5.04
2 09/01/2004, 15:02:55.507
F27 #1: Pickup [A ]/Trip [A ] VN 119.7 VX 119.7 3rdH 1.63 Rbc 120.18 Xbc -0.76
F50 #2: Pickup [A ]/Trip [A ]
3 09/01/2004, 15:02:55.615 VPS 113.3 VNS 6.7 VZS 6.7 Rca 110.48 Xca -6.62

4
F27 #1: Pickup [A ]/Trip [A
F32 #1: Pickup/Trip
F50 #2: Pickup [A ]/Trip [A
09/01/2004, 15:05:03.624
F21 #2: Pickup
]

] Currents (A)
IA 0. 996 IB 1.005 IC 0.997
Others
V/Hz (%) 99.9
B
F27 #1: Pickup [A ]/Trip [A ]
F32 #1: Pickup/Trip Ia 0. 994 Ib 1.003 Ic 0.997 Frequency (Hz) 99.9
F21 #3: Pickup [A C]
F50 #2: Pickup ]A ]/Trip [A ] IPS 0.996 INS 0.002 IN 0.997 Current Profile 1

Input
PU 1 2 3 4 5 6
Items Value Unit
Expanded Real Power 0.97 W
IO >>
DR 1 2 3 4 5 6 Reactive Power -0.007 Var
IZS 0.003 A
Output Ia diff 1.01 A
PU

DR
1

1
2

2
3

3
4

4
5

5
6

6
7

7
8

8
Ib diff
Ic diff
Delta V
Delta F
1.01
1.01
0.1
0.000
A
A
V
Hz
C
Voltages, Currents and I/O Status

Figure 4-19 Event Log Viewer

4–19
 M-3425A Instruction Book

Retrieve Oscillograph Record X

Events Download X
Record #1: Cleared Record #9: Cleared
Event Record Record #2: Cleared Record #10: Cleared

Record #3: Cleared Record #11: Cleared

Total Event Number: Download Record #4: Cleared Record #12: Cleared

1 Record #5: Cleared

Record #6: Cleared

Record #7: Cleared

Record #13: Cleared

Record #14: Cleared

Record #15: Cleared

Record #8: Cleared Record #16: Cleared

Cancel
File Format: Beco (.OSC) COMTRADE (Binary.cfg, .dat)

Retrieve Cancel

Figure 4-20 Event Download Screen

Figure 4-22 Retrieve Oscillograph Record
Dialog
Relay

Setup
Monitor Relay

Target Setup
Sequence of Events Monitor
Oscillograph Setup Target
Profile Retrieve Sequence of Events
Trigger Oscillograph
Write File to Relay Switching Method
Clear Profile Active Profile
Read Data From Relay
Copy Profile

3 The Oscillograph submenu allows storing data on

selected parameters for review and plotting at a
Write File to Relay
Read Data From Relay

later time. The Setup command allows the user to The Profile submenu provides three command
set the number of partitions and triggering options: Switching Method, Active Profile, and
designations to be made (see Table 3-1, Recorder Copy Profile.
Particitions). The Retrieve command downloads
and stores collected data to a file; Trigger allows Switching Method command allows selection of
the manual triggering of the recorder; Clear erases either Manual or Input contact. Active Profile allows
user to designate active profile. Copy Profile copies
A the existing records. Run the optional M-3801D
IPSplot® PLUS Oscillograph Analysis Software
program to view the downloaded oscillograph files.
active profile to one of four profiles (user should
allow approximately 2 minutes for copying.)
▲ CAUTION: Switching the active profile when the
Setup Oscillograph Recorder
relay is on-line may cause unexpected operation if
Number of Records

1 2 3 4 5 6 7 8
the wrong profile is selected.
9 10 11 12 13 14 15 16

Profile Switching Method ? X

Post Trigger Send
Delay 0 %

B
Cancel
Trigger Inputs
Manual Input Contact
6 5 4 8 7 6 5

3 2
Trigger Outputs
1 4 3 2 1 Active Profile
Trigger Inputs Expanded Trigger Outputs Expanded
14 13 12 11 23 22 21 20 19 18 17 16 P1 P2 P3 P4
10 9 8 7 15 14 13 12 11 10 9

OK Cancel

Figure 4-21 Setup Oscillograph Recorder

Figure 4-23 Profile Switching Method
Dialog
C ■ NOTE: During Profile Switching, relay operation
is disabled for approximately 1 second.

4–20
 Remote Operation – 4

Select Active Profile ? X Window Menu/Help Menu

Manual Input Contact

Active Profile

P1 P2 P3 P4
1
The Window menu enables the positioning and
arrangement of all IPScom® windows so that there
OK Cancel
is better access to available functions. This feature
allows the display of several windows at the same
time. Clicking on an inactive window activates that
Figure 4-24 Select Active Profile window.

Copy Active Profile ? X

Currently in revision, the Help menu will enable the
user to look up information about any IPScom
Manual Input Contact
menus or commands. Though displaying (greyed-out)
Help commands, this menu item is currently
Copy Active Profile to:
unavailable.
P1 P2 P3 P4

Help
OK Cancel

Figure 4-25 Copy Active Profile

Contents
About...
3
Profile Info
The Write File To Relay command is used to write
the data to the relay. The Read Data From Relay
command is used to retrieve the data from the relay The Help menu provides three commands. The
to the computer for display. Contents command initiates a link to a PDF (Portable
Document File) version of this instruction book for
easy reference. An Adobe Acrobat® reader is
Relay

Setup
Monitor
required to view this document.
The M-3425A Instruction Book has been indexed to
A
Target its table of contents. By selecting the “Navigator
Sequence of Events pane’ in Adobe Acrobat Reader, the user can directly
Oscillograph
access selected topics. The About command
Profile
displays IPScom version and development
information. Profile Info displays user infromation
Write File to Relay for input and editing.
Read Data From Relay

About IPScom
IPScoms OK
X
B
Integrated Protection System
Version: D-0133V02.00.15
Copyright 1997-2002 Beckwith Electric Co., Inc.

Unit Information
ID M-3425A

BECKWITH ELECTRIC CO
M-3425A

Serial Number
Software Version
Communication Address
1
V02.00.22
1
C
Control Number 1
Setpoint Checksum 13
Calibration Checksum 3E

Figure 4-26 About IPScom Dialog Box

4–21
 M-3425A Instruction Book

4.4 Checkout Status/Metering

Primary Status - X

1 0.00
Phase A
(v)
0.00
Phase B (v)
0.00
Phase C (v)
0.00
Neutral
(v)
0.00
Pos Seq
(v)
VOLTAGE

0.00
Neg Seq
(v)
0.00
Zero Seq (v)
0.00
3rd Harm
(v)
0.00
VX
(v)

CURRENT

0.0 0.0 0.0 0.0 0.0 0.0 0.0

Phase A (A) Phase B (A) Phase C (A) Neutral (A) Phase a (A) Phase b (A) Phase c (A)

0.000 0.000 0.000

Pos. Seq. (A)

Neg. Seq. (A) Zero Seq. (A)

POWER

0.00 0.00 0.00 0.00 LAG

(W) (W) (va) Power Factor
Real Reactive Apparent

FREQUENCY V/HZ ROCOF

DISABLED 0.0 DISABLED

Hz % Hz/S

OUTPUTS INPUTS BREAKER

CLOSED

8 7 6 5 4 3 2 1 FL 6 5 4 3 2 1

EXPANDED OUTPUTS EXPANDED INPUTS

3 16 15 14 13 12 11 10 9 13 12 11 10 9 8 7

23 22 21 20 19 18 17 14

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.

A Secondary Status - X

VOLTAGE

0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.0
Phase A Phase B Phase C Neutral VX Pos Seq Neg Seq Zero Seq Low F Inj. Brush (mV)

0.0 0.0 0.0

VN (3rd) V0 (3rd) 3V0/VN

CURRENT

0.000 0.000 0.000 0.000 0.000 0.000 0.000 0.000

Phase A Phase B Phase C Neutral Pos. Seq. Neg. Seq. Zero Seq. Low F. Inj (mA)

B Phase a
0.000
Phase b
0.000

POWER
Phase c
0.000 0.000
A-a diff B-b diff
0.000
C-c diff
0.000 0.000
I diff G
0.000
49#1 49#2
0.000

FREQUENCY V/HZ ROCOF

0.0000 0.0000 0.0000 0.0000 DISABLED 0.0 DISABLED

Real (p.u.) Reactive (p.u.) Apparent (p.u.) Factor
Hz % Hz/S

IMPEDANCE

R 0.00 X 0.00 R 0.00 X 0.00 R 0.00 X 0.00 R 0.00 X 0.00 R <5 k ohm

Phase AB Phase BC Phase CA Pos Seq Field Insulation

OUTPUTS BREAKER
INPUTS

C 8 7 6

EXPANDED OUTPUTS
5 4 3 2 1 FL 6 5 4

EXPANDED INPUTS
3 2 1
CLOSED

16 15 14 13 12 11 10 9 13 12 11 10 9 8 7

23 22 21 20 19 18 17 14

Figure 4-28 Secondary Status Dialog Box

Path: Relay menu/ Monitor submenu/ Secondary Status window

4–22
 Remote Operation – 4

Frequency Accumulator Status

Startup Time:
Accumulator #1 Cycles
1
Accumulator #2 Cycles

Accumulator #3 Cycles

Accumulator #4 Cycles

Accumulator #5 Cycles

Accumulator #6 Cycles

Breaker Monitor Accumulators

Neutral: (Amp Cycles)
Phase A Phase B Phase C

3
Figure 4-29 Accumulator Status Screen

Phase Distance X
Circle Diameter
X 1.00
70
Circle Offset

A
0.10
60

Circle Impedance Angle

50

40

30 Phase Impedances:

AB: Ω
20
BC: Ω

10 CA: Ω

-0.80 -0.60 -0.40 -0.20 0.20 0.40 0.60 0.80

Load Encr Angles:
B
-10 Load Encr. R Reach:

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.
C
CONTROL BUTTONS Move the scope window to the right
Move up the scope window Zoom In
Move down the scope window Zoom Out
Move the scope window to the left Refresh Scope

4–23
 M-3425A Instruction Book

Loss of Field X
Circle Diameter:
X

10 Circle Offset:

1
-0.80 -0.30 -20 -10 10 20 30 40
Directional Element
-10

-20
Positive Sequence
Impedance :

-30

-40

-50

-60

-70

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 sequence
impedance.

CONTROL BUTTONS

Zoom In
3 Move up the scope window
Move down the scope window Zoom Out

Move the scope window to the left Refresh Scope

Move the scope window to the right

Out of Step X
Circle Diameter

A
X 20.0 W
40
Circle Offset
15.0 W
35

Circle Impedance Angle

30
85°

25
Blinder Impedance
20 5.0 W

Positive Sequence Impedance

15 327.67 + j327.67 W

Trip on Mho Exit

B
10
ENABLED

5
-0.80 -0.60 -0.40 -0.20 -10 0.20 0.40 0.60 0.80

Figure 4-32 Out-of-Step Dialog

Path: Relay menu / Monitor submenu / Out-of-Step window

C CONTROL BUTTONS

Move up the scope window Move the scope window to the right

Move down the scope window Zoom In

Move the scope window to the left Zoom Out

Refresh Scope

4–24
 Remote Operation – 4

Figure 4-33 Phasor Dialog Box

Path: Relay menu / Monitor submenu / Phasor Diagram window

CONTROL BUTTONS
3
p Voltage Toggle & display voltage channel information
p Currents (A) Toggle & display current channel information.
p Freeze Toggle & update information

Sync Scope X

SLOW
0
FAST
A
330 30
o
Phase Angle: 23.1

Delta Volts: 0.4 V

300 60 Delta Freq: 0.023 Hz

270 90
B
240 120

210 150

180

Figure 4-34 Sync Scope Screen

C

4–25
 M-3425A Instruction Book

Function Status X

P T P: Pickup T:Tripped T P
(21) #1 Phase Distance (59N) #1 Neutral Overvoltage

1 (21) #2 Phase Distance

(21) #3 Phase Distance
(24DT) #1 Volts/Hz DEF
(24DT) #2 Volts/Hz DEF
(59N) #2 Neutral Overvoltage
(59N) #3 Neutral Overvoltage
(59X) #1 Multi-purpose Overvoltage
(59X) #2 Multi-purpose Overvoltage
(24IT) Volts/Hz INV (60FL) VT Fuse Loss
(27) #1 Phase Undervoltage (64F) #1 Field Ground
(27) #2 Phase Undervoltage (64F) #2 Field Ground
(27) #3 Phase Undervoltage (64B) Brush Lift-Off
(25S) Sync Check
(64S) 100% Stator Ground
(25D) Dead Check
(67NDT) Residual Definite Overcurrent
(27TN) #1 Third Harmonic Undervoltage
(67NIT) Residual Inverse Overcurrent
(27TN) #2 Third Harmonic Undervoltage
(32) #1 Directional Power (78) Out of Step
(32) #2 Directional Power (81) #1 Frequency
(32) #3 Directional Power (81) #2 Frequency
(40) #1 Loss of Field (81) #3 Frequency
(40) #2 Loss of Field (81) #4 Frequency
(40VC) #1 Loss of Field with VC (81A) #1 Freq Accumulator
(40VC) #2 Loss of Field with VC (81A) #2 Freq Accumulator
(46DT) Neg. Seq. Overcurrent DEF (81A) #3 Freq Accumulator
(46IT) Neg. Seq. Overcurrent INV (81A) #4 Freq Accumulator
(49) #1 Stator Overload (81A) #5 Freq Accumulator
(49) #2 Stator Overload (81A) #6 Freq Accumulator
(50BF) Breaker Failure (81R) #1Rate of Change of Frequency
(50) #1 Phase Overcurrent (81R) #2 Rate of Change of Frequency

3
(50) #1 Phase Overcurrent (87) #1 Phase Differential Current
(50) #2 Phase Overcurrent (87) #2 Phase Differential Current
(50N) Instant. Neutral Overcurrent (87GD) Ground Differential Current
(50DT) #1 Time Overcurrent (IPSL) #1 IPS LOGIC
(50DT) #2 Time Overcurrent (IPSL) #2 IPS LOGIC
(50/27) Inadvertent Energizing (IPSL) #3 IPS LOGIC
(51N) Inv. Time Neu. Overcurrent (IPSL) #4 IPS LOGIC
(51V) Inv. Time Phase Overcurrent (IPSL) #5 IPS LOGIC
(59) #1 Phase Overvoltage (IPSL) #6 IPS LOGIC
(59) #2 Phase Overvoltage (BM) Breaker Monitor
(59) #3 Phase Overvoltage (TC) Trip Circuit Monitor
(59D) Third Harmonic Voltage Differential

A OUTPUT 1 OUTPUT9 OUTPUT 17 INPUT 1 INPUT 7 INPUT 14

OUTPUT 2 OUTPUT 10 OUTPUT 18 INPUT 2 INPUT 8

OUTPUT 3 OUTPUT 11 OUTPUT 19 INPUT 3 INPUT 9

OUTPUT 4 OUTPUT 12 OUTPUT 20 INPUT 4 INPUT 10

OUTPUT 5 OUTPUT 13 OUTPUT 21 INPUT 5 INPUT 11
OUTPUT 6 OUTPUT 14 INPUT 6 INPUT 12
OUTPUT 22
OUTPUT 7 OUTPUT 15 INPUT FL INPUT 13
OUTPUT 23

B OUTPUT 8 OUTPUT 16

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

C 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.

4–26
 Remote Operation – 4

4.5 Cautions

System and IPScom® Compatibility Echo Cancel

Every attempt has been made to maintain
compatibility with previous software versions. In
The Echo Cancel check box, under the Comm
menu, should only be used when several relays are 1
some cases (most notably with older protection connected using a fiber optic loop network.
systems), compatibility cannot be maintained. If Otherwise, echo cancel must not be selected or
there is any question about compatibility, contact communication will be prevented.
the factory.
Serial Port Connections
System Priority If the serial port is connected to something other
System conflicts will not occur, as local commands than a modem, and an IPScom modem command
initiated from the front panel receive priority is executed, the results are unpredictable. In some
recognition. When the unit is in local mode, cases, the computer may have to be reset.
communication using the serial ports is suspended.
IPScom displays an error message to indicate this
fact.

Time and Date Stamping

Time and date stamping of events is only as useful
as the validity of the unit’s internal clock. Under the
Relay menu, the Set Date/TIme command allows 3
you to manually set the unit’s clock.

4–27
 M-3425A Instruction Book

4.6 Keyboard Shortcuts

1
Keyboard Shortcuts
SYSTEM 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.

3 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 A character key To choose the menu or command. The underlined character matches
the 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.

B Alt-a character key To move to the option or group whose underlined letter or number
matches 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 or

clear a check box.

C Enter

Esc or Alt-F4
To carry out a command.

To close a dialog box without completing the command.

Table 4-2 Microsoft Windows Keyboard Shortcuts

4–28
 Remote Operation – 4

4.7 IPSutil™ Communications Software

IPSutility ( Relay M-3425A D-00XX VX.XX.XX )

Comm Relay Comm Ethernet Clock Security Miscellaneous Help 1
Window Miscellaneous

Setup
Monitor Status
RelayComm Ethernet Calibration

Comm Help

Connect About...
Exit Alt+F4

3
Clock

Security
A
Change Comm Access Code
Change Access Level Code

Figure 4-36 IPSutil Main Menu Flow

B
M-3890 IPSutil Installation and Setup
The M-3890 IPSutil Communication software package IPSutil runs with the Microsoft® Windows 95 operating
provides communication with the Beckwith Integrated system or above. Hardware requirements are the
Protection System® (IPS) for setting up the relays. same as those stated for IPScom®.
Its main purpose is to aid in setting up IPS relays
that are ordered without the optional front panel HMI
interface.
C

4–29
 M-3425A Instruction Book

Installation • Select the access code resident in the

An installation utility has been provided as a part of relay. Factory default is 9999.
IPScom® and IPSutil™ programs. After installation, • Select “Open com”.
IPSutil can be run from the hard drive by choosing
1 IPSUTIL.EXE. The following message window will be displayed
showing COM opened. Now, the title bar will display
System Setup the relay model and the software version.
Connect a null modem cable from COM1 of the
relay to the PC serial port. IPSutil supports COM1 IPSutility X

port direct connection only. Modem connection is M-3425A

not supported. IPSutil is not supported through COM Opened

COM2 or COM3 ports of the relay.

OK

Overview
The Exit submenu allows you to quit IPSutil. If the
IPSutil helps in setting up IPS relays which were relay was connected, this submenu disconnects
ordered without the optional front panel HMI interface. the relay. When the relay was connected, if you
Units delivered without HMI’s are shipped with a set have made any changes for some parameters (for
of factory default settings for various parameters example, baud rate, phase rotation) the following
that the end user may wish to change. While the message window appears.
utility program is directed to users that do not have
HMI, users of HMI-provided relays can also use IPSUTILITY X

3 IPSutil to set various parameters. When IPSutil is

started, a warning window appears:
Some parameter’s changes require resetting the relay to become effective. Do you wish
to reset the relay now?

OK Cancel
WARNING X

IPSutility should NOT be used to set up the relay which is on-line because some
parameter’s modifications may result in unexpected operations. It is only for off-line relay
setup. Figure 4-38 IPSutility Reset Relay Message
OK
Relay Comm Command

A Figure 4-37 Warning Message When Relay Comm command is selected, the
Relay Comm Port Settings dialog box appears (See
Figure 4-42). It allows you to set the relay
After the user accepts the warning, the user can
access the IPSutil main menu. The following sections communication ports COM1 or COM2/COM3 baud
describe each IPSutil menu items. rate. For COM2/COM3, it allows you to set the
protocol and dead synch time. Additionally, for
COM2 and COM3, if you select MODBUS protocol,
Comm Menu
the dialog box allows you to enable the parity
Comm option.

B Connect
Exit Alt+F4
■ NOTE: If COM1 baud rate is changed and the
relay is reset, the new baud rate must be
used to communicate with COM1
The Comm menu allows the user to make
connections to the relay. This is the first command Ethernet Command
the user must use to access the unit. After the user
selects the Connect submenu item, the When the Ethernet command is selected, the
Communications dialog box appears (See Figure Ethernet Settings dialog box appears (see Figure
4-41). 4-43.) This command allows the user to enable or

C • Select the correct PC communication port

where the null modem cable is connected
disable the ethernet connection and enable/set
protocols.

for the relay. Clock Command

• Select the baud rate of the relay. Factory When the Clock command is selected, the “Set
default is 9600 baud. Unit Date/Time” dialog box appears (See Figure
4-44). Date and Time can be changed and sent to
the relay. This dialog box allows you to start or stop
the clock in the relay.
4–30
 Remote Operation – 4

Security Menu Monitor Status X

Error Codes Counters

Security Clear

OUT1: 147 OUT13: 0

Last Selftest: 45
Change Comm Access Code OUT2: 110 OUT14: 0

1
Last Selftest-1: 28

Change Level Access Code Last Selftest-2: 0

OUT3: 8 OUT15: 0

OUT4: 0 OUT16: 0
Last Selftest-3: 0
The Security Menu allows you to set the Last Comm: 4112
OUT5: 18 OUT17:
0

communication access code and the level access Receive Packet: 24

OUT6: 22 OUT18:
0
codes for the relay. OUT7: 27 OUT19:
0
Checksums
OUT8: 7 OUT21: 0
Calibration: 94 Setpoints: 10
The Change Comm Access Code allows you to Alarm: 0 OUT 22: 0
assign new communication access code to the Input Test Indicator
Powerloss: 42 OUT23: 0
relay. The range of the access code is 1 to 9999. 6 5 4 3 2 1
Open
Note that the access code 9999 is a factory default Close
Clear Counters (OUT1-OUT23):
Alarm: Clear Alarm
(See Figure 4-45). Extended Input Test Indicator Powerloss:
14 13 12 11 10 9 8 7
■ NOTE: Setting the access code to 9999 disables Open
Close
security.
OK Cancel

The Change User Access Code allows you to

assign three different levels of access code for the Figure 4-39 Monitor Status Screen
relay functions accessibility. The range of the level
access code is 1 to 9999 (See Figure 4-46).
▲ CAUTION: This submenu allows you to change
the relay level access codes.
The Calibration command provides the user with
instructions to recalibrate Nominal Frequency, Third
Harmonic, (64F) Field Ground, and (64S) Stator
3
Protection.
Miscellaneous Menu Calibration X

Miscellaneous Select Calibration Procedures

Setup Nominal Frequency Connect VN=VX=10.0 (+/- 0.01) and

VA=VB=VC=120.0 VAC at 180 Hz,
Monitor Status Third Harmonic 0 deg phase. Press Calibrate when ready.

Calibration

The Miscellaneous menu allows you to set and

64F Field Ground
64S Stator Protection A
monitor some of the relay parameters. Calibrate Cancel

The Setup command allows you to change the

users Logo information, test outputs, assign Figure 4-40 Calibration Dialog
communication address and user control number,
phase rotation, OK LED flash mode in the relay.
Note that the highest number used for the COMMAND BUTTONS
communication address is 255 and the highest
control number allowed is 9999 (See Figure 4-47).
Calibrate Sends the currently
information to the relay.
displayed
B
The Monitor Status command allows you to monitor Cancel Returns you to the IPSutil main window.
and clear the error code counters, monitor the check
sums, and to view inputs test status. Note that
powerloss counter cannot be cleared.

4–31
 M-3425A Instruction Book

Help Menu Ethernet Settings X

Ethernet: Enable Disable

Help
TCP/IP SETTINGS
About...

1
DHCP Protocol: Enable Disable

IP Address: 192 168 1 43

Under Help, the About... submenu provides you
Net Mask: 255 255 255 0
the information on the IPSUtil™ version numbers.
Gateway: 0 0 0 0

EGD Protocol: Enable Disable

COMM X Protocol Selection: MODBUS Serconv

Save Cancel
PC Port Baud Rate Open COM
COM1
300 600

Access Code
1200 2400 Close COM
Figure 4-43 Ethernet Settings
4800 9600
Cancel

COMMAND BUTTONS
Ethernet Enable/Disable: Allows user to enable
Figure 4-41 Communication Dialog and disable the Ehternet Port.
DHCP Protocol Enable/Disable: Allows the user
COMMAND BUTTONS to enable or disable the DHCP protocol. When
Open COM Initiates communication with the DHCP protocol is enabled the the IP Address portion
3 protective system by direct serial
communication.
of the screen is grayed out. When DHCP protocol is
disabled the IP Address can be manually entered.
Close COM Discontinues communication with the
EGD Protocol Enable/Disable: Not available.
protective system.
Cancel Returns you to the IPSutil main window. Protocol Selection MODBUS/Serconv: Provides
Any changes to the displayed the user with the ability to select either MODBUS
information are lost. over TCP/IP or Serconv (BECO2200 over TCP\IP)
protocol.
Relay Comm Port Settings X

A COM1 Baud Rate:

Communication Address:
9600

1
COM2 Baud Rate: 9600
Save
Cancel
Saves values to the relay.
Returns you to the IPSutil main window.
Any changes to the displayed
COM2 COM3
Beco 2200 MODBUS Beco 2200 MODBUS
information are lost.
Dead Sync Time: 50 ms Dead Sync Time: 50 ms

1 ms 3000 ms 1 ms 3000 ms

Parity: None Even Odd Parity: None Even Odd

Stop Bit: 1 Bit 2 Bits Stop Bit: 1 Bit 2 Bits

B Figure 4-42
OK Cancel

Relay Comm Port Settings

SET UNIT DATE/TIME

TIME SYNC

Stop Clock
COMMAND BUTTONS
Date: 12 / 15 / 98
OK Sends the currently displayed
information to the relay.
Cancel Returns you to the IPSutil main window. Time: 20 : 01 : 01

C Any changes to the displayed

information are lost.
Save Cancel

Figure 4-44 Set Unit Date/Time Dialog Box

4–32
 Remote Operation – 4

COMMAND BUTTONS Change User Access Code X

Stop Clock This toggles between start/stop the clock

of the relay. The ‘Stop’ stops the clock in Level 1 Level 2 Level 3
the relay. The ‘Start’ resumes the clock

1
New User Access Code: xxxx xxxx xxxx
in the relay.
Save When connected to the protection Confirm New User Access Code: xxxx xxxx xxxx
system, the date and time information
on the display is sent to the relay.
Cancel Returns you to the IPSutil™ main OK Cancel
window. Any changes to the displayed
information are lost.
There is a blue Time Sync LED mimic on the Set Date/
Time dialog box (the LED is displayed as different
Figure 4-46 Change User Access Code
shading on a monochrome monitor). When this LED is Dialog Box
blue, the relay is synchronized with the IRIG-B signal
and the Time field is grayed out, indicating that this field
can’t be changed. But the Date field can be changed COMMAND BUTTONS
(by editing and pressing Save). When the LED is not
OK Sends the currently displayed
blue, the relay is not time-synchronized and therefore,
information to the relay.
both the Date and Time fields can be changed. The
time field in the dialog box is not updated continuously. Cancel Returns you to the IPSutil main window.
The time at which the dialog box was opened is the Any changes to the displayed
time that is displayed and remains as such. This is true information are lost.
whether the relay is synchronized with the IRIG-B signal
or not. Setup
User Logo
X 3
Line1: BECKWITH ELECTRIC CO.
Change Comm Access Code X
Line2: M-3425A

Output Test (Relay)

8 7 6 5 4 3 2 1
New Access Code: xxxx
OFF
ON
Confirm New Access Code: xxxx

A
Output Test (Relay) Extended
23 22 21 20 19 18 17 16 15 14 13 12 11 10 9
OFF
ON
OK Cancel
User Control Number: 1

OK LED Flash: Enable Disable

Phase Rotation: ABC ACB
Figure 4-45 Change Communication Access OK Cancel
Code Dialog Box
Figure 4-47 Setup Dialog Box
COMMAND BUTTONS
OK Sends the currently displayed COMMAND BUTTONS
B
information to the relay. OK Sends the currently displayed
Cancel Returns you to the IPSutil™ main information to the relay.
window. Any changes to the displayed Cancel Returns you to the IPSutil main window.
information are lost. Any changes to the displayed
information are lost.
■ NOTE: Output Test is not available on some
versions of the M-3425A Relay.
C

4–33
 M-3425A Instruction Book

3
This Page Left Intentionally Blank

4–34
 Legal Information
Patent Indemnification
The Seller shall not be liable for any property
The units described in this manual are covered by damages whatsoever or for any loss or damage
U.S. Patents, with other patents pending. arising out of, connected with, or resulting from
Buyer shall hold harmless and indemnify the Seller, this contract, or from the performance or breach
its directors, officers, agents, and employees from thereof, or from all services covered by or furnished
any and all costs and expense, damage or loss, under this contract.
resulting from any alleged infringementof United In no event shall the Seller be liable for special,
States Letters Patent or rights accruing thereform or incidental, exemplary, or consequential damages,
trademarks, whether federal, state, or common law, including but not limited to, loss of profits or
arising from the Seller’s compliance with Buyer’s revenue, loss of use of the equipment or any
designs, specifications, or instructions. associated equipment, cost of capital, cost of
purchased power, cost of substitute equipment,
facilities or services, downtime costs, or claims or

Warranty damages of customers or employees of the Buyer

for such damages, regardless of whether said claim
or damages is based on contract, warranty, tort
Seller hereby warrants that the goods which are the including negligence, or otherwise.
subject matter of this contract will be manufactured
Under no circumstances shall the Seller be liable
in a good workmanlike manner and all materials
for any personal injury whatsoever.
used herein will be new and reasonably suitable for
the equipment. Seller warrants that if, during a It is agreed that when the equipment furnished
period of five years from date of shipment of the hereunder are to be used or performed in connec-
equipment, the equipment rendered shall be found tion with any nuclear installation, facility, or
by the Buyer to be faulty or shall fail to peform in activity, Seller shall have no liability for any
accordance with Seller’s specifications of the nuclear damage, personal injury, property damage,
product, Seller shall at his expense correct the or nuclear contamination to any property located at
same, provided, however, that Buyers shall ship the or near the site of the nuclear facility. Buyer agrees
equipment prepaid to Seller’s facility. The Seller’s to indemnify and hold harmless the Seller against
responsibility hereunder shall be limited to replace- any and all liability associated therewith whatso-
ment value of the equipment furnished under this ever whether based on contract, tort, or otherwise.
contract. Nuclear installation or facility means any nuclear
reactor and includes the site on which any of the
Seller makes no warranties expressed or implied
foregoing is located, all operations conducted on
other than those set out above. Seller specifically
such site, and all premises used for such opera-
excludes the implied warranties of merchantibility
tions.
and fitness for a particular purpose. There are no
warranties which extend beyond the description
contained herein. In no event shall Seller be liable for
consequential, exemplary, or punitive damages of
Notice:
whatever nature. Any illustrations and descriptions by Beckwith
Any equipment returned for repair must be sent Electric Co., Inc. are for the sole purpose of
with transportation charges prepaid. The equipment identification.
must remain the property of the Buyer. The afore- The drawings and/or specifications enclosed herein
mentioned warranties are void if the value of the are the proprietary property of Beckwith Electric
unit is invoiced to the Seller at the time of return. Co., Inc., and are issued in strict confidence;
therefore, shall not be used as a basis of reproduc-
tion of the apparatus described therein without
written permission of Beckwith Electric Co., Inc.
No illustration or description contained herein
shall be construed as an express warranty of
affirmation, promise, description, or sample, and
any and all such express warranties are specifically
excluded nor shall such illustration or description
imply a warranty that the product is merchantable
or fit for a particular purpose. There shall be no
warranties which extend beyond those contained in
the Beckwith Electric Co., Inc. terms of sale.

All rights reserved by Beckwith Electric Co., Inc. No reproduction may be made without prior written approval
of the Company.
 0
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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) 546-0121
E-MAIL marketing@beckwithelectric.com
WEB PAGE www.beckwithelectric.com

© 2004 Beckwith Electric Co.

Printed in USA 800-3425A-IB-01MC6 01/06