BECKWITH ELECTRIC M-3425A Instruction Book

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Page 1

Instruction Book

Part 1 of 2

M-3425A Generator Protection

Page 2

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 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

Communications Software provides simple and logical

• 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)

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M-3425A Generator Protection Relay

Protective Functions

Base Package

• Overexcitation (V/Hz) (24)

• Phase Undervoltage (27)

• Directional power sensitive triple-setpoint Reverse Power, Low Forward Power or Overpower detection, one of which can be used for sequential tripping (32)

• Dual-zone, offset-mho Loss of Field (40), which may be applied with undervoltage controlled accelerated tripping

• Sensitive Negative Sequence Overcurrent protection and alarm (46)

• Instantaneous Phase Overcurrent (50)

• Inadvertent Energizing (50/27)

• Generator Breaker Failure (50BF)

• Instantaneous Neutral Overcurrent (50N)

• Inverse Time Neutral Overcurrent (51N)

• Three-phase Inverse Time Overcurrent (51V) with voltage control and voltage restraint.

• Phase Overvoltage (59)

• Neutral Overvoltage (59N)

• Multi-purpose Overvoltage (59X)

• VT Fuse-Loss Detection and blocking (60FL)

• Residual Directional Overcurrent (67N)

• Four-step Over/Underfrequency (81)

• Phase Differential Current (87)

• Ground (zero sequence) Differential Current (87GD)

• IPSlogicTM takes the contact input status and function status and generates outputs by employing (OR, AND, and NOT) boolean logic and a timer.

Protective Functions

Comprehensive Package

The Comprehensive Package includes all Base Package functions, as well as the following:

• Three-zone Phase Distance protection for phase fault backup protection (21). Zone three can be used for Out-of-Step Blocking. Load encroachment blinders can be applied.

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

• Stator Overload (49) (Positive Sequence Overcurrent)

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

• Out-of-Step (78)

• UnderFrequency Accumulation (81A)

• Rate of Change of Frequency (81R)

Optional Protective Functions

• Sync Check with Phase Angle, ΔV and ΔF

with dead line/dead bus options (25)

• Field Ground (64F) and Brush Lift Off (64B) (Includes M-3921 Field Ground Coupler)

• 100% Stator Ground protection by low frequency injection (64S). The following equipment is supplied with the 64S option:

– 20 Hz signal generator (430-00426) – Band-pass Filter (430-00429)

Standard Features

• Eight programmable outputs and six programmable inputs

• Oscillographic recording with COMTRADE or BECO format

• Time-stamped target storage for 32 events

• Metering of all measured parameters and calculated values

• Three communications ports (two RS-232 and one RS-485)

• M-3820D IPScom® Communications Software

• Includes MODBUS and BECO 2200 protocols

• Standard 19" rack-mount design (vertical mounting available)

• Removable printed circuit board and power supply

• 50 and 60 Hz models available

• Both 1A and 5 A rated CT inputs available

• Additional trip inputs for externally connected devices

• IRIG-B time synchronization

• Operating Temperature: –20° C to +70° C

• Sequence of Events Log

• Trip Circuit Monitoring

• Breaker Monitoring

• Four Setpoint Groups

Optional Features

• Redundant power supply

• M-3925A Target Module

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

• RJ45 Ethernet port utilizing MODBUS over TCP/IP and BECO2200 over TCP/IP protocols

• M-3801D IPSplot® sis Software

• Expanded I/O (15 additional outputs and 8 additional inputs)

PLUS

Oscillograph Analy-

–2–

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PROTECTIVE FUNCTIONS

M-3425A Generator Protection Relay

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%

(–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

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

Pickup #1, #2, #3 5 to 180 V 1 V 0.5 V or 0.5%

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

†

Select the greater of these accuracy values.

Values in parentheses apply to 1 A CT secondary rating.

–3–

20 cycles or 1%.

0.8 V or 0.75%*

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M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (

Device Setpoint Number Function Ranges Increment Accuracy

cont

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 1 V 0.5 V or 0.5%

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

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

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

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

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

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

High Band 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%

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%

Offset #1, #2 –50.0 to 50.0 Ω 0.1 Ω 0.1 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 1 V 0.5 V or 0.5% (positive sequence)

Directional Element 0° to 20° 1° —

(0.5 to 500.0 Ω)(0.5 Ω or 5%)

(–250.0 to 250.0 Ω)(0.5 Ω or 5%)

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–

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M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (

Device Setpoint Number Function Ranges Increment Accuracy

cont

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

Time Dial Setting 1 to 95 1 3 Cycles or 3%

(K= I

(0.5% of 1 A)

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

Maximum Overload Current 1.00 to 10.00 A 0.01 A 0.1 A or 2%

(0.20 to 2.00 A)

†

Instantaneous Phase Overcurrent

Pickup #1, #2 0.1 to 240.0 A 0.1 A 0.1 A or 3%

(0.1 to 48.0 A) (0.02 A or 3%)

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

When frequency f is < (f

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

nom

Breaker Failure

Pickup

Phase Current 0.10 to 10.00 A 0.01 A 0.1 A or 2%

BF-Ph

Neutral Current 0.10 to 10.00 A 0.01 A 0.1 A or 2%

BF-N

(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%

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

(0.04 A to 48.00 A) (0.02 A or 3%)

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 I

†

Select the greater of these accuracy values.

, IB and IC inputs must be connected to the split phase differential currents.

Values in parentheses apply to 1 A CT secondary rating.

–5–

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M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (

Device Setpoint Number Function Ranges Increment Accuracy

cont

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 < (f

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

nom

Inadvertent Energizing

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%)

Undervoltage

Pickup 5 to 130 V 1 V 0.5 V

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

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

Inverse Time Neutral Overcurrent

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

51N

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

Time Dial 0.5 to 11.0 0.1 3 Cycles or 3%*

* For IEC Curves the timing accuracy is 5%.

When the frequency f is < (f

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

nom

Inverse Time Phase Overcurrent, with Voltage Control or Voltage Restraint

(0.05 to 2.40 A) (0.02 A or 1%)

Moderately Inverse/Very Inverse/Extremely Inverse/IEEE Curves

0.05 to 1.10 (IEC curves) 0.01

0.85 to 1.15 (IEEE curves) 0.01

†

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 1 V 0.5 V or 0.5%

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–

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M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (

Device Setpoint Number Function Ranges Increment Accuracy

cont

†

Phase Overvoltage

Pickup #1, #2, #3 5 to 180 V 1 V 0.5 V or 0.5%

0.8 V or 0.75%*

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

Input Voltage Select Phase 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

59D

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

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

Line Side Voltage V

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 3V

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

(equivalent to VA + VB + VC) or VX.

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 logic, and/or from input contacts.

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–

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M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (

Device Setpoint Number Function Ranges Increment Accuracy

cont

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 3V

(calculated), VN or V

*Directional control for 67NDT or 67NIT may be disabled. V

polarization cannot be used if 25 function is enabled.

polarization can only be used with line-ground VT configuration.

Operating current for 67N can be selected as 3

If 87GD is enabled, 67N with

(Residual CT) operating current will not be available.

(calculated) or

(Residual CT).

Out of Step (mho characteristic)

†

Circle Diameter 0.1 to 100.0 Ω 0.1 Ω 0.1 Ω or 5%

(0.5 to 500.0 Ω)(0.5 Ω or 5%)

Offset –100.0 to 100.0 Ω 0.1 Ω 0.1 Ω or 5%

(–500.0 to 500.0 Ω)(0.5 Ω or 5%)

Impedance Angle 0° to 90° 1° 1°

Blinder 0.1 to 50.0 Ω 0.1 Ω 0.1 Ω or 5%

(0.5 to 250.0 Ω)(0.5 Ω or 5%)

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*

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–

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M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (

Device Setpoint Number Function Ranges Increment Accuracy

Frequency AccumulationFrequency Accumulation

Frequency Accumulation

Frequency AccumulationFrequency Accumulation

cont

†

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

* This range applies to 50 Hz nominal frequency models.



0.1 Hz.

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%)

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

Ground (zero sequence) Differential Current

Pickup 0.20 to 10.00 A 0.01 A 0.1 A or 5%

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

CT Ratio Correction (R

(0.04 to 2.00 A) (0.02 A or 5%)

) 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 3 becomes non-directional.

If 67N function with split-phase differential, 87GD function will not be available.

(Residual) operating current is enabled, 87GD will not be available. Also, if 50DT is used for

is extremely small (less than 0.2 secondary Amps), the element

†

Select the greater of these accuracy values.

Values in parentheses apply to 1 A CT secondary rating.

–9–

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M-3425A Generator Protection Relay

PROTECTIVE FUNCTIONS (

Device Setpoint Number Function Ranges Increment Accuracy

IPSlogic

cont

†

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

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

or kA

Cycles or kA2 Cycles or kA2 Cycles

Timing Method IT or I2T

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

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–

Page 12

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 1 V 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 1 V 0.5 V or ±0.5%

Lower Voltage Limit 40 to 120 V 1 V 0.5 V or ±0.5% Delta Voltage Limit 1.0 to 50.0 V 0.1 V 0.5 V or ±0.5% Delta Frequency Limit 0.001 to 0.500 Hz 0.001 Hz 0.0007 Hz or ±5%

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

Various combinations of input supervised hot/dead closing schemes may be selected. The 25 function cannot be enabled if the 59D function with V

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 (

+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 (

+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 1 V 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–

Page 13

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–

Page 14

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

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.

: Uses Discrete Fourier Transform algorithm on sampled voltage and current

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

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

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.

: Rated for a nominal voltage of 50 V ac to 140 V ac at 60 Hz or 50 Hz. Will withstand 240

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

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–

Page 15

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–

Page 16

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

IN X

Alarm/Trip

IN RTN

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–

Page 17

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–

Page 18

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–

Page 19

M-3425A Generator Protection Relay

3433

3130 32

22 24

50 Hz 60 Hz SERIA L NO .

MODEL: M-3425A FIRMWARE: D-0150

10 11

FOR CONTACT RATINGS SEE INSTRUCTION MANUAL

WA RNING! C ONT AC T WITH TERMINAL S MAY CAUSE ELECT RIC SHOCK

727- 544 - 232 6

LARGO, FL 33773

6190 118th AVE NO.

BECKWITH ELECTRIC CO. INC.

NRTL/ C

LR 89464

83F4

LISTED

IND.CONT .EQ

RS2 32

COM 2

COM2

IRIG- B

4824250

ETHERNET

OUTPUTS

SELF-TEST

ALARMS

P/ S

RTN

(52b)

INPUTS

RS485

COM 3

AUX

125

PS1

PS2

3AMP,250V(3AB)3AMP,250V(3AB)

COUPLER

1-85

65-18 6

54 55 57

64S

4545

44444444

43434343

42424242

40404040 41414141

39393939

37373737 38383838

36363636

35353535

S P1

2PS

D N G

LDFI E

5 685 2

55268

0.01A NOM

64F

RATED C URRENT

1A,NOM 5 A,NOM

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

RATED VOLTAGE

60-140VAC,50/60Hz

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.

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,

■■

■ NOTES:

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.

8 WARNING: The protective grounding terminal must be connected to an earthed ground any time external connections have been

made to the unit.

–18–

Page 20

M-3425A Generator Protection Relay

RTN

IN IN IN IN INININ IN

INPUTS

RS2 32

COM 2

ETHERNET

COM 2

727- 544- 2326

6190 118th AVE NO.

LARGO, FL 33773

BECKWITH ELECTRIC CO. INC.

WA RNING! C ONT AC T WIT H T ERMINAL S MAY CA USE ELE CT RIC S HOC K

FOR CONTACT RATINGS SEE INSTRUCTION MANUAL

9695 97 9998

P/ S

36363636

35353535

44444444

40404040

3838383837373737

39393939

42424242

41414141

43434343

4545

COUPLER

D E

IFL

IRIG- B

AUX

N GD

RS485

COM 3

(52b)

INPUTS

IN IN

RTN

3AMP,250V(3AB)3AMP,250V(3AB)

PS2

SELF- TEST

ALARMS

OUTPUTS

SP2

OUTPUTS

1SP

PS1

101

100

102

104

103

105

125

250

0.01A NOM

64S

856

5 26

RATED VOLTAGE

60-140VAC,50/60Hz

MODEL: M-3425A FIRMWARE: D-0150

50 Hz 6 0Hz SERIAL NO.

1A ,N O M

RATED C URRENT

5A,NOM

64F

.QE.TNOC.DNI

DETSIL

CUS

83F4

hes and Jumpers,

he unit is configured

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

8 WARNING: ONLY DRY CONTACTS must be connected to inputs (terminals 5 through 10 with 11 common and terminals 68 through

to may result in mis-operation or permanent damage to the unit.

for the information regarding setting Trip Circuit Monitoring input voltage. Connecting a voltage other than the voltage that t

2. Before making connections to the Trip Circuit Monitoring input, see M-3425A Instruction Book Section 5.5, Circuit Board Switc

1. See M-3425A Instruction Book Section 2.3, Setpoints and Time Settings, subsection for 64B/F Field Ground Protection.

■■

■ NOTES:

made to the unit.

8 WARNING: The protective grounding terminal must be connected to an earthed ground any time external connections have been

result in damage to the units.

75 with 66 and 67 common) because these contact inputs are internally wetted. Application of external voltage on these inputs m

–19–

Page 21

M-3425A Generator Protection Relay

M-3425A

Targets

(Optional)

Integral HMI

(Optional)

Metering

Waveform Capture

IRIG-B

Front RS232

Communication

Rear RS232

Communication

Rear Ethernet

Port (Optional)

Rear RS-485

Communication

Multiple Setting

Groups

Programmable I/O

Self Diagnostics

Dual Power Supply

(Optional)

Breaker

Monitoring

Trip Circuit

Monitoring

Event Log

3VO (Calculated)

59D Line Side

Voltage

(Software Select)

M-3425A Typical Connection Diagram

3VO (Calculated)

67N Po lari zati on

(Software Select)

59D

These functions are available in the Comprehensive Package. A subset of these functions are also available in a Base Package.

This function is available as a optional protective function.

This function provides control for the function to which it points.

BFPh

81R 81 27 59 24

81A

(Note 3)

59X

51V 50/27

67N Operating Current

(Software Select)

64S

59N

67N

BFN

(Metering)

492132 504078

64F 64B

50N

51N

(Note 5)

50N

51N

(Metering)

Utility System

Unit

VT (Note 1)

CT (Residual)

Gen

VT (Note 1)

M-3921

(Note 4)

CT (Neutral)

(Notes 2 & 5)

High-impedance Grounding with Third Harmonic 100% Ground Fault Protection

Low-impedance Grounding with Ground Differential 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–

Page 22

M-3425A Generator Protection Relay

M-3425A

Targets

(Optional)

Integral HMI

(Optional)

Metering

Waveform Capture

IRIG-B

Front RS232

Communication

Rear RS232

Communication

Rear Ethernet

Port (Optional)

Rear RS-485

Communication

Multiple Setting

Groups

Programmable I/O

M-3425A Typical Connection Diagram

(Configured for Split-Phase Differentia l)

81R 81 59 27 24

81A

These functions are available in the Comprehensive Package. A subset of these functions are also

Utility System

available in a Base Package.

This function is available as a optional protective function.

Unit

This function provides control for the function to which it points.

VT (Note 1)

CT (Residual)

(Note 5)

(Metering)

(Note 2)

59X

64F 64B

CT (Note 3)

M-3921

VT (Note 1)

Gen

Self Diagnostics

Dual Po wer Supply

(Optional)

Breaker

Monitoring

Trip Circuit

Monitoring

Event Log

59D Line Side

Voltage

(Software Select)

3VO (Calculated)

67N Polarization

(Software Select)

3VO (Calculated)

59D

64S 59N

High-impedance Grounding with Third Harmonic 100% Ground Fault Protection

46492132 504078 60FL 51V 50/27

(Metering)

(Note 4)

67N

50N 51N

Low-impedance Grounding with 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.

CT (Neutral)

(Note 5)

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

–21–

Page 23

M-3425A Generator Protection Relay

Rear View

17.48 [44.4] ACTUAL

5.21 [13.23] ACTUAL

10.20 [25.91]

19.00

[48.26]

19.00 [48.26]

18.34 [46.58]

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).

0.33

[0.84]

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

2.35 [5.96]

1.35 [3.42]

–22–

Page 24

10.20 [25.9]

M-3425A Generator Protection Relay

6.96

[17.68]

4.00

[10.16]

1.48

3.76

0.33

[0.84]

19.00

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

11910 121314

RELAY

COM 1

BRKR

CLOSED

TIME

OSC.

SYNC

TRIG

TARGET

PS 1

RESET

PS 2

[48.26]

OUTPUTS

17 1918 20 21 22 23

TARGET

M-3425A

GENERATOR PROTECTION

KCEWI

ECELT

Made in U.S.A.

OINC..C

EXIT

18.34

[46.58]

ENTER

OUTPUTS

OUT 1

OUT 3

OUT 2

OUT 5

OUT 4

OUT 6

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

OUT 7 OUT 8

–23–

Page 25

M-3425A Generator Protection Relay

5.65

[13.41]

19.00

[48.26]

0.40 [1.02] x

0.27 [0.68] SLOT (4x)

0.33

[0.84]

18.34

[46.58]

2.25

[5.72]

5.59

[14.20]

ACTUAL

1.71

[4.34]

17.5

[44.45]

17.31

[43.97]

Actual

n NOTE: Dimensions in brackets are in centimeters.

RECOMMENDED CUTOUT WHEN

Rear View

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–

Page 26

5.28

[13.40]

.34

[.86]

1.48

[3.76]

2.25

[5.72]

18.34

[46.17]

17.50

[44.45]

RECOMMENDED CUTOUT

STANDARD 3 UNIT PANEL M-3425A

M-3425A Generator Protection Relay

\U+2205.28 (4X)

7.03

[17.86]

.34

[.86]

1.48

[3.76]

4.00

[10.16]

18.34

[46.17]

17.50

[44.45]

RECOMMENDED CUTOUT

4 UNIT PANEL M-3425A (EXTENDED I/O)

TOLERANCE: .XX±.015

Figure 9 M-3425A Panel Mount Cutout Dimensions

\U+2205.28 (4X)

–25–

Page 27

M-3425A Generator Protection Relay

M-3921 Field Ground Coupler

PROTECTION RELAY

M-3425A

PROCESSOR

Excitation

System

Field Ground

Detection

Squarewave

Generator

Signal

Measurement

and Processing

COUPLING NETWORK

(M-3921)

Gen. Rotor

Ground/Machine Frame

Brushes

Ground

Shaft

Brush

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 (V

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.

) and measures return signal (Vf) to calculate Rf.

out

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–

Page 28

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–

Page 29

7.87 [19.99]

2.96 REF [7.52]

3.54 [9.0]

4.72 [11.99]

.18 DIA [0.46] 4 X

3.54 [9.0]

M-3921

Field Ground

Coupler

BECKWITH

CO. I NC.

ELECTRIC

Made in U.S.A.

9.06 [23.01]

.18 DIA [0.46] 4 HOLES

7.40

[18.79]

MOUNTING PATTERN

WITHOUT TABS

nNOTE: Dimensions in brackets are in centimeters.

Figure 11 M-3921 Field Ground Coupler Mounting Dimensions

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

BECKWITH ELECTRIC CO., INC.

PHONE (727) 544-2326 • FAX (727) 546-0121

E-MAIL [email protected]

WEB PAGE www.beckwithelectric.com

800-3425A-SP-01MC5 1/06

Page 30

WARNING

DANGEROUS VOLTAGES, capable of causing death or serious

injury, are present on the external terminals and inside the equipment. Use extreme caution and follow all safety rules when handling, testing or adjusting the equipment. However, these internal voltage levels are no greater than the voltages applied to the external 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 applied. In no case may components be replaced with power applied. In some instances, dangerous voltages 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 personnel 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.

Page 31

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.

Page 32

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)

Page 33

This Page Left Intentionally Blank

Page 34

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

Page 35

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

Page 36

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

Page 37

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

Page 38

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

Page 39

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

Chapter 3

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

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

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

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

Page 40

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

Page 41

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

viii

Chapter 4

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

4-2 Microsoft Windows Keyboard Shortcuts .............................................4–28

Page 42

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

Page 43

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

Appendices

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

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

Page 44

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

Chapter 6

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

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

Page 45

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

Appendix D

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

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

xii

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

Page 46

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

Appendix D

Appendix E

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

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

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

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

800-3425A-IB-01MC6 01/06

xiii

Page 47

M-3425A Instruction Book

This Page Left Intentionally Blank

xiv

Page 48

Introduction – 1

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 Appendices.

Chapter 1: Introduction

Chapter One summarizes relay capabilities, introduces the instruction book contents, and describes accessories.

Chapter 2: Application

Chapter Two is designed for the person or group responsible for the application of the M-3425A Generator Protection Relay. It includes functional and connection diagrams for a typical application of the relay; and describes the configuration process for the unit (choosing active functions), output contact assignment and input blocking designation. It also illustrates the definition of system quantities and equipment characteristics required by the protective relay, and describes the individual function settings.

Chapter 3: Operation

Chapter Three is designed for the person(s) responsible for the operation, direct setting, and configuration of the relay. Chapter Three provides information regarding the operation and interpretation of the unit's front panel controls and indicators, including operation of the optional M-3931, Human Machine Interface (HMI) and M-3925A Target Modules. It further describes the procedures for entering all required data to the relay. Included in this chapter is a description of the process necessary for review of setpoints and timing, monitoring function status and metering quantities, viewing the target history, and setup of the oscillograph recorder.

IntroductionIntroduction

Introduction

IntroductionIntroduction

Chapter 4: Remote Operation

Chapter 4 is designed for the person or group responsible for the remote operation and setting of the relay using the M-3820D IPScom Communications Software or other means.

Chapter 5: Installation

The person or group responsible for the installation of the relay will find herein all mechanical information required for physical installation, equipment ratings, and all external connections in this chapter. For reference, the Three-Line Connection Diagram is repeated from Chapter 2, Application. Further, a commissioning checkout procedure is outlined using the HMI option to check the external CT and VT connections. Additional tests which may be desirable at the time of installation are described in Chapter 6, Testing.

Chapter 6: Testing

This chapter provides step-by-step test procedures for each function, as well as diagnostic mode and autocalibration procedures for HMI-equipped units.

Appendix A: Configuration Record Forms

This Appendix supplies a set of forms to record and document the settings required for the proper operation of the relay.

Appendix B: Communications

This Appendix describes port signals, protocols, and various topologies, and equipment required for remote communication.

1–1

Page 49

M-3425A Instruction Book

Appendix C: Self-Test Error Codes

This Appendix lists all the error codes and their definitions.

Appendix D: Inverse Time Curves

This Appendix contains a graph of the four families of Inverse Time Curves for V/Hz applications, the Inverse Time Overcurrent Curves, and the IEC curves.

Appendix E: Declaration of Conformity

This Appendix contains the Beckwith Electric Co.’s Declaration of Conformity required by ISO/IEC 17050–1:2004.

1.2 M-3425A Generator 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 relay stores time-tagged target information for the thirty-two most recent trips. For units equipped with the optional M-3925A Target Module, LEDs are used to provide a detailed visual indication of function operation for the most recent event.

The unit retains up to 472 cycles of oscillograph waveform data. This data can be downloaded and analyzed using the M-3801D IPSplot®

PLUS

Oscillograph Analysis Software.

The unit is powered from a wide input range switch mode power supply. An optional redundant power supply is available for units without the Expanded I/O. When expanded I/O option is selected, the unit includes the second power supply.

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

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

Page 50

Introduction – 1

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Communication Ports

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There are three physical communication ports provided on the M-3425A. If the optional RJ45 Ethernet port is purchased, then the relay includes four physical communication ports:

• COM1, located on the relay front panel, is a standard 9-pin RS-232 DTE-configured port. COM1 is used to locally set and interrogate the relay using a portable computer.

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• COM2, located on the rear of the relay, is a standard 9-pin RS-232 DTE-configured port. When the optional RJ45 Ethernet Port is enabled, COM2 port is disabled.

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The RJ45 Ethernet port uses a 10Base-T type connection that accepts an RJ45 connector using CAT5 twisted pair cable. The Ethernet port supports MODBUS over TCP/IP, BECO2200 over TCP/IP. The IP address can be obtained automatically when using the DHCP protocol if enabled, or a static IP address can be manually entered, using the HMI.

tniartseRrolortnoC

• COM3, located on the rear terminal block of the relay, is an RS-485 communications port.

The relay may be remotely set and interrogated utilizing either a hard-wired RS-232 serial connection or modem (COM2 when activated as RS-232, or COM3), or when purchased, the ethernet connection (RJ45 activated).

M-3820D IPScom

Communications Software

IPScom is shipped standard with every relay. This software runs on a PC-compatible computer operating under Microsoft Windows® 95 or later. When properly connected using either a direct serial connection, modem or ethernet network connection. IPScom can provide the following functions:

• Setpoint interrogation and modification

• Line status real-time monitoring

• Recorded oscillograph data downloading

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Table 1-1 M-3425A Device Functions

1–3

Page 51

M-3425A Instruction Book

1.3 Accessories

M-3925A Target Module

The optional target module, shown below, includes 24 individually labelled TARGET LEDs to indicate operation of the functions on the front panel. Eight individually labelled OUTPUT LEDs will be lit as long as the corresponding output contact is picked up.

TARGETS

24 VOLTS/Hz

27 PHASE UNDERVOLTAGE

59 PHASE OVERVOLTAGE

27TN/59D/64S STATOR GND

59N/59X NEUT/GND OVERVOLT

32 DIRECTIONAL POWER

21 PHASE DISTANCE

40 LOSS OF FIELD

78 OUT OF STEP

50BF BREAKER FAILURE

50/27INADVERTENT ENRGNG

60FL V.T. FUSE LOSS

PHASE OVERCURRENT 50

PHASE OVERCURRENT 51V

NEUTRAL O/C 50N/51N

SPLIT PHASE DIFF 50DT

STATOR OVERLOAD 49

NEG SEQ OVERCURRENT46

FIELD GND/BRUSH LIFT64F/B

FREQUENCY 81/81R/81A

PHASE DIFF CURRENT 87

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

TRIP CIRCUIT MONITOR TC

IPS LOGIC LOGIC

OUTPUTS

OUT 1

OUT 2

OUT 3

OUT 4

OUT 5

OUT 6

OUT 7

OUT 8

M-3933/M-0423 Serial Communication Cables

The M-3933 cable is a 10-foot RS-232 cable for use between the relay’s rear panel (COM2) port and a modem. This cable has a DB25 (25-pin) connector (modem) and a DB9 (9-pin) at the relay end.

The M-0423 cable is a 10-foot null-modem RS-232 cable for direct connection between a PC and the relay’s front panel COM1 port, or the rear COM2 port. This cable has a DB9 (9-pin) connector at each end.

M-3931 HMI (Human-Machine Interface) Module

The optional HMI module provides the means to interrogate the relay and to input settings, access data, etc. directly from the front of the relay. Its operation is described in detail in Section 3.1, Front Panel Controls.

BECKWITH ELECTRIC CO.

M-3425A

Figure 1-1 M-3925A Target Module

EXIT

Figure 1-2 M-3931 Human-Machine

Interface (HMI) Module

M-3801D IPSplot® Software Package

The IPSplot 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.

PLUS

Oscillograph Analysis

PLUS

Oscillograph Analysis Software

ENTER

1–4

Page 52

Application – 2

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

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

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

ApplicationApplication

Application

ApplicationApplication

Chapter Two is designed for the person or group responsible for the application of the M-3425A Generator Protection Relay. It includes functional and connection diagrams for a typical application of the relay; and describes the configuration process for the unit (enabling functions), output contact assignment and input blocking designation. It also illustrates the definition of system quantities and equipment characteristics required by the protective relay, and describes the individual function settings.

Menu screens in the following examples are as they would appear on units equipped with the M-3931 Human Machine Interface (HMI) Module. The same setting may be entered remotely using M-3820D IPScom® Communications Software (see Chapter 4, Remote Operation).

2.1 Configuration

Configuration of the relay consists of enabling the functions for use in a particular application, designating the output contacts each function will operate, and which control/status inputs will block the function. The choices include eight programmable output contacts (OUT1–OUT8) and six control/status inputs (IN1–IN6), or OUT9–23 and IN7–14 for units purchased with expanded I/O, plus a block choice for fuse loss logic operation (see Section 2.3, Setpoint and Time Settings, 60FL Fuse Loss subsection for details).

The blocking control/status inputs and output contact 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

Page 53

M-3425A Instruction Book

Control/status input IN1 is preassigned to be the 52b breaker status contact. If a multiple breaker scheme is used, the control/status input IN1 must be the series combination of the “52b” breaker contacts. Additional user-chosen control/status inputs may initiate actions such as breaker failure, initiate external fuse loss detection, or trigger the oscillograph recorder.

■ NOTE: Uppercase text indicates selection.

27#1 PHASE UNDERVOLTAGE disable ENABLE

This menu designation is required for each relay function. After enabling 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 fl i6 i5 i4 i3 i2 I1

fuse-loss logic) for the enabled function. “OR” logic is used if more than one input is selected.

This submenu item assigns the output contacts (up to eight) for the

27#1 RELAY OUTPUT o8 o7 o6 o5 o4 o3 o2 O1

particular relay function. If no output contacts are assigned, the function 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

Up to four setpoint profiles may be used. Each profile contains a complete set of function configuration and settings. One of the four profiles may be designated as the Active Profile, which will contain the settings that the relay will actively use.

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

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

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

Profile 1 is set to be the Active Profile, and all setpoints entered. An image of Profile 1 will then be copied to Profile 2 with the Copy Active Profile command. Profile 2 is then selected as the Active Profile, and the overcurrent setpoints modified.

The relay allows the user to designate up to six logic functions which perform similarly to internal relay functions, using IPSlogic

. These external functions may be enabled or disabled, and output contacts and blocking control/status inputs are chosen the same as for the internal functions. The external functions are described in further detail in Section 2.3, Setpoint and Time Settings, IPSlogic subsection.

Functions

Configuration of the relay consists of enabling the functions for use in a particular application, designating the output contacts each function will operate, and which control/status inputs will block the function. The choices include eight programmable output contacts (OUT1–OUT8) and six control/status inputs (IN1–IN6)/(OUT1–OUT23 and IN1–IN14 for expanded I/O units) plus a block choice for fuse loss logic operation (see Section 2.3, Setpoint and Time Settings, 60FL Fuse Loss subsection for details.)

Control/status inputs may also initiate actions, such as Breaker Failure Initiate, Trigger Oscillograph Recorder, Switch Setpoint Profile, or initiate an IPSlogic function. The control/status inputs and output contacts need to be chosen before configuring the individual functions. Both can be recorded on the Relay Configuration Table in Appendix A, Forms.

Special Considerations

Control/status input IN1 is preassigned to be the 52b breaker contact. IN5 and IN6 may be used to select setpoint profiles.

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

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

2–2

Page 54

Application – 2

Relay System Setup

The system setup consists of defining all pertinent information regarding the system quantities. Setup screens shown here may be accessed through the SYSTEM SETUP menu. Regardless of the functions that are enabled or disabled, all System Setup

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Table 2-1 Input Activated Profile

INPUT ACTIVATED PROFILES disable enable

ACTIVE SETPOINT PROFILE

________

COPY ACTIVE PROFILE TO_PROFILE_1 

When Input Activated Profiles is disabled, the Active Profile can be 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).

This screen sets the active setpoint profile.

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

values are required to be input. Several functions require proper setting of these values for correct operation. The Nominal Voltage and Nominal Current settings are needed for proper normalization of per unit quantities. CT and VT ratios are used only in monitoring and displaying system primary quantities.

NOMINAL VOLTAGE

________ Volts

NOMINAL CURRENT

________ Amps

VT CONFIGURATION line-line line-ground

line-gnd_to_line-line

DELTA-Y TRANSFORM dis delta_ab delta_ac

The secondary VT voltage when primary voltage is equal to the rated

generator

VT connections. V

voltage. V

nominal

=( V gen rated $ VT ratio) for L-L

nominal

=(Vgen rated $ (S3 VT ratio)) for L-G VT

connections.

The secondary CT current of the phase CT’s with rated

generator

current. I nom = (VA $ (Vgen rated(S3) )(CT ratio) )

Indicates VT connection. (See Figure 2-7, Three-Line Connection Diagram.) When line-ground voltages are used, functions 24, 27, and 59 may operate for line-ground faults. If this is not desired, the line-gnd-toline-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 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 ac) unit transformer, the relay will internally consider the 30° phase shift for 51V and 21 functions.

PHASE ROTATION a-c-b a-b-c

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

2–3

Page 55

M-3425A Instruction Book

59/27 MAGNITUDE SELECT rms dft

50DT SPLIT-PHASE DIFF disable enable

PULSE RELAY o8 o7 o6 o5 o4 o3 o2 o1

This screen allows the selection of RMS or DFT for the 59 and 27 functions. The magnitude can be selected as the RMS of the total 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, this selection should be enabled. If the 50DT function is to be used as a 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 delay expires, even if the condition which caused the relay to pick up is still out of band. When selected, latching outputs are not available.

LATCHED OUTPUTS o8 o7 o6 o5 o4 o3 o2 o1

RELAY SEAL-IN TIME OUT1

________ Cycles

ACTIVE INPUT OPEN/close I6 i5 i4 i3 i2 i1

V.T. PHASE RATIO

________ : 1

V.T. NEUTRAL RATIO

________ :1

V.T. VX RATIO

________ :1

C.T. PHASE RATIO

________ : 1

If any of the outputs are selected as latched, then after tripping, this output will stay activated, even when the tripping condition is removed. 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 seal-in, regardless of the subsequent state of the initiating function. Individual Seal-In settings are available for all outputs.*

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

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

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

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

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

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

C.T. NEUTRAL RATIO

________ : 1

2–4

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

Page 56

SETUP

Application – 2

SETUP SYSTEM

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

Nominal Voltage: 120

Nominal Current: 5.00

Input Active State:

V.T. Configuration:

59/27 Mag. Select:

Phase Rotation:

V.T. Phase Ratio:

V.T. Neutral Ratio:

V.T. VX Ratio

C.T. Phase Ratio:

C.T. Neutral Ratio:

Pulse Relay

Outputs:

Latched Outputs

Injection Frequency for F64S: 20 Hz

1 234567 8

Outputs:

50.0 V

65432 1

Open Close

Line to Ground

RMS

ABC

1.0

1234567 8

140.0 V

6.00 A0.50 A

Open Close

DFT

ACB

1.0

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

Open Close

Line to Line Line-Ground to Line-Line

50DT Split Phase Differential:

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

Enable

Disable

6550.0

65500

Delta-Y Transform

Disable

Open Close

Relay Seal-In Time

OUT 1:

Pulse Relay Expanded Outputs

Latch Relay Expanded Outputs

Delta-AB Delta-AC

Open Close

8160 cycles

2 cycles

Input Active State Expanded

Relay Seal-In Time Expanded

8160

OUT 9:

10:

11:

12:

13:

14:

15:

16:

cycles

2 cycles

OUT 17

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

■■

■ NOTE: Checking the inputs for the Active Input Open parameter designates the “operated” state established by

■■

opening

rather than a closing external contact.

main window; any changes to the displayed information are lost.

2–5

Page 57

M-3425A Instruction Book

? X

Expanded Input Active State

Open

Figure 2-2 Selection Screen for Expanded Input

Pulse Relay Expanded Outputs

OUTPUT9

OUTPUT10

OUTPUT11

OUTPUT12

OUTPUT13

OUTPUT14

OUTPUT15

OUTPUT16

OUTPUT17

OUTPUT18

OUTPUT19

OUTPUT20

OUTPUT21

OUTPUT22

OUTPUT23

Cancel

2–6

Figure 2-3 Pulse Relay Expanded Output Screen

Latch Relay Expanded Outputs

OUTPUT9

OUTPUT10

OUTPUT11

OUTPUT12

OUTPUT13

OUTPUT14

OUTPUT15

OUTPUT16

OUTPUT17

OUTPUT18

OUTPUT19

OUTPUT20

OUTPUT21

OUTPUT22

OUTPUT23

Cancel

Figure 2-4 Latch Relay Expanded Output Screen

Page 58

2.2 System Diagrams

Application – 2

M-3425A

Targets

(Optional)

Integral HMI

(Optional)

Metering

Waveform Capture

IRIG-B

Front RS232

Communication

Rear RS232

Communication

Rear Ethernet

Port (Optional)

Rear RS-485

Communication

Multiple Setting

Groups

Programmable I/O

Self Diagnostics

Dual Power Supply

(Optional)

Breaker

Monitoring

Trip Circuit Monitoring

Event Log

3VO (Calculated)

59D Line S ide

Voltage

(Software Select)

M-3425A Typical Connection Diagram

60 FL

3VO (Calculated)

67N Polari zation

(Software Sele ct)

59D

These functions are available in the Comprehensive Package. A subset of these functions are also available in a Base Package.

This function is available as a optional protective function.

This function provides control for the function to which it points.

BFPh

81R 81 27 59 24

81A

(Note 3)

59X

51V 50 /27

67N Oper ating Current

(Software Sel ect)

64S

59N

67N

BFN

50 DT

(Metering)

492132 504078

64F 64B

50N

51N

(Note 5)

50N

51N

(Metering)

Utility System

Unit

VT (Note 1 )

Gen

VT (Note 1 )

M-3921

CT (Residual)

(Note 4)

CT (Neutral)

(Notes 2 & 5 )

High-impedance Grounding with Third Harmonic 100% Ground Fault Protection

Low-impedance Grounding with Ground Differential and Overcurre nt 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

Page 59

M-3425A Instruction Book

M-3425A

Targets

(Optional)

Integral HMI

(Optional)

Metering

Waveform Capture

IRIG-B

Front RS232

Communication

Rear RS232

Communication

Rear Eth ernet

Port (Optional )

Rear RS-485

Communication

Multiple Setting

Groups

Programmable I/O

Self Diagnostics

Dual Power Supply

(Optional)

Breaker

Monitoring

Trip Circuit

Monitoring

Event Log

M-3425A Typical Connection Diagram

(Config ured for Split -Phas e Diffe rential )

81R 81 59 27 24

81A

3VO (Calculated)

67N Polarization

(Software Select)

These functions are available in the Comprehensive Package. A subset of these functions are also available in a Base Package.

This function is available as a optional protective function.

This function provides control for the function to which it points.

(Metering)

(Note 2)

59X

492132 504078 60FL 51V 50/27

(Note 4)

67N

64F 64B

(Metering)

Utility System

Unit

VT (Note 1)

Gen

CT (Note 3)

VT (Note 1)

M-3921

CT (Resid ual)

(Note 5)

3VO (Calculated)

■

NOTES:

59D L ine Side

Voltage

(Software Select)

59D

64S 59N

High-impedance Grounding with Third Harmonic 100% Ground Fault Protection

50N 51N

Low-impedance Grounding with Overcurrent Stator Ground Fault Protection

CT (Neutra l)

(Note 5)

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

Page 60

Application – 2

Generator

ABC

Gen

abc

Other

Relays

52b

Coupler Module

Other

Relays

M-3425A

M-3921

Field Ground

50 51

48 49

46 47

43 41 3942 40 38

M-3425A

58 59

56 57

54 55

Three VT Wye-Wye

Alternate Connection

Three VT Wye-Wye

Wire to split phase differential CTs for use with 50DT split phase function. Required generator breaker status input (52b). Contact is closed when generator breaker is open. Use unit breaker contact if no generator breaker present. Output contact pairs designated by user.

M-3425A

434139 424038

43 41 3942 40 38

Connection

abc

Other

Relays

M-3425A

59 58

57 56

55 54

Alarm output can be grouped to a single alarm

at the discretion of user. Available control output to service other relays

for VT Fuse Loss can be designated.

Input contact number is designated by user.

WARNING: ONLY dry contact inputs must be connected because these contact inputs are internally wetted. Application of external voltage on these inputs may result in damage to the units.

NOTE: M-3425A current terminal polarity marks

(

. ) indicate "entering" current direction when

primary current is "from" the generator to the system. If CT connections differ from those shown, adjust input terminals.

Two Vt Open-Delta

Connection

abc

Other

Relays

M-3425A

59 58

57 56

55 54

DC: 24V 48V

OR DC: 110V 125V 220V 250V AC: 110V 120V 230V 240V

M-3425A

45 44

High Impedance Grounding

Example of Control/Output Connections

M-3425A

60 62

Power

61 63 11 10

Supply

BREAKER

FAILURE

INITIATE

Figure 2-7 Three-Line Connection Diagram

60FL52b

OSCILLOGRAPH

RECORDER

INITIATE

EXTERNAL

INPUTS

M-3425A

52 53

Low Impedance Grounding

3 3

ALARM

TRIP

SELF-

TEST

FAILURE

ALARM

OUTPUTS

POWER

STATUS

ALARM

FUSE LOSS

CONTROL

OUTPUTS

52G

52Ga

TRIP

OUTPUT

2–9

Page 61

M-3425A Instruction Book

M-3425A

Used when Generator

Side VTs are connected

Line-Ground.

ABC

Gen

ABC

52b

M-3425A

Used for Sync Check (25)

Used when Generator Side VTs

are connected Line-Line

M-3425A

Three VT Wye-Wye

Connection

M-3425A

Two VT Open-Delta

Connection

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

Page 62

Application – 2

M-3425A

VX used for turn-to-turn

fault protection (59X)

Line to Neutral

Voltage Rated

Cable

ABC

Gen

ABC

abc

52b

Generator

M-3425A

52 53

M-3425A

45 44

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

Page 63

M-3425A Instruction Book

M-3425A

Bus Section

65 64

59X

Bus Ground

M-3425A

67N, 59D

Connection

M-3425A

52b

67N

Connection

M-3425A

Residual CT

ABC

Gen

ABC

input can be connected

either at Neutral or as Residual.

VX can be used for both 67N and 59D if connected in this manner.

abc

Generator

M-3425A

Low Impedance Gr ounding

52 53

input can be connected

either at Neutral or as Residual.

M-3425A

45 44

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

Page 64

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).

Expanded Output Initiate

OUTPUT9

OUTPUT10

OUTPUT11

OUTPUT12

OUTPUT13

OUTPUT14

OUTPUT15

OUTPUT16

OUTPUT17

OUTPUT18

OUTPUT19

OUTPUT20

OUTPUT21

OUTPUT22

OUTPUT23

Expanded Input Initiate

Input 7

Input 8

Input 9

Input 10

Input 11

Input 12

Input 13

Input 14

Cancel

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

2–13

Page 65

M-3425A Instruction Book

21 Phase Distance

The Phase Distance function (21) is designed for system phase fault backup protection and is implemented as a three-zone mho characteristic.

Three separate distance elements are used to detect AB, BC, and CA fault types. The ranges and increments are shown in Figure 2-14. The diameter, offset, system impedance angle (relay characteristic angle), and definite time delay need to be selected for each zone for coordination with the system relaying in the specific application.

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

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

When Zone 3 is used for Out-of-step blocking, the out of step delay is used for the detection of the transit time of the swing between Zone 3 and Zone 2 impedances.

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

When the generator is connected to the system through a delta/wye transformer, proper voltages and currents (equivalent to the high side of the transformer) must be used in order for the relay to see correct impedances for system faults. By enabling the Delta-Y Transform feature (see Section

2.1, Configuration, Relay System Setup), the relay can internally consider the 30° phase shift (30° lead delta-ab or 30° lag delta-ac) through the delta/wye transformer, saving auxiliary VTs. Impedance calculations for various VT connections are shown in Table 2-2. All impedance settings are secondary relay quantities and can be derived from the following formula:

= Z

SEC

where Z = primary impedance, RC = current transformer

x (RC ÷ RV)

PRI

= secondary reflected impedance, Z

SEC

PRI

ratio, and RV = voltage transformer ratio.

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

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

21 #1 DIAMETER

________ Ohms

21 #1 OFFSET

________ Ohms

21 #1 IMPEDANCE ANGLE

________ Degrees

21#1 LOAD ENCROACHMENT disable ENABLE

21 #1 LOAD ENCR ANGLE

________ Degrees

21 #1 LOAD ENCR R REACH

________ Ohms

Typically the first zone of protection is set to an impedance value enough in excess of the first external protective section (typically 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 circle from the origin. This offset is usually set at zero. See Figure 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.

When enabled the 21 Function is blocked when the impedance falls within the zone but above the R Reach and below the Load Encroachment angle.

■ NOTE: The 21 #2 and #3 zone settings can be set for an additional external section of protection on the system (typically transmission Zone 1 distance relays) plus adequate overreach. #2 and #3 screens are identical to those in #1. Element #3 also includes out-of-step time delay when outof-step blocking is enabled for Zone #1 and/or Zone #2.

2–14

Page 66

Application – 2

21 #1 OC SUPERVISION disable enable

21 #1 OC SUPERVISION

________ Amps

21 #1 OUT OF STEP BLOCK disable enable

21 #1 DELAY

________ Cycles

21 #3 OUT OF STEP DELAY

________ Cycles

Protected Range Zone 3

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

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

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

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

–R

–X

Protected Range Zone 2

Protected Range Zone 1

Bus

M-3425A

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

Page 67

M-3425A Instruction Book

+jX

ZONE 3

Circle

Diameters

–R

Transmission Line

Unit Transformer

–jX

ZONE 2

ZONE 1

δ 2

Block

δ 1

Block

R1 Zone 1 Load Encroachment Blinder R Reach

R2 Zone 2 Load Encroachment Blinder R Reach

δ1 Zone 1 Load Encroachment Blinder Angle

δ2 Zone 2 Load Encroachment Blinder Angle

Θ Impedance Angle Setting

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

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

2–16

Page 68

Application – 2

#1 #2

(21) PHASE DISTANCE

Circle Diameter:

Offset:

Impedance Angle:

Load Encr. Angle:

Load Encr. R Reach:

Delay:

Overcurrent SV:

Out of Step Block Enable

OUTPUTS

8765432 1 FL654321

@ : WARNING, You have not selected an output!

0.1 Ohm

-100.0 Ohm(s)

1°

0.1 Ohm

1 Cycle

0.1 A

0°

Out of Step Block Disable

Blocking Inputs

100.0 Ohm(s)

90°

100.0 Ohm(s)

8160 Cycles

20 A

Save

Enable

Disable

Enable

Disable

Expanded I/O’s

Cancel

AB Fault

BC Fault

CA Fault

Transformer Direct

VT Connection

L-L or L-G to L-L

I a  I

I b  I

I c  I

Figure 2-14 Phase Distance (21) Setpoint Ranges

Connected

L-G

VA  V

I a  I

VB  V

I b  I

VC  V

I c  I

Transformer Delta-AC Connected

VT Connection

L-L or L-G to L-L

VBC  V

( 3 ) I

VCA  V

( 3 ) I

VAB  V

( 3 ) I

L-G

VB  V

VC  V

VA  V

Transformer Delta-AB Connected

L-L or L-G to L-L

VAB  V

VBC  V

VCA  V

Table 2-2 Impedance Calculation

VT Connection

( 3 ) I

L-G

Va  V

Vb  V

Vc  V

2–17

Page 69

M-3425A Instruction Book

24 Overexcitation Volts/Hz

The Volts-Per-Hertz function (24) provides overexcitation protection for the generator and unitconnected transformers. This function incorporates two definite time elements which can be used to realize traditional two-step overexcitation protection. In addition, the relay includes an inverse time element that provides superior protection by closely approximating the combined generator/unit transformer overexcitation curve. Industry standard inverse time curves may be selected along with a linear reset rate which may be programmed to match specific machine cooling characteristics. The percent pickup is based on the Nominal Voltage setting and the nominal frequency. The V/Hz function provides reliable measurements of V/Hz up to 200% for a frequency range of 2–80 Hz. The ranges and increments are presented in Figure 2-16.

Setting this relay function involves determining the desired protection levels and operating times. The first step is to plot the combined generator and associated unit transformer overexcitation capability limits. This data is typically available from the manufacturer and should be plotted on the same voltage base. Depending on the resulting characteristic, one of the four families of inverse time curves (as shown in Appendix D, Inverse Time Curves) can be matched to provide the protection. The two definite time elements can be used to further shape the protection curve or provide an alarm.

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

24DT #1 PICKUP

________ %

24DT #1 DELAY

________ Cycles

24DT #2 PICKUP

________ %

24DT #2 DELAY

________ Cycles

24IT PICKUP

________ %

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

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

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

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

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

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

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

24IT TIME DIAL

________

24IT RESET RATE

________ Seconds

2–18

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

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

Page 70

Application – 2

M-3425A Firmware Versions D-0114VXX.XX.XX and Earlier

■ NOTE:

When the inverse time element is enabled, the definite time element #1 must be enabled which will provide definite minimum time setting for the inverse time curve.

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

1. The pickup of the inverse time element must be less than the pickup of the definite time element #1

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

3. When the inverse time element is enabled, definite time element #1 should not be used for alarm. Only definite time element #2 can be used for alarm.

After any V/Hz excursion, cooling time must also be taken into account. If the unit should again be subjected to high V/Hz before it has cooled to normal operating levels, damage could be caused before the V/Hz trip point is reached. For this reason, a linear reset characteristic, adjustable to take into account the cooling rate of the unit, is provided. If a subsequent V/Hz excursion occurs before the reset characteristic has timed out, the time delay will pick up from the equivalent point (as a %) on the curve. The Reset Rate setting entered should be time needed for the unit to cool to normal operating temperature if the V/Hz excursion time was just under the trip point.

M-3425A Firmware Version D-0150V 01.00.34

The inverse time element has a definite minimum time of 30 cycles. Definite Time Element #1 is independent, and has no effect on inverse time elements.

M-3425A Firmware Version D-0150V 01.04.00

The inverse time element has a definite minimum time of 60 cycles. Definite Time Element #1 is independent, and has no effect on inverse time elements.

1000

Generator Limit Curve

100

Inverse Time Delay at Definite

Time Pickup #1 (A2)

Time in Minutes

0.1

0.01

100 105 110 115 120 125 130 135 140 145 150

Definite Time Delay (A1)

Definite Time Pickup

Inverse Time Pickup

Percentage Volts/Hz

Transformer Limit Curve

on Generator Base

Inverse Square Curve

Combined Protection

K = 5

Curve

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

2–19

Page 71

M-3425A Instruction Book

F24

(24) - VOLTS/HZ

Pickup:

Delay:

8765432 1

Pickup:

Delay:

8765432 1

Pickup:

Curves: #1 #2 #3 #4

Time Dial:

Reset Rate:

8765432 1

@ : WARNING, You have not selected an output!

100%

30 Cycles

100%

30 Cycles

100% 200%

1 Sec

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

200%

8160 Cycles

Blocking InputsOUTPUTS

FL654321

200%

8160 Cycles

Blocking InputsOUTPUTS

FL 6 5 4 3 2 1

100

999 Secs

Blocking InputsOUTPUTS

FL654321

Def. Time #1

Expanded I/O’s

Def. Time #2

Expanded I/O’s

Inv. Time

Expanded I/O’s

Save

Cancel

2–20

Page 72

25 Sync Check

■ NOTE: The 25 function cannot be enabled under any one of the following conditions:

• 67N (Residual Directional Overcurrent) is enabled and the polarizing quantity has been set to V

• 59D is enabled and the line side voltage is set to VX.

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

The Synchronism (Sync) Check function (25) is used to ensure that the voltage magnitude, phase angle and frequency of the generator (V1) and the utility system (VX) are within acceptable limits before the generator is synchronized with the system. Generator voltage (V1) can be selected as A, B, or C (line-to-ground and line-ground to line-line) or AB, BC, or CA (line-to-line).

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

Phase Angle Check

The phase angle is considered acceptable when the selected sync phase voltage (V1) and system voltage (VX) are within the Upper Volt Limit and Lower Volt Limit window and the measured phase angle is within the phase angle window.

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

Application – 2

Dead Line/Dead Bus Check

The Dead Volt Limit defines the Hot/Dead voltage level used in Deadline/Dead Bus closing schemes. When the measured V the Dead Volt Limit, V

voltage is equal to or below

is considered dead. When

the measured VX is above the Dead Volt Limit, V is considered hot. The opposite side of the breaker uses the positive sequence voltage measurement (V1) for 3-phase consideration in determining hot/ dead detection. Different combinations of hot line/ dead bus closings may be selected, depending on how the buses are referenced. A logic diagram of the Deadline/Dead Bus scheme is presented in Figure 2-17.

The Dead V1, Dead VX, and Dead V1 & VX enable are software switches used to enable the dead line/dead bus logic. Further conditioning can be performed on the dead detection logic by selecting one or more input contacts (Dead Input Enable) to control the enabled dead detection element. For example, if INPUT2 (I2) is selected under the Dead Input Enable screen, and both the Dead V1 and Dead VX elements are enabled, the dead check timer will start when INPUT2 is activated, and either V1 dead/VX hot or V1 hot/VX dead. This allows for external control of the desired dead closing scheme. Dead Input Enable selections are common to all dead detection elements. If no inputs are selected under the Dead Input Enable screen, and any dead element is enabled, the dead check timer will start immediately when the dead condition exists.

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

Delta Voltage and Delta Frequency Check

Delta Voltage and Delta Frequency elements may be individually enabled or disabled, as desired. The 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.

■ NOTE: The 25 function does not produce a target or LED and is accompanied by the HMI message “F25 Function Operated”.

2–21

Page 73

M-3425A Instruction Book

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

25S PHASE LIMIT

Phase angle setting.

________ Degrees

25S UPPER VOLT LIMIT

________ Volts

25S LOWER VOLT LIMIT

________ Volts

25S SYNC CHECK DELAY

________ Cycles

25S DELTA VOLT disable ENABLE

25S DELTA VOLT LIMIT

________ Volts

25S DELTA FREQUENCY disable ENABLE

25S DELTA FREQ LIMIT

________ Hz

Upper voltage limit for voltage acceptance.

Lower voltage limit for voltage acceptance.

Sync check time delay.

Delta voltage element.

Delta voltage setting.

Delta frequency element.

Delta frequency setting.

25S SYNC-CHECK PHASE abc

25D DEAD VOLT LIMIT

________ Volts

25D DEAD V1 HOT VX disable ENABLE

25D DEAD VX HOT V1 disable ENABLE

25D DEAD V1 & VX DISABLE enable

25D DEAD INPUT ENABLE

i6 i5 i4 I3 i2 i1

25D DEAD DELAY

________ Cycles

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

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

Enables Dead V1/Hot V

setting.

Enables Hot V1/Dead VX setting.

Enables Dead V1/Dead VX closing.

Externally controlled dead closing. Inputs IN7–IN14 must be set using IPScom.

Dead delay timer setting.

2–22

Page 74

Phase Angle Check Logic

Lower Voltage Limit

Upper Voltage Limit

Lower Voltage Limit

VX Upper Voltage Limit

Phase Angle

Phase Limit

Delta V and Delta F Check Logic

AND

AND AND

Delta V and Delta F Check Logic

With Delta V AND Delta F Enabled

|V1- VX| < Delta V Limit

AND

Delta V Is Enabled

|F1- FX| < Delta F Limit

AND

Delta F Is Enabled

Phase Angle OK

With Delta V OR Delta F Enabled

|V1- VX| < Delta V Limit

AND

Delta V Is Enabled

|F1- FX| < Delta F Limit

AND

Delta F Is Enabled

AND

Application – 2

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

AND

Sync Check Timer

Output Seal-in Timer

25S

Output

Contact

AND

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

Dead V1 Hot VX Enabled

Dead Input Enable

Selected INPUT Is Activated

Dead VX Hot V1 Enabled

Dead Line/ Dead Bus Check Logic

Dead Limit

pos

VX > Dead Limit

Dead V1 Hot VX Enabled

Dead Limit

pos

VX < Dead Limit

Dead VX Hot V1 Enabled

Dead Limit

pos

VX < Dead Limit

Dead V1 VX Enabled

AND

Dead Line/ Dead Bus Check Input Initiate Logic

Dead Limit

pos

AND

VX > Dead Limit

Dead Limit>

pos

VX < Dead Limit

User Software Setting

Measured Variable

Figure 2-17 Sync Check Logic Diagrams

Dead Check Timer

Output Seal-in Timer

25D

Output

Contact

2–23

Page 75

M-3425A Instruction Book

F25

Phase Angle Window:

Upper Voltage Limit:

Lower Voltage Limit:

Sync Check Delay:

Delta Voltage:

Delta Frequency: 0.001 Hz 0.500 Hz

(25) - SYNC CHECK

60 V

40 V

1 Cycle

1.0 V 50.0 V

Enable Disable

25S Sync Check Phase

Phase AB Phase BC

Phase CA

140 V

120 V

8160 Cycles

25S

8765432 1 FL654321

OUTPUTS

Dead Voltage Limit:

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

Dead Time Delay:

OUTPUTS

87 65 43 2 1

0 V 60 V

1 Cycle 8160 Cycles

Blocking Inputs

Dead Input Enable

654321

Blocking Inputs

FL654321

Expanded I/P Initiate

@ : WARNING, you have not selected an output!

Figure 2-18 Sync Check (25) Setpoint Ranges

Expanded I/Os

Save

25D

Cancel

2–24

Page 76

27 Phase Undervoltage

The Phase Undervoltage function (27) may be used to detect any condition causing long- or short-term undervoltage. This is a true three-phase function in that each phase has an independent timing element. The ranges and increments are presented in Figure 2-19.

Application – 2

Magnitude measurement depends on the 59/27 Magnitude Select setting. (See Section 2.1, Configuration, Relay System Setup.) When the RMS calculation 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. 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

________ Volts

27 #1 DELAY

________ Cycles

F27

Pickup:

Delay:

8765432 1 FL6 54321

Pickup:

Delay:

(27) - PHASE UNDERVOLTAGE

1 Cycle

OUTPUTS

1 Cycle

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

5 V

180 V

8160 Cycles

Blocking Inputs

180 V

8160 Cycles

Expanded I/Os

OUTPUTS

8765432 1 FL6 54321

Pickup:

Delay:

OUTPUTS

8765432 1 FL6 54321

5 V

1 Cycle

@ : WARNING,You have not selected an output!

Blocking Inputs

180 V

8160 Cycles

Blocking Inputs

Figure 2-19 Phase Undervoltage (27) Setpoint Ranges

Expanded I/Os

Save

Cancel

2–25

Page 77

M-3425A Instruction Book

27TN Third Harmonic Undervoltage, Neutral

For ground faults near the stator neutral, the Third Harmonic (180/150 Hz) Neutral undervoltage function (27TN) provides stator ground-fault protection for high-impedance-grounded generator applications (See Figure 2-20). When used in conjunction with the fundamental neutral overvoltage (60/50Hz) function (59N), 100% stator ground-fault protection can be provided. This is illustrated in Figure 2-20.

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

In some generators, the third harmonic voltage can be very low, especially during light load conditions. It is also observed in some generator installations that the third harmonic voltage is considerably reduced for a specific range of power output (band). To prevent mis-operation during these conditions, the 27TN function can be programmed to be supervised (blocked) by low forward power, low reverse power, low Vars (lead and lag), low power factor (lead/lag), and when the forward power is inside a band.

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

27TN #2 Screens are identical to 27TN #1.

before the unit synchronized, small current measurement errors cause the measured power to fluctuate (typically <0.2%.) This may result in a measured power value that is negative (i.e., –0.001 pu.) If the reverse power blocking is not enabled, the 27TN may be momentarily unblocked, resulting in a relay operation and nuisance generator trip. It is highly recommended that if the Forward Power Blocking is used, both the Forward Power Blocking and Reverse Power Blocking be enabled and set.

In the majority of the cases, these blocking functions will be disabled, except for those operating cases where the third harmonic neutral voltage magnitude is less than 0.5 V. The settings for the blocking functions should be set based on field measurements. Blocking regions are illustrated in Figure 2-21.

The 27TN setting depends on the actual thirdharmonic neutral voltage level seen during normal operation of the generator. The setting should be about 50% of the minimum third-harmonic voltage observed during various loading conditions. This can be most conveniently measured during commissioning of the relay. Since the relay measures the third harmonic voltage levels and will display those values directly, no additional equipment is required. The undervoltage inhibit setting should be about 80% to 90% of the nominal voltage. The ranges and increments are presented in Figure 2-22.

27TN #1 PICKUP

________ Volts

27TN #1 POS SEQ VOLT BLK disable ENABLE

27TN #1 POS SEQ VOLT BLK

________ Volts

27TN #1 FWD POWER BLK disable ENABLE

27TN #1 FWD POWER BLK

________ PU

2–26

Relay volts are equal to the primary neutral voltage divided by the grounding transformer ratio. Generally set for approximately 50% of the minimum third harmonic voltage observed during various loading conditions.

27TH #1 REV POWER BLK disable ENABLE

27TN #1 REV POWER BLK

________ PU

27TN #1 LEAD VAR BLK disable ENABLE

27TN #1 LEAD VAR BLK

________ PU

Page 78

Application – 2

27TN #1 LAG VAR BLK disable ENABLE

27TN #1 LAG VAR BLK

________ PU

27TN #1 LEAD PF BLK disable enable

27TN #1 LEAD PF BLK

________ LEAD

27TN #1 LAG PF BLK disable enable

27TN #1 LAG PF BLK

________ LAG

27TN #1 BAND FWD PWR BLK disable enable

27TN#1 LO B FWD PWR BLK

________ PU

27TN#1 HI B FWD PWR BLK

________ PU

27TN #1 DELAY

________ Cycles

Fundamental (60/50 Hz) neutral voltage during ground fault

Third Harmonic (180/150 Hz) neutral voltage during ground fault

Neutral Voltage

27TN Setpoint

59N Setpoint (typically 5V)

Pre-fault third harmonic voltage level

Pre-fault fundamental neutral voltage level

Neutral End of Generator

50%

100%

Fault Position

(% of stator winding measured

27TN

from neutral end of generator)

Protection provided by:

5% - 10%

59N

0-30%

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

Terminal End of Generator

2–27

Page 79

M-3425A Instruction Book

Lag var Block

-P

Reverse

Power

Block

Lead var Block

Block Block

Low Band Forward

Power Block

Forward

Power

Block

-Q

Figure 2-21 27TN Blocking Regions

High Band

Forward

Power Block

2–28

Page 80

(27TN) - THIRD HARMONIC UNDERVOLTAGE, NEUTRAL

Pickup:

Pos. Seq. Voltage Block:

Forward Power Block:

Reverse Power Block:

Lead var Block:

Lag var Block:

Lead Power Factor Block:

Lag Power Factor Block:

Hi Band Forward Power Block:

Lo Band Forward Power Block:

Delay:

OUTPUTS

8765432 1

0.1 V

5 V

0.01 PU

-1.00 PU

0.01 PU

0.01 Lead

0.01 Lag

0.01 PU

1 Cycle

14.00 V

180 V

1.00 PU

-0.01 PU

1.00 PU

1.00 Lead

1.00 Lag

1.00 PU

8160 Cycles

Blocking Inputs

FL 6 5 4 3 2 1

Enable Disable

Expanded I/O’s

Application – 2

@ : WARNING, You have not selected an output!

Save

Cancel

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

2–29

Page 81

M-3425A Instruction Book

32 Directional Power

The Directional Power function (32) can provide protection against both generator motoring and overload. It provides three power setpoints, each with a magnitude setting and a time delay. The Forward Power direction (power flow to system) is automatically chosen when the pickup setting is positive and the Reverse Power direction (power flow to generator) is automatically chosen when the pickup setting is negative. The range, as shown is from –3.000 PU to 3.000 PU where 1.0 PU is equal to the generator MVA rating. Normalized PU power flow measurements are based on Nominal Voltage and Nominal Current setting, as shown in Section

2.1, Configuration, Relay System Setup.

Protection from Generator Motoring

Protection against motoring is provided by selecting a negative pickup with Over/Under power set to Over. The relay will operate when the measured real power is greater (more negative) than the pickup setting in the reverse direction.

In some steam generator applications it is desirable to trip the generator when the forward power is less than a small value. This is due to the fact that the trapped steam will cause the generator to supply a small amount of power even though the steam

valves are closed. In this case the Over/Under power setting is set to Under and a positive pickup setting is chosen. The relay will trip when the measured forward power is less than the pickup value. The function should be blocked when the generator breaker is open (using contact input blocking) otherwise the function will trip and prevent the generator from being brought online.

Protection from Generator Overload

Protection from generator overload is provided by selecting a positive pickup setting with Over/Under Power setting set to Over. The relay will operate when the measured real power is greater than the pickup setting.

Protection from Excessive Reactive Power

The directional power element #3 can be set to operate on either real power or reactive power. When protection from excessive reactive power is required the element #3 can be set to operate on reactive power. The relay will operate when the measured reactive power exceeds the pickup setting.

Figures 2-23 through 2-26 show reverse power, low forward power, over power, and over reactive power applications.

32 #1 PICKUP

________ PU

32 #1 DELAY

________ Cycles

32 #1 TARGET LED disable enable

32#1 UNDER/OVER POWER over under

32 #2 PICKUP

________ PU

32 #2 DELAY

________ Cycles

The reverse power pickup setting should be based on the type of prime mover and the losses when the generator is motoring.

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

Target LED for the 32 Function elements can be individually enabled or disabled.

When Low Forward Power protection is desired, set this to 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 protection, providing either alarm or tripping or both, when power 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 of the generator in which case the associated time delay will be in the range of 2 to 3 seconds.

2–30

Page 82

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

Application – 2

32 #3 DIR POWER SENSING real reactive

Reverse Power Flow

-1.0 PU

TRIP

Pickup

Directional Power Sensing for Element #3 can be selected as Real or Reactive.

Forward Power Flow

1.0 PU

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

2–31

Page 83

M-3425A Instruction Book

Reverse Power Flow

-1.0 PU

1.0 PU

Forward Power Flow

TRIP

Pickup

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

2–32

Reverse Power Flow

-1.0 PU

Pickup

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

1.0 PU

Forward Power Flow

TRIP

Page 84

Pickup

Application – 2

Reactive Power

Into System

TRIP

Reverse Power Flow

Forward Power Flow

-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

Page 85

M-3425A Instruction Book

F32

(32) - DIRECTIONAL POWER

Pickup:

Delay:

Overpower Underpower Target LED Enable

8765432 1 FL654321

Pickup:

Delay:

Overpower Underpower Target LED Enable

8765432 1 FL654321

Pickup:

Delay:

Overpower Underpower Target LED Enable

Directional Power Sensing:

8765432 1 FL654321

-3.000 PU

1 Cycle

Real

Reactive

OUTPUTS

-3.000 PU

1 Cycle

OUTPUTS

-3.000 PU

1 Cycle

OUTPUTS

@ : WARNING, You have not selected an output!

3.000 PU

8160 Cycles

Blocking Inputs

3.000 PU

8160 Cycles

Blocking Inputs

3.000 PU

8160 Cycles

Blocking Inputs

Expanded I/Os

Save

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

Cancel

2–34

Page 86

40 Loss of Field

The Loss-of-Field function (40) provides protection for a partial or complete loss of field. A variety of possible settings make the M-3425A Generator Protection Relay very flexible when applied to lossof-field protection. Ranges and increments are presented in Figure 2-30.

The loss-of-field function is implemented with two offset mho elements, an undervoltage element, and a directional element. The setting for each mho element, diameter, offset, and time delay, are adjusted individually. Each element has two time delay settings. The second time delay (delay with VC) is applicable with voltage control, and the timer only starts if the positive sequence voltage is below the voltage control setting. The function with voltage control and without voltage control can be programmed to send to two different output contacts, if desired. The delay with voltage control may be enabled on each element but the voltage level setting is common. The voltage control allows for faster tripping when low voltage may be caused by the VAr intake by the machine with loss of excitation. A common directional unit is provided to block the relay operation during slightly underexcited conditions (since approach #1 with negative offset is inherently directional, the directional element is

Application – 2

not required). The directional unit’s angle setting

) can be set from 0° to 20°.

(Θ

The settings of the offset mho elements should be such that the relay detects the loss-of-field condition for any loading while not mis-operating during power swings and fault conditions. Two approaches are widely used in the industry, both of which are supported by the M-3425A relay. Both approaches require knowledge of the reactances and other parameters of the generator. They are described in Figure 2-28, Loss of Field (40) — Protective Approach I and Figure 2-29, Loss of Field (40) — Protective Approach II.

Positive sequence impedance measurements are used for the loss of field functions. All impedance settings are secondary relay quantities and can be derived from the following formula:

= Z

SEC

where Z = primary impedance, RC = current transformer

= secondary reflected impedance, Z

SEC

x (RC ÷ RV)

PRI

ratio, and RV = voltage transformer ratio.

40 #1 DIAMETER

________ Ohms

40 #1 OFFSET

________ Ohms

40 #1 DELAY

________ Cycles

40VC #1 DELAY WITH VC

________ Cycles

The first approach is shown in Figure 2-28, Loss of Field (40) — Protective Approach I. Here, both of the offset mho elements (#1 and #2) are set with an offset of –X

÷2, where X

is the (unsaturated) direct axis transient reactance 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 lossof-field from full load to about 30% load. A small time delay provides fast protection.

The diameter of the larger circle (#2) is set equal to Xd, where Xd is the (unsaturated) direct axis 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

Page 87

M-3425A Instruction Book

40 #2 DIAMETER

________ Ohms

40 #2 OFFSET

________ Ohms

40 #2 DELAY

________ Cycles

40VC #2 DELAY WITH VC

________ Cycles

40 VOLTAGE CONTROL

________ Volts

The second approach is shown in Figure 2-29, Loss of Field (40) – Protective Approach II. In this approach, one of the mho elements is set with an offset of –X

÷ 2, a diameter of 1.1 Xd-(X

÷ 2), and a time delay of 10 to 30 cycles. The second element is set to coordinate with the generator minimum excitation limit and steadystate stability limit.

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 (XT). The diameter is approximately equal to (1.1 X

+ XT). A time

delay of 30 to 60 cycles would prevent misoperation on stable swings.

The following table provides suggested time settings when time delay with VC is used in addition to standard time delay.

40 DIRECTIONAL ELEMENT

________ Degrees

Typical setting is 13° (0.974 power factor). This setting is common to both element #1 and #2.

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.

1enoZ 2enoZ

gnitteSlortnoCegatloVA/N

yaleDselcyC51selcyC006,3

CVhtiwyaleDelbasiDselcyC06

Table 2-3 Voltage Control Time Settings

fo%09ot08

egatloVlanimoN

2–36

Page 88

Application – 2

Heavy Load

X'

R +R

Light Load

1.0 pu

Loss of Excitation

Final Impedance

Locus

X

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

Directional Element

Underexcited

Steady-State Stability Limit

Machine Capability

Minimum Exciter Limit

Block Direction

Trip Direction

R

Directional

Element Angle

Setting

1.1 X

Heavy Load

X'

Loss of Excitation

Final Impedance

Locus

Light Load

X

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

Underexcited

Steady-State Stability Limit

Machine Capability

Minimum Exciter Limit

2–37

Page 89

M-3425A Instruction Book

F40

Circle Diameter:

Offset:

Delay:

(40) - LOSS OF FIELD

0.1 Ohm

- 50.0 Ohms

1 Cycle

100.0 Ohms

50.0 Ohms

8160 Cycles

0.1 Ohm

- 50.0 Ohms

1 Cycle

5 V

0°

Blocking Inputs

8160 Cycles

VC Blocking Inputs

100.0 Ohms

50.0 Ohms

8160 Cycles

Blocking Inputs

8160 Cycles

VC Blocking Inputs

180 V

20°

8765432 1 FL654321

Delay with VC:

1 Cycle

VC OUTPUTS

OUTPUTS

8765432 1 FL654321

Circle Diameter:

Offset:

Delay:

OUTPUTS

8765432 1 FL654321

Delay with VC:

VC OUTPUTS

8765432 1 FL654321

Voltage Control:

Directional Element:

@ : WARNING, You have not selected an output!

Expanded I/Os

VC#1

Expanded I/Os

VC#2

Expanded I/Os

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

Page 90

46 Negative Sequence Overcurrent

The Negative Sequence Overcurrent function (46) provides protection against possible rotor overheating and damage due to unbalanced faults or other system conditions which can cause unbalanced three phase currents in the generator. Ranges and increments are presented in Figure 2-32.

This function has a definite time element and an inverse time element. The definite time pickup value and definite operating time are normally associated with an alarm function. The inverse time element is usually associated with a trip function and has a pickup and an operating time defined by an (I Setting and I

)2t = K, where K is the Time Dial

is the per unit negative sequence

current.

The minimum delay for the inverse time function is factory set at 12 cycles to avoid nuisance tripping. A maximum time to trip can be set to reduce the operating times for modest imbalances. An important feature that helps protect the generator from damage due to recurring imbalances is a linear reset characteristic. When I

decreases below the pickup

Application – 2

value, the trip timer takes four minutes to reset from its 100% trip level. Figure 2-31, Negative Sequence Overcurrent Inverse Time Curves, illustrates the inverse time characteristic of the negative sequence overcurrent function.

Operating times are lower than shown in Figure 2-31 when measured current values are greater than 15 A (3 A for 1 A rated circuit).

The first task of setting this function is to determine the capabilities of the associated machine. As established by ANSI standards, the machine limits are expressed as (I2)2t = K. The value of K is established by the machine design and is generally provided on test sheets of the machine. The relay can accommodate any generator size because of the wide range of K settings from 1 to 95. Typical values can be found in ANSI C50.13-1977.

The negative sequence pickup range is from 3% to 100% of the Nominal Current value input during system setup (see Section 2.1, Configuration).

This protection must

not

operate for system faults that will be cleared by system relaying. This requires consideration of line protection, bus differential and breaker failure backup protections.

46DT PICKUP

________ %

46DT DELAY

________ Cycles

46IT PICKUP

________ %

46IT MAX DELAY

________ Cycles

46IT RESET TIME

________ Seconds

46IT TIME DIAL

________

The pickup setting is usually quite low (3–5%) and the output of this function is usually connected to alarm only.

Time delay should be set high enough to avoid alarms on transients.

The 46 Inverse Time pickup setting should coincide with the continuous negative sequence current capability of the generator operating at full output.

The maximum trip time is used to reduce the longer trip times associated with low to moderate imbalances to a preset time.

The time dial setting corresponds to the K provided by the generator manufacturer for the specific unit being protected. See Figure 2-31 for the negative sequence overcurrent inverse time curves.

2–39

Page 91

M-3425A Instruction Book

Negative Sequence Current (% of Nominal Value)

Time (Seconds)

Pickup Setting Range

1000

800

600

400

200

100

0.6

0.4

0.2

0.1

4 5 6 8 10 20 40 60 80 100 150 200 300 400 500600 800 1000 1000 2000 3000 4000

To 65,500 cycles

Definite Maximum

Time Setting Range

t=K

Definite Minimum Time

■■

■ 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.

2–40

Figure 2-31 Negative Sequence Overcurrent Inverse Time Curves

F46

(46) - NEGATIVE SEQUENCE OVERCURRENT

Pickup:

Delay:

8765432 1 FL654321

Pickup:

Time Dial:

Maximum Time:

Reset Time:

8765432 1 FL654321

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

1 Cycle

OUTPUTS

600 Cycles

1 Second

OUTPUTS

@ : WARNING, You have not selected an output!

100%

8160 Cycles

Blocking Inputs

100%

65500 Cycles

600 Seconds

Blocking Inputs

Def. Time

Expanded I/Os

Inv. Time

Expanded I/Os

Save

Cancel

Page 92

49 Stator Overload Protection

The Stator Thermal Overload function (49) provides protection against possible damage during overload conditions. The characteristic curves are based on IEC-255-8 standard, and represent both cold and hot curves. The function uses the thermal time constant of the generator and stator maximum allowable continuous overload current (I implementing the inverse time characteristic.

max

) in

Where: t = time to trip τ = thermal time constant IL = load current IPL = pre-load current I

= maximum allowed continuous overload current

max

Example

: If we consider that the generator was

Application – 2

loaded with 80% of its rating power prior to overload, then the current goes up to 2.0 times the maximum current ((I (see Figure 2-28), we have t/τ =0.1133. If τ =30

)=2.0). Selecting the curve P=0.8

L/Imax

minutes, then the time delay for this condition would be: t = 0.1133 x 30 = 3.3999 minutes.

The 49 function has two elements, one of which can be used for trip and the other for alarm.

Current-Square

max

49 #1 TIME CONSTANT

________ Min

Tripped

Not Tripped

Figure 2-33 Time Constant, Function 49

Selects the time constant, ‘τ ’

49#1 MAX OVERLOAD CURR

________ Amps

Selects the maximum allowed continuous overload current.

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

2–41

Page 93

M-3425A Instruction Book

49 - Overload Curves

t / t

P=0.99

123456789

IL/I

max

where: P=

max

P=0.0 P=0.5

P=0.6 P=0.7

P=0.8

P=0.9

0.1

0.01

0.001

2–42

Figure 2-34 49 Function Overload Curves

Page 94

F49

Application – 2

(49) - STATOR OVERLOAD

Time Constant:

Max. Overload Current:

8765432 1

Time Constant:

Max. Overload Current:

8765432 1

@ : WARNING, You have not selected an output!

1.0 min

1.00 A

1.0 min

1.00 A

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

999.9 min

10.00 A

FL 6 5 4 3 2 1

FL654321

Blocking InputsOUTPUTS

999.9 min

10.00 A

Blocking InputsOUTPUTS

Expanded I/Os

Save Cancel

2–43

Page 95

M-3425A Instruction Book

50/50N Instantaneous Overcurrent, Phase and Neutral Circuits

The Instantaneous Phase (50) and Instantaneous Neutral (50N) overcurrent functions provide fast tripping for high fault currents. The settings of both functions must be set such that they will not pickup for fault or conditions outside the immediate protective zone. If the neutral current input is connected to a step-up transformer’s neutral CT, the 50N function can be used as a breaker flashover protection when used in conjunction with external breaker failure protection. Ranges and Increments are presented in Figures 2-36 and 2-37. The function

automatically selects fundamental RMS or total RMS calculation based on the input frequency. When the generator frequency is within &5 Hz from the nominal frequency, it uses fundamental RMS calculation. Outside of this range, it uses total RMS calculation, which will provide protection during offline down to a frequency of 8 Hz.

For providing off-line protection, one of the elements can be supervised by a breaker ‘b’ contact, and the element blocked when the breaker is closed. This allows the function to be set sensitively (below full load current).

50#1 PICKUP

________ Amps

50#1 DELAY

________ Cycles

50N PICKUP

________ Amps

50N DELAY

________ Cycles

F50

Pickup:

8765432 1 FL654321

Delay:

The relay current (I the appropriate CT ratio. These screens are repeated for 50#2 element.

(50) - INSTANTANEOUS OVERCURRENT

0.1 A

1 Cycle

OUTPUTS

) is equal to the primary current (Ip) divided by

240.0 A

8160 Cycles

Blocking Inputs

Expanded I/Os

2–44

Pickup:

Delay:

8765432 1 FL654321

0.1 A

1 Cycle

OUTPUTS

@ : WARNING, You have not selected an output!

240.0 A

8160 Cycles

Blocking Inputs

Expanded I/Os

Save

Figure 2-36 Instantaneous Overcurrent (50) Setpoint Ranges

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Page 96

F50N

Application – 2

(50N) - INSTANTANEOUS NEUTRAL OVERCURRENT

Pickup:

Delay:

8765432 1

@ : WARNING, You have not selected an output!

0.1 A

1 Cycle

Blocking InputsOUTPUTS

FL 6 5 4 3 2 1

240.0 A

8160 Cycles

Expanded I/Os

Save

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

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2–45

Page 97

M-3425A Instruction Book

50BF Generator Breaker Failure/HV Breaker Flashover

The Generator Breaker Failure/HV Breaker Flashover function (50BF) is applicable when a generator breaker is present and line side generator CTs are being used. The 50BF-Ph phase detector element (if enabled) is used for breaker failure and the 50BF-N (if enabled) provides breaker flashover protection by providing an additional breaker failure initiate which is only active when the breaker is open. For high impedance grounded applications, the 50BF-N function is inapplicable and must be disabled. Ranges and increments are presented in Figure 2-39.

50BF-Ph Generator Breaker Failure: When the M-3425A Generator Protection Relay detects an internal fault or an abnormal operating condition, it closes an output contact to trip the generator breaker or the unit HV breaker. When a generator breaker is used, protection is available for the instance where it fails to clear the fault or abnormal condition. Such generator breaker failure protection output contacts must be connected to trip the additional necessary breakers to isolate the generator from the system.

The breaker-failure condition is usually detected by the continued presence of current in any one or more of the phases after a trip has been sent to the breaker. However, the current detector (50BF-Ph) may not always give the correct status of the breaker, especially for generator breakers. This is because faults and abnormal operating conditions such as ground faults, overexcitation, over/under frequency, and reverse power may not produce enough current to operate the current detectors. For this reason, the breaker status input 52b contact must be used, in addition to the 50BF-Ph, to provide adequate breaker status indication.

Implementation of the generator breaker failure function is illustrated in Figure 2-38. The breaker failure timer will be started whenever any one of the designated output contacts or the external programmed breaker failure initiate status input are operated. The timer continues to time if any one of the phase currents are above the 50BF-Ph pickup setting or if the 52b contact indicates the breaker is still closed; otherwise, the timer is reset.

Since current in the generator high side CT which energizes the 50BF protection (I

, IB, IC) might not

extinguish concurrently with the breaker opening for faults between the CT location and the generator breaker, a possible area of mis-operation exists. Usually the risk of faults in this limited area is small enough to be ignored but should be considered.

50BF-Neutral Element: This instantaneous overcurrent relay is energized from the generator neutral CT (See Figure 2-5, One-Line Functional Diagram). This function is internally in series with a breaker “b” contact (IN1) to provide logic for the breaker flashover protection (see Figure 2-38).

HV Breaker Failure (limited) The breaker failure function may be used for a unit breaker rather than a generator breaker. It is limited in that it has no fault detector associated with the unit breaker. Output contact operation would occur if any of the initiate contacts close and the 52b contact indicated a closed breaker after the set time delay.

This operation is chosen by disabling the neutral element, disabling the phase element, and designating initiating inputs and outputs and a time delay setting.

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Page 98

Application – 2

50BF PHASE ELEMENT disable enable

50BF PICKUP PHASE

________ Amps

50BF NEUTRAL ELEMENT disable enable

50BF PICKUP NEUTRAL

________ Amps

50BF INPUT INITIATE i6 i5 i4 i3 i2 i1

50BF OUTPUT INITIATE o8 o7 o6 o5 o4 o3 o2 o1

50BF DELAY

________ Cycles

If generator breaker failure function is used in this application, ENABLE here.

Set phase pickup amps.

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

Set the neutral pickup amps.

Designate the status inputs which will initiate the breaker failure timer. Inputs IN7–IN14 must be set using IPScom®.

Designate the outputs that will initiate the breaker failure timer. Outputs OUT9–OUT23 must be set using IPScom.

For generator breaker failure protection, the time delay should be set to allow for breaker operating time plus margin.

50BF-Ph

Overcurrent

I>P.U.

Phase Initiate Enable

IN1 (52b)

Logic high when breaker open

50BF-N

Overcurrent

I>P.U.

Neutral Initiate Enable

Output Initiate

Input Initiate

AND

NOT

Logic high when breaker closed

AND

Figure 2-38 Breaker Failure Logic Diagram

AND

DELAY

TIME

Programmed

Output

Contacts

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Page 99

M-3425A Instruction Book

F50BF

(50BF) - BREAKER FAILURE

Phase Current:

Neutral Current:

Delay:

8765432 1

0.10 A

Enable Disable

0.10 A

Enable Disable

1 Cycle 8160 Cycles

@ : WARNING, You have not selected an output!

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

10.00 A

Input InitiateOutput Initiate

654321

Blocking InputsOUTPUTS

FL 6 5 4 3 2 1

50BF

Expanded I/O Initiate

Expanded I/Os

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Page 100

50DT Definite Time Overcurrent (for split-phase differential)

The Definite Time Overcurrent (50DT) function can be applied in two different configurations based on the CT connections. When CT configuration shown in Figure 2-5, One Line Functional Diagram is used, the 50DT function is used as a definite time phase overcurrent function to provide protection for external and internal faults in the generator. When the CTs are connected to measure the split phase differential current (shown in Figure 2-6, Alternative One Line Functional Diagram), the 50DT function can be used as a split-phase differential relay.

50DT #1 PICKUP PHASE A

________ Amps

50DT #1 PICKUP PHASE B

________ Amps

Application – 2

■ NOTE: When 50DT function is used for split- phase differential, 50BF, 87 and 87GD functions must be disabled.

Refer to Section 2.1, Configuration, Relay System Setup for a description of the 50DT Split-Phase Operate setting, and Section 2.2, System Diagrams.

In some cases, the generators may be run with a faulted turn shorted until the generator winding is repaired. To prevent mis-operation under these 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 increments are presented in Figure 2-40

50DT #1 PICKUP PHASE C

________ Amps

50DT #1 DELAY

________ Cycles

F50DT

(50DT) - DEFINITE TIME OVERCURRENT

Pickup (A):

Pickup (B):

Pickup (C):

Delay:

OUTPUTS

8765432 1 FL654321

Pickup (A):

Pickup (B):

Pickup (C):

Delay:

OUTPUTS

8765432 1 FL654321

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

0.20 A

1 Cycle

0.20 A

1 Cycle

240.0 A

8160 Cycles

Blocking Inputs

240.0 A

8160 Cycles

Blocking Inputs

Expanded I/Os

@ : WARNING, You have not selected an output!

Save Cancel

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

2–49