Woodward MFR 15 Manual Download

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37143A

Manual

Software Version 1.9xx / 2.0xx / 2.1xx / 3.0xx / 3.1xx

Manual 37143A

MFR 15
Protection Relay & Control

Summary of Contents for MFR 15

Page 1: ...37143A Manual Software Version 1 9xx 2 0xx 2 1xx 3 0xx 3 1xx Manual 37143A MFR 15 Protection Relay Control ...

Page 2: ...ned off before disconnecting the battery from the system Electronic controls contain static sensitive parts Observe the following precautions to prevent dam age to these parts Discharge body static before handling the control with power to the control turned off contact a grounded surface and maintain contact while handling the control Avoid all plastic vinyl and Styrofoam except antistatic versio...

Page 3: ...ntents CHAPTER 1 GENERAL INFORMATION 7 Introduction 7 Measurement Value Logging 8 Extent of Functions 9 CHAPTER 2 ELECTROSTATIC DISCHARGE AWARENESS 10 CHAPTER 3 INSTALLATION 11 Wiring Diagram up to Version 1 9xx 2 0xx 11 Wiring Diagram from Version 3 0xx 3 1xx 12 Power Supply Standard 13 Wide Range Power Supply Option N 13 Measuring Inputs 14 Generator Voltage 14 Synchronizing Voltage Option Y 14 ...

Page 4: ...c Mode Second Line of the Display Measured Values 35 Display in Automatic Mode Second Line of the Display Alarm Indication 36 CHAPTER 6 CONFIGURATION 37 Basic Data 38 Configuration Access 38 Sealing Until Version 1 9xx 38 Password Starting with Version 2 0xx 3 0xx 40 Change Passwords 41 Direct Configuration from Version 3 0xx 42 Measurement 43 Voltage Measurement 43 Potential Transformer Configura...

Page 5: ...l Profibus DP Slave Option SU 88 Screens for Protocol Modbus RTU Slave Option SU SB 88 Screens for Protocol CAN Bus Options SU SB 89 General Screens for All Interfaces Option SB 90 CHAPTER 7 COMMISSIONING 91 APPENDIX A DIMENSIONS 93 APPENDIX B TECHNICAL DATA 94 APPENDIX C MEASURED QUANTITIES AND ACCURACY 96 APPENDIX D INTERFACE TELEGRAM 97 Communication Interface Addresses 97 Transmission Message ...

Page 6: ... 20 Figure 3 13 Interface CAN bus shielding 20 Figure 3 14 Interfaces CAN bus topology 21 Figure 4 1 Direction of power 28 Figure 5 1 Front panel 32 Figure 6 1 Diagram for independent time overcurrent monitoring 70 Figure 7 1 Dimensions 93 Figure 7 2 Interface cosphi scaling 101 Figure 7 3 Interface Modbus connection 103 Figure 7 4 Interface Profibus DP slave 105 Tables Table 3 1 Conversion chart ...

Page 7: ...nt real power control C power factor control IZ independ ent time overcurrent monitoring M pulse output for kWh PM reverse reduced load and overload moni toring PS unbalanced load monitoring U over undervoltage over underfrequency and voltage asym metry monitoring X analog input for external set point Y synchronisation and ZQ reactive power monitoring Intended Use The unit must only be operated in...

Page 8: ... measurement of the r m s value 1 A 1 5 A 5 Active power The active power is measured though real time multiplication of either the three phase to neutral voltages and the three phase conductor currents or single phase measurement of voltage V12 and the current I1 Reactive power The reactive power is calculated from the measured single phase voltage V12 and the single phase current I1 Power factor...

Page 9: ...toring 2 levels V V U 9 9 9 Three phase over under frequency monitoring 2 levels f f U 9 9 9 Voltage asymmetry monitoring Vas U 9 9 9 Overload monitoring P PM 9 9 9 Reverse reduced power monitoring P P PM 9 9 9 Unbalanced load monitoring Ias PS 9 9 9 Reactive power monitoring loss of excitation monitoring Q Q ZQ 9 9 9 Independent time overcurrent monitoring I I I IZ 9 9 9 Control synchronization f...

Page 10: ...cups cigarette packages cello phane wrappers vinyl books or folders plastic bottles etc away from the control modules and work area as much as possible 4 Opening the control cover may void the unit warranty Do not remove the printed circuit board PCB from the control cabinet unless absolutely necessary If you must remove the PCB from the control cabinet follow these precautions Ensure that the dev...

Page 11: ...ller PID characteristic SYNCHRONIZATION Impulse or holding relay alternatively V a 21 22 lower a I 0 Possible combinations A1 A2 A3 A4 S A6 A8 S 52 Analog output 2 A8 A4 10 V Reference point terminal 4 10 V Auxiliary voltage 75 to 265 VAC or 90 to 300 V DC Input output Psum Analog input 20 mA N NC W O X MFR 15 until version 1 9xx 2 1xx E open collector C kWh or kvarh impulse A1 Relay 2 Relay 1 M R...

Page 12: ...ing relay alternatively V a 21 22 lower a I 0 Possible combinations A1 A2 A3 A4 S A6 A8 S 52 Analog output 2 A8 A4 10 V Reference point terminal 4 10 V Input output Psum Analog input 20 mA NC W O X E open collector C kWh or kvarh impulse A1 Relay 2 Relay 1 M Relay 3 Analog output 1 Common 1 2 2001 07 25 MFR 15 Anschlußplan r15leo 2901 ap skf 17 0 59 56 57 58 18 20 mA 60 12 61 11 10 9 50 51 0 13 16...

Page 13: ...m AWG mm AWG mm AWG mm AWG mm AWG mm 30 0 05 21 0 38 14 2 5 4 25 3 0 95 600MCM 300 28 0 08 20 0 5 12 4 2 35 4 0 120 750MCM 400 26 0 14 18 0 75 10 6 1 50 300MCM 150 1000MCM 500 24 0 25 17 1 0 8 10 1 0 55 350MCM 185 22 0 34 16 1 5 6 16 2 0 70 500MCM 240 Table 3 1 Conversion chart wire size Power Supply Standard 18 to 30 Vdc 7 8 0 V 18 to 30 Vdc Standard Power supply Figure 3 3 Power supply Terminal ...

Page 14: ...is necessary if the generator voltage is connected as a three wire system and the power measurement of the generator power must be three phase If the input for balancing the measuring system is not connected minor inaccuracies will occur during the three phase power measurement Functionality will not be affected if the voltage L3 is not con nected and the power measurement is configured as single ...

Page 15: ...he transducers Generator current 1 A or 5 A L3 L2 L1 N G S2 S1 s2 l s1 k s2 L s1 L s1 k s2 l s1 k s2 l L2 s1 k s2 l 42 43 40 41 44 45 L1 L3 G Figure 3 7 Measuring inputs current Terminal Measurement Description Amax 40 Generator current L1 transformer terminal s1 k 4 mm 41 Generator current L1 transformer terminal s2 l 4 mm 42 Generator current L2 transformer terminal s1 k 4 mm 43 Generator curren...

Page 16: ... 2 5 mm 32 30 Generator power circuit breaker is open 2 5 mm 74 Isolated operation 2 5 mm 75 73 up to Version 2 0xx 3 0xx free starting with Version 2 1xx 3 1xx Remote acknowledgement 2 5 mm with Option G 5 6 Blocking of protective device remote acknowledgement 2 5 mm 31 Enable controller 2 5 mm 32 30 Reply power circuit breaker 2 5 mm 74 Raise set point value 2 5 mm 75 73 Lower set point value 2 ...

Page 17: ... 9 Relay outputs Description Form A contact Amax main make A B 9 10 Relay 1 ready for operation 2 5 mm Form C contact make main break C D E 11 12 13 Relay 2 2 5 mm 14 15 16 Relay 3 2 5 mm 27 28 29 Synchronization pulse holding relay Option Y 2 5 mm Pulse Output Option M B A Pulse output Open collector 24 V DC R 1 kOhm V Figure 3 10 Pulse output Terminal Description Amax A 60 B 61 Pulse output Open...

Page 18: ...puts Description Amax 0 to 20 4 to 20 20 to 20 mA IA 0 V A B 51 50 Analog output 1 Option A2 3 6 1 5 mm 53 52 Analog output 2 Option A3 6 1 5 mm 55 54 Analog output 3 Option A3 6 1 5 mm 82 81 Analog output 4 Option A6 1 5 mm 84 83 Analog output 5 Option A6 1 5 mm 87 86 Analog output 6 Option A6 1 5 mm 0 to 10 10 to 10 V VA 0 V C D 51 Analog output 1 Option A1 4 8 1 5 mm 52 50 Analog output 2 Optio...

Page 19: ...se Common Voltage power factor controller f P controller V power factor contr V power factor contr f P controller 23 24 25 26 Terminal Assignment Description Amax 19 raise 2 5 mm 20 common 2 5 mm 21 common 2 5 mm 22 lower Speed active power controller 2 5 mm 23 raise 2 5 mm 24 common 2 5 mm 25 common 2 5 mm 26 lower Voltage power factor ϕ controller reactive power 2 5 mm Analog Controller Output O...

Page 20: ...L D A B C Interface Profi bus DP Screen A Line GND 5 V E F B Line RTS Figure 3 12 Interfaces Terminal Description A X1 B X2 C X3 D X4 E X5 RxD RTS GND CTS TxD RS 232 A B GND Z RS 422 GND B A RS 485 Modbus RTU Slave RxD RxD NC TxD TxD TTY transmitter drives current GND CAN H CAN L CAN bus A X1 B X2 C X3 D X4 E X5 F X6 Screen 5 V GND A Line B Line RTS Profibus DP the file LEON00D9 GSD has to be used...

Page 21: ...blems T structure bus is utilized stub end feeders or branch lines are not recommended CAN L and CAN H are interchanged Not all devices on the bus are using identical Baud rates Terminating resistor s is are missing Incorrect baud rate too high for length of CAN bus Maximum CAN Bus Length The maximum length of the communication bus wiring is dependent on the configured Baud rate Refer to Table 3 2...

Page 22: ...ve lines like phone lines will destroy the unit CAUTION The connection cable delivered with the DPC must be used between DPC and the unit to ensure proper functionality of the unit An extension or utilization of different cable types for the connection between the unit and DPC may result a malfunction of the unit This may possibly result in damage to compo nents of the system If an extension of th...

Page 23: ...from recognizing fault conditions i e undervoltage underfrequency when the generator is not operating If blocking of these protective functions is not required the discrete input should not be con nected to any potential source The following protective functions cannot be blocked via this discrete input Overvoltage monitoring Overfrequency monitoring Centralized alarm External acknowledgement of t...

Page 24: ...losed ON The load is reduced according to the ramp rated configured in pa rameter Stop sequence ramp and the circuit breaker is opened when the load level reaches 10 of the configured load rating Reply CB is open Terminal 30 32 This DI is energized to signal the unit that the circuit breaker is open Isolated operation Terminal 73 74 Energized Enable voltage frequency control when circuit breaker i...

Page 25: ...peration function is always assigned to relay 1 However other protective functions may also be assigned to relay 1 additionally Relay 1 is always configured as Normally Closed break contact and will de energize if the unit is not ready for operation Relay 2 3 Terminals 11 through 16 Output relay type change over contact The relay manager controls these relays Option Y Synchronization relay Termina...

Page 26: ...a break contact Table 4 1 Operating Modes illustrates the terminals that must be energized 24 Vdc to enable specific control functionality If the input terminal has the symbol in the provided space the energizing 24 Vdc or de energizing 0 Vdc the specific input will not affect the functionality of the control Conditions The device functionality is dependent upon the measured voltages in addition t...

Page 27: ...filled The parameter Synchronizing functions is configured as ON The busbar is energized synchronization voltage The generator voltage and frequency are within the configured permissible limits all three phases The DI Reply CB is open is energized The DI Enable CB is energized Dead Bus Closure of Circuit Breaker Close CB Without Synchronization The power circuit breaker is closed without synchroni...

Page 28: ...own the following values are indi cated Positive generator active load The generator supplies active load Inductive generator power factor The generator is overexcited and supplies Positive reactive power inductive reactive power MAINS G pos pos Q Q P P ind ind GENERATOR MFR 1 CB circuit breaker 40 41 s2 l x2 S2 L X2 X1 S1 K x1 s1 k Figure 4 1 Direction of power ...

Page 29: ...orm lags the voltage waveform thus having a lagging power fac tor Some inductive loads such as electric motors have a large startup current requirement resulting in lagging power factors Capacitive Electrical load whose current waveform leads the voltage waveform thus having a leading power factor Some capacitive loads such as capacitor banks or buried cable result in leading power factors Differe...

Page 30: ...Manual 37143A MFR 15 Protection Relay Control Page 30 119 Woodward Phasor diagram inductive capacitive ...

Page 31: ...vel 1 Option ZC Pow fact 1 Power factor cosphi level 2 Option ZC Pow fact 2 Reactive power capacitive Option ZQ React pow Reactive power inductive Option ZQ React pow Active power surge positive Option ZW Pow shift Active power surge negative Option ZW Pow shift Overvoltage busbar Option US U busbar Undervoltage busbar Option US U busbar Overfrequency busbar Option US f busbar Underfrequency busba...

Page 32: ...on cable there DPC MFR 1 L2 L23 L1 L12 L3 L31 Hz Reversible Display Operating Display Menu Digit Cursor Clear Alarm Converting Controlling Monitoring Select 14 1 2 13 12 4 3 5 7 6 Figure 5 1 Front panel Brief Description of LEDs and Push Buttons LEDs No Description Function 1 Wye Indication of the wye star voltages phase neutral 2 Delta Indication of the delta voltages phase phase 3 Operating Auto...

Page 33: ...Color Yellow Indication of the delta voltages If this LED is illuminated the values indicated on the display are the delta voltages phase phase 3 Operation Color Green Operation This LED is illuminated constantly when the control unit is in the Automatic mode If this LED is flashing the control is in the configuration mode 4 Alarm Color Red Alarm This LED flashes as long as a set point limit is ex...

Page 34: ...is saved by pressing the Select push button once By pressing the button again the user causes the system to advance to the next configuration screen 13 Menu Digit Color none Menu Digit Automatic mode Menu By pressing this button the user advances through the messages displayed on the second line of the dis play Various measured values and any alarm messages that have not been cleared are indicated...

Page 35: ...n The Wye LED is off and the Delta LED is illuminated The delta voltages VL1 L2 VL2 L3 and VL3 L1 of the phase to phase system phase neutral system are indicated The Wye LED is off and the Delta LED is off The phase currents IL1 IL2 and IL3 are displayed Display in Automatic Mode Second Line of the Display Measured Values NOTE The Menu button may be used to scroll through the messages shown on the...

Page 36: ... U Overfreq 1 Overfrequency level 2 Option U Overfreq 2 Underfrequency level 1 Option U Und freq 1 Underfrequency level 2 Option U Und freq 2 Phase shift Option V Phase jmp df dt Option D Fault df Independent time overcurrent level 1 Option IZ Ov curr 1 Independent time overcurrent level 2 Option IZ Ov curr 2 Independent time overcurrent level 3 Option IZ Ov curr 3 Overload Option PM Overload Reve...

Page 37: ...l permit the operator to reverse up to four previous screens exception it is not possible to reverse from the first parameter to the last parameter To perform the reverse function through the parameter screens the Select and Cursor push buttons must be pressed and released simultaneously The control unit will revert to automatic mode if an entry isn t performed a change made or any other action pe...

Page 38: ...omplete Î SEQUENCE DIAGRAM on the following page By entering a five character code number the input operation can be protected from unauthorized access opera tion and modifications The function represents the exact software emulation of a mechanical seal Encoding ON Sealing function ON OFF ON The input of the following values is protected by a code word The subsequent screens of this option are be...

Page 39: ...t NO the code is inquired again Leaving the inquiry is only possible by terminating input mode Code no 000 New code Code for seal 001 new entry 00000 to 60000 After breaking the old seal the unit requests the code number for the new seal Sealing can now be effected with a new code number Adjust Settings SELECT ANWAHL Enter values Button Select Press the button Select for input Code no 000 Breake C...

Page 40: ...is set to CS0 thus locking the device for external persons If for 2 hours uninterruptedly supply voltage is applied the device automatically switches to code level 0 NOTE Starting with Version 2 1xx 3 1xx The following configuration screen Enter code number only appears if the parameter Password Pro tection is configured ON see below Enter code number 0000 Enter code number 0000 to 9999 Upon enabl...

Page 41: ...l is en abled After entering this code the user only has the access rights assigned to this code level This code level CS is preset to CS1 0 0 0 1 Define level 2 code 0000 Define level 2 password 0000 to 9999 This screen appears only when the level 2 password has been entered After enter ing the digits into this screen the code level for level 2 commissioning level is enabled After entering the co...

Page 42: ...ry LeoPC After the PC program has been started establish the communication by pressing the F2 button This will es tablish a data link between the unit and the laptop PC Start the sub program Device Parameterization and adjust the parameter of the unit to your application us ing this manual WARNING If the following parameter Direct parametr is configured to YES communication via the interface termi...

Page 43: ... to calculate the system voltage in the display For voltages measured without a potential transformer secondary and primary voltage must be configured the same Volt transformer prim GN 00 000kV Generator potential transformer primary 00 100 to 65 000 kV The potential transformer primary voltage is set here in kV This entry is used to show the system voltage in the display Volt transformer sec MN 0...

Page 44: ...of operating capacity i e at 100 of system capacity a 5A CT should output 3A If the current transformers are sized so that the percentage of the output is lower the loss of resolution may cause inaccuracies in the monitoring and control functions and may affect the functionality of the control The control may be ordered with either 1 A or 5 A current transformer inputs The CT inputs will dictate h...

Page 45: ... Direction of power on page 27 Rated power 00000kW Rated power 5 to 32 000 kW The rated power is configured here The exact value of the rated power is abso lutely vital Many measurement control and monitoring functions refer to this value e g the percentage input for the power protection Power measuring Power measurement one phase three phase Power measurement may be configured as one phase or thr...

Page 46: ...g functions have been enabled and the subsequent screens of this function are displayed OFF Synchronizing functions have been disabled and the subsequent screens of this function are not displayed Synchronization df max 0 00Hz Maximum permissible positive slip frequency differential for synchr 0 02 to 0 49 Hz This parameter defines the upper permissible frequency differential limit for syn chroniz...

Page 47: ...the phase angle between generator and mains voltage exceeds 14 degrees the discrete input Reply circuit breaker is open is energized The continuous signal does not release and open the circuit breaker if an alarm condition is de tected The breaker must be opened by an external opening circuit Synchronization Time pulse 000ms Minimum pulse time of the breaker close relay 50 to 250 ms The duration o...

Page 48: ...troller if a higher level control i e a PLC is utilized to regulate the breaker functionality of all units in the sys tem The higher level control should only enable the circuit breaker in one lower level controller during a dead bus closure condition by dictating which unit has its Release CB digital input energized and de energizing all other Release CB digital inputs to other units Dead busbar ...

Page 49: ...d set point is continuously adjusted An external correc tion of the set point via actuating signals higher or lower is not possible Variable The set point can be externally corrected within certain limits Set Point Setting Freq controller Setpoint 00 0Hz Frequency controller set point 48 0 to 62 0 Hz The generator frequency set point is defined in this screen This value is the refer ence for the f...

Page 50: ... speed control This prevents unneeded wear on the speed control and or the contacts for terminals 19 20 21 22 The value configured for this pa rameter must be less than half of the value configured for df max maximum frequency differential for synchronization Freq controller Time pulse 000ms Minimum frequency controller ON period 10 to 250 ms The minimum duty cycle for the speed raise lower contac...

Page 51: ...lly adjusted to the configured set point in a mains parallel opera tion The subsequent screens of this function are displayed OFF The active power controller is disabled The subsequent screens of this function are not displayed External Real Power Control Option X External setp Adjustment ON External control of active power set point ON OFF ON External control of the active power set point is enab...

Page 52: ...ge the faster the load reference for the control is increased Example If the rated load for the generator is 100kW and 10 s is configured for this pa rameter The load ramp for the control is 10kW s or it will take 10 seconds for the generator to load to 100 Power limitation P max 000 Active power controller maximum power limitation 10 to 120 The maximum active power of the generator may be limited...

Page 53: ...e relays By increasing the gain the response is increased to permit larger corrections to the active power con trol The farther out of tolerance the active power is the larger the response action is to return the active power to the tolerance band Excessive overshoot undershoot of the desired value will result if the gain is configured too high Analog Controller Outputs Option QF Instead of Three ...

Page 54: ...iable only with Option G GU Lower limit for variable voltage set point value 1 50 to 125 V 4 70 to 440 V The set value indicates the minimum set point value that can be reached with an ex ternal set point selection via that actuating signals lower The smaller voltage value should be entered here Volt controller max value OO0V Set point variable only with Option G GU Upper limit for variable voltag...

Page 55: ...f the control deviation subsequently exceeds 5 0 again the controller s original sen sitivity is automatically reset 2 5 This input can be used in the event of small control deviations to avoid unnecessarily frequent actuation processes thereby protecting the adjustment facility Volt controller Time pulse 000ms Minimum voltage controller duty cycle 20 to 250 ms The minimum duty cycle for the volta...

Page 56: ... NOTE It is vital to ensure that the following variables are properly configured for the controller to operate properly Rated power Primary current Primary voltage If these variables are not configured properly the droop controller and or power factor controller may not operate properly Power factor controller ON Power factor controller ON OFF ON In a mains parallel operation automatic control of ...

Page 57: ... should be entered here Setp pow fact max value O O0 Set point variable only with Option G GU Upper limit with variable power factor set point i0 70 to 1 00 to k0 70 The set value indicates the maximum set point that can be reached with an external selection of the set point via actuating signal higher The greater voltage value should be entered here otherwise the assignment to terminals 6 and 7 h...

Page 58: ...on processes thereby protecting the adjustment facility Pow fact contr Time pulse 000ms Minimum power factor controller duty cycle 20 to 250 ms The minimum duty cycle for the power factor raise lower contacts should be con figured so that the voltage regulator is able to respond reliably to the command is sued It is recommended that the shortest possible time period for this duty cycle be configur...

Page 59: ...rator rated load refer to page 45 the circuit breaker is opened The remaining generators that are participating in the load distribution control assume the load proportionally Message Shutdown achieved Once the measured load of the generator reaches 10 of the generator rated power refer to page 45 a Stop or der message may be issued via the relay manager This message may be used to open the circui...

Page 60: ...es not perform reactive load sharing This requires the voltage controller to be set up for parallel operations i e droop mode Prerequisite The following parameters must be configured identically for each unit that will participate in load sharing Frequency controller set point Active power load sharing must be enabled The discrete input Isolated operation is energized on all units participating in...

Page 61: ...orm active load sharing This requires the speed controller to be set up for parallel operations i e droop mode Prerequisite The following parameters must be configured identically for each unit that will participate in load sharing Voltage controller set point Reactive power load sharing must be enabled The discrete input Isolated operation is energized on all units participating in load sharing R...

Page 62: ...ages is recommended to avoid a phase earth fault in a compensated or isolated mains resulting in the voltage protection tripping The only effect on the screen Voltage measuring is the one described in the above note The settings in the screen Volt Monitoring do have the fol lowing effects on the configuration screens Phase neutral The voltage at the terminals 1 2 3 4 is measured as a four wire in ...

Page 63: ...oltage must ex ceed and remain above the configured threshold without interruption for at least the period of time specified in this screen Screen for Phase neutral Overvoltage 2 Phase N 000V Screen for Phase to phase Overvoltage 2 V ph ph 000V Threshold Phase phase 1 20 to 150 V 4 20 to 520 V overvoltage level 2 Phase neutral 1 10 to 87 V 4 10 to 300 V Overvoltage level 2 is defined by this param...

Page 64: ...must fall below and remain below the configured threshold without interruption for at least the period of time specified in this screen Screen for Phase neutral Undervoltage 2 Phase N 000V Screen for Phase to phase Undervoltage 2 V ph ph 000V Threshold Phase phase 1 20 to 150 V 4 20 to 520 V undervoltage level 2 Phase neutral 1 10 to 87 V 4 10 to 300 V Undervoltage level 2 is defined by this param...

Page 65: ...t displayed Asymmetry Response v 00V Maximum permissible asymmetry 0 to 99 V The maximum voltage asymmetry is defined by this parameter If this limit is reached or exceeded the unit outputs the message Asymmetry If a relay was assigned to this function in the relay manager that relay will be energized Asymmetry Delay 00 00s Pickup delay 0 02 to 99 98 s In order to initiate a voltage asymmetry alar...

Page 66: ...gized Overfrequency 1 Delay 00 00s Pickup delay level 1 0 02 to 99 98 s In order to initiate an overfrequency level 1 alarm the measured frequency must exceed and remain above the configured threshold without interruption for at least the period of time specified in this screen Overfrequency 2 f 00 00Hz Threshold overfrequency level 2 40 00 to 80 00 Hz Overfrequency level 2 is defined by this para...

Page 67: ...nderfrequency 1 Delay 00 00s Pickup delay level 1 0 02 to 99 98 s In order to initiate an underfrequency level 1 alarm the measured frequency must fall below and remain below the configured threshold without interruption for at least the period of time specified in this screen Underfrequency 2 f 00 00Hz Threshold underfrequency level 2 40 00 to 80 00 Hz Underfrequency level 2 is defined by this pa...

Page 68: ...t monitoring is disabled and the subsequent screens of this function are not displayed Phase jump monit Vector phase shift monitoring one three phase 3 phase only one three phase An alarm will be issued if the phase angle in any one phase ex ceeds the configured phase shift phase angle limit Monitoring of single phase voltage is exceptionally sensitive and may lead to nui sance tripping if the con...

Page 69: ...can be suppressed with the discrete input Blocking of protective functions remote acknowledgement df dt Monitoring ON df dt monitoring ON OFF ON Rate Of Change Of Frequency monitoring is enabled The subse quent screens of this function are displayed OFF Rate Of Change Of Frequency monitoring is disabled The subse quent screens of this function are not displayed df dt Response 0 0Hz s Tripping df d...

Page 70: ...ing ON Independent time overcurrent monitoring ON OFF ON Independent time overcurrent monitoring is enabled The subsequent screens of this function are displayed OFF Independent time overcurrent monitoring is disabled The subsequent screens of this function are not displayed Overcurrent 1 I 000 Threshold independent time overcurrent level 1 0 to 300 Overcurrent level 1 is defined by this parameter...

Page 71: ...configured rated system current refer to page 44 If this limit is reached or exceeded the unit outputs the message overcur rent 3 If a relay was assigned to this function in the relay manager that relay will be energized Overcurrent 3 Delay 00 00s Pickup delay level 3 0 02 to 99 98 s In order to initiate an overcurrent level 3 alarm the measured current must exceed and remain above the configured ...

Page 72: ... here refers to the configured rated power refer to page 44 If this limit is reached or exceeded the unit outputs the message overload If a relay was assigned to this function in the relay manager that relay will be energized Overload Delay time 000s Pickup delay 0 to 300 s In order to initiate an overload alarm the measured active load must exceed and remain above the configured threshold without...

Page 73: ...displayed Reverse min pow 00 Threshold reverse reduced power 99 to 99 Reverse power monitoring If the direction of the active power reverses and the measured power value falls below the configured negative percent age value the unit issues the message Rev Power Reduced power monitoring If the measured power falls below the configured positive percentage value the unit issues the message Rev Power ...

Page 74: ...000 Maximum permissible unbalanced load 0 to 100 The maximum unbalanced load refers to the measured three phase currents If an asymmetrical load causes the phase currents to exceed the configured percentage for the configured time the unit displays the alarm message Unbalance If a relay was assigned to this function in the relay manager that relay will be ener gized Unbalanced load Delay 00 00s Pi...

Page 75: ...ored is set in this mask If the value is either reached or exceeded inductive or fallen below capacitive the unit issues the message cosphi 1 If additionally a relay was configured via the relay manager an output is also made to this relay cosphi 1 Delay 00 00s Delay cos ϕ level 1 0 02 to 99 98 s For a tripping to occur the threshold must be exceeded without interruption for at least the period of...

Page 76: ... relay will be energized Cap react pow Delay 00 00s Pickup delay 0 02 to 99 98 s In order to initiate a capacitive reactive power alarm the measured capacitive reac tive load must exceed and remain above the configured differential threshold with out interruption for at least the period of time specified in this screen Ind react pow Response v 000 Threshold reactive power inducitive 0 to 100 The i...

Page 77: ... Load shift or Load shift appears These message can be separately controlled via the relay manager and can be suppressed with the discrete input Blocking of protective device remote acknowledgement Act power shift Monitoring 000 Load Shift Monitoring ON OFF ON A load shift is being monitored and the subsequent masks of this function are displayed OFF Monitoring is not carried out and the subsequen...

Page 78: ...s of this op tion are not displayed Start next gen at 000 Boost command threshold 0 to 120 The value of the active power that is to be monitored is set in this screen If the value is reached or exceeded the unit outputs the message Boost if a relay is con figured via the relay manager The function has no indication in the display Start next gen Delay 000 0s Boost command pickup delay 0 to 320 0 s ...

Page 79: ... is reached or exceeded the unit outputs the message U busbar If a relay is also parameterized via the relay manager the output still occurs also on this relay Busbar overvolt Delay 00 00s Pickup delay 0 02 to 99 98 s In order to trip monitoring the threshold value must be exceeded without interrup tion for at least the period of time specified in this screen Busbar undervolt V 000V Undervoltage 2...

Page 80: ...r If a relay is also parameterized via the relay manager the output still occurs also on this relay Busbar overfreq Delay 00 00s Pickup delay 0 02 to 99 98 s In order to trip monitoring the threshold value must be exceeded without interrup tion for at least the period of time specified in this screen Busbar underfrq f 00 00Hz Underfrequency threshold value 40 00 to 80 00 Hz The underfrequency valu...

Page 81: ...nowledgement Acknowledgement via the discrete input ON OFF Auto clearing Relays configured OFF refer to Auto Acknowledge ment of the Relays on page 82 OFF Alarms that cannot be blocked with discrete input Blocking of pro tective functions remote acknowledgement will not be reset when the fault condition is no longer present Pressing the Clear button resets the relays ON All alarms are reset when t...

Page 82: ...turned to the permissible limits plus minus the hysteresis depending on monitoring without interruption for the time specified in this pa rameter If the monitored value exceeds falls below the threshold limit the delay timer re initiates its countdown The following protective functions may have reset delays configured Monitoring for Display indication instead of xxxxxxxx Remark Overvoltage Option ...

Page 83: ...igured Refer to the list of parameters YES The relay assignments can be configured and the user may define the relay functionality and assignments The subsequent screens are dis played NO The relays are configured with the factory default settings The sub sequent screens are not displayed NOTE All relay outputs are configured the same The following is an example showing relays 1 through 3 Example ...

Page 84: ...isplay instead of xxxxxxxxxx Boost Option PZ Start next gen Overvoltage level 1 Option U Overvoltage 1 Overvoltage level 2 Option U Overvoltage 2 Undervoltage level 1 Option U Undervoltage 1 Undervoltage level 2 Option U Undervoltage 2 Asymmetry Option U Asymmetry Overfrequency level 1 Option U Overfrequency 1 Overfrequency level 2 Option U Overfrequency 2 Underfrequency level 1 Option U Underfreq...

Page 85: ...se or positive the collec tor output terminal 60 61 is energized for each positive kWh pulse Active energy Pulse kWh 000 0 Pulses per positive kWh 0 1 to 150 0 The quantity of pulses per measured kWh is defined here The pulses issued by this controller must be analyzed by an external control Example If this parameter is configured as Pulse kWh 020 00 and 20 kWh are measured the number of pulses th...

Page 86: ... and upper setting value 0 V 10 V 0 mA 4 mA 20 mA 10 V 20 mA Vol 1 0 to 65 000 V LeoPC1 0 to 32 000 V Vol 2 0 to 65 000 V LeoPC1 0 to 32 000 V Vol 3 0 to 65 000 V LeoPC1 0 to 32 000 V Vol ph N AV 0 to 65 000 V LeoPC1 0 to 32 000 V Vol ph N max 0 to 65 000 V LeoPC1 0 to 32 000 V Vol ph N min 0 to 65 000 V LeoPC1 0 to 32 000 V Vol 1 2 0 to 65 000 V LeoPC1 0 to 32 000 V Vol 2 3 0 to 65 000 V LeoPC1 0...

Page 87: ...ut OFF The analog output is not enabled The subsequent screens of this function are not displayed The only variable that may be changed for this parameter is the lower value for this analog output The upper limit is always 10 V 10 10 V 10 V is the configured low limit for the analog output 0 10 V 0 V is the configured low limit for the analog output OFF The analog output is not enabled The subsequ...

Page 88: ...word RK512 0 to 255 Data word address in receiver e g PLC Screens for Protocol Profibus DP Slave Option SU Device number Profibus 000 Device number profi bus DP slave 0 to 126 Device number for the profi bus DP slave Screens for Protocol Modbus RTU Slave Option SU SB Device number MOD Bus 000 Device number Modbus RTU Slave 1 to 255 Device number for the Modbus RTU Slave Baudrate 0000 Baud rate Mod...

Page 89: ...ber 2 ID 802 etc Device number CAN Bus 0 Device number CAN bus 1 to 8 The device number at CAN bus is entered here The device number affects the cal culation of the transmitting and controlling IDs Baudrate 0000 Baudrate CAN Bus 125 250 500kBaud Setting the baudrate Base ID send 0000 Basic ID Transmission 0 to 2015 The ID from which the device is transmitting its operating data is calculated from ...

Page 90: ...these bits are not read within the prescribed time and unsuccessful data exchange is detected and the alarm message Interface is is sued OFF The interface monitoring is disabled Interface fault to relay 0000 Relay assignment for interface error 0 to 3 0 to 8 Relays may be configured to energize when an interface fault is detected The de sired relays that to energize are configured here The relays ...

Page 91: ...d correctly apply the control system voltage i e 24 Vdc The Operation LED will illuminate 2 After applying the measured variables the unit indicates the various measuring values which can be veri fied with a measuring instrument 3 By simultaneously pressing the two push buttons Digit and Cursor the configuration mode is ac cessed After entering the access code number the unit may be configured acc...

Page 92: ... Enter code number 0 to 9999 On accessing the parameterization mode a code number which identifies the vari ous users is first requested The indicated number XXXX is a random number ZU and is confirmed using the Select button If the random number was con firmed without modification using Select the code level remains as it was Two four digit code numbers 0000 to 9999 exist for changing the code le...

Page 93: ...nsions r1ww 0503 ab skf 70 75 45 16 32 17 50 130 96 8 90 130 72 65 27 35 61 50 40 1 70 75 45 16 32 17 X5 X1 Option S Option A6 A8 Back view with connecting terminals Bottom view Back plate mounting optionally Front view alternative Configuration plug Configuration plug Configuration plug Configuration plug Figure 7 1 Dimensions ...

Page 94: ...surge voltage 1 2 5 kV 4 4 0 kV Measuring frequency 40 0 to 80 0 Hz Accuracy Class 1 Resistance 0 1 Linear measuring range 1 3 Vrated Input resistance 1 0 21 MΩ 4 0 7 MΩ Maximum power consumption per path 0 15 W Measuring current isolated Measuring current Irated 1 1 A 5 5 A Accuracy Class 1 Linear measuring range 3 0 Irated Power consumption 0 15 VA Rated short time current 1 s 1 100 0 Irated 5 2...

Page 95: ...0 to 10 Vdc outpu Internal resistance 1 kΩ Interface isolated Insulation voltage 3000 Vdc Version variable Housing Type APRANORM DIN 43 700 Dimensions W H D 96 72 130 mm Front cutout W H 91 1 0 67 0 7 mm Wiring Screw type terminals depending on connector 1 5 mm 2 5 mm or 4 mm Recommended tightening torque 1 5 mm 2 5 mm 0 5 Nm 4 mm 0 6 Nm use 60 75 C copper wire only use class 1 wire only or equiva...

Page 96: ... depending on the configured transformer ratio Re active power Actual value in L1 L2 L3 32 0 to 32 0 Mvar 2 Accuracy depending on the configured transformer ratio Apparent power Actual value in L1 L2 L3 0 to 45 0 MVA 2 Accuracy depending on the configured transformer ratio Power factor cos ϕ Actual value cos ϕL1 c0 00 to 1 00 to i0 00 1 5 Miscellaneous Active energy 0 to 4200 GWh Reference conditi...

Page 97: ...MUX 4 3 11 Power factor cosphi dim less 100 24 25 13 26 27 MUX 5 1 12 Real power kW 26 27 14 28 29 MUX 5 2 13 Reactive power kvar 28 29 15 30 31 MUX 5 3 14 Busbar voltage L12 V 30 31 16 32 33 MUX 6 1 15 Busbar voltage L12 Hz 100 32 17 34 MUX 6 2 16 dim less VGN 33 17 35 MUX 6 2 16 Exponent dim less IGN 34 18 36 MUX 6 3 17 dim less PGN QGN 35 18 37 MUX 6 3 17 Exponent dim less VSS 36 37 19 38 39 MU...

Page 98: ...ernal alarms 3 Bit 15 1 Bit 14 0 Power factor level 1 Bit 13 1 Bit 12 0 Power factor level 2 Bit 11 1 Bit 10 0 Inductive reactive power Bit 9 1 Bit 8 0 Capacitive reactive power Bit 7 1 Bit 6 0 Positive real power surge Bit 5 1 Bit 4 0 Negative real power surge Note example bit 15 14 Bit 3 1 Bit 2 0 Overcurrent level 2 0 1 alarm not triggered 1 0 alarm triggered Bit 1 1 Bit 0 0 Interface fault 46 ...

Page 99: ... Bit 5 1 Bit 4 0 Internal Note example bit 15 14 Bit 3 1 Bit 2 0 Zero voltage 0 1 alarm not triggered 1 0 alarm triggered Bit 1 1 Bit 0 0 Power level reached 50 51 26 52 53 MUX 9 2 25 Internal alarms 6 Bit 15 1 Bit 14 0 Ground fault Ue level 1 Bit 13 1 Bit 12 0 Internal Bit 11 1 Bit 10 0 Internal Bit 9 1 Bit 8 0 Internal Bit 7 1 Bit 6 0 Internal Bit 5 1 Bit 4 0 Ground fault Ue level 2 Note example...

Page 100: ...requency fSetpoint Hz 100 3200 to 6800 7 08 09 5 10 11 Setpoint voltage VSetpoint V 0 to 480 8 10 11 6 12 13 free 1 The transmitted number has a sign When connected correctly capacitive inductive 100 means power factor 1 2 This control bit is ignored if the screen Blocking via interface is set to OFF 3 Corresponds to the digital input Release isolated operation terminal 73 74 4 Option Y G Correspo...

Page 101: ... power 0 to 9999 with sign measured in var data format two s complement positive inductive negative capacitive Frequency measured in Hz 100 Real energy 32 Bit measured in kWh data format two s complement positive exported real energy negative imported real energy power factor 99 to 100 measured in cos phi 100 positive inductive generator over excited negative capacitive generator under excited Sca...

Page 102: ... 4 123 104 W 1 230 000 W 1 23 MW PGN 803 exponent 2 803 102 W 80 300 W 80 3 kW fGN 5230 5230 Hz 100 52 30 Hz 52 3 Hz cos phi 87 87 Cos phi 100 0 87 Cos phi i0 87 Bit Change at Tripping of a Watchdog Function If one of the watchdog functions protective alarms trips the corresponding bits for example bit 15 14 over frequency limit 2 will change from not tripped 0 1 to tripped 1 0 ...

Page 103: ...ng its control line RTS to ON The prerequisite of this is that no data are received CTS OFF The receiver regis ters this status and indicates its readiness to receive by switching its RTS line to ON The transmitter can then begin transmitting when it detects this ON status on its CTS line As soon as the receiver withdraws its RTS signal RTS OFF the transmitter interrupts its transmission and waits...

Page 104: ...d as follows all word vari ables are in the high byte low byte format Byte 1 Multiplexer Byte 2 3 1 data word note table no 1 multiplexed MUX 1 1 Byte 4 5 2 data word note table no 2 multiplexed MUX 1 2 Byte 6 7 3 data word note table no 3 multiplexed MUX 1 3 etc Configuration Data Option SF ID ID configure default value 831 No ID s can be assigned twice in the system This applies for all devices ...

Page 105: ...account Byte 1 The bit 0 is used as a watchdog If monitoring is switched ON in the configuration screen this bit must be toggle every 4 seconds The unit monitors this and possibly triggers a fault and reinitializes the interface Byte 8 9 Control word 1 Byte 10 11 Control word 2 Byte 12 13 Control word 3 Connection Example 2003 01 24 Datenkopplung 2003 01 24 skf A B External unit PLC According to t...

Page 106: ...rmer sec MN 50 to 125 50 to 480 V 100 400 V Volt transformer prim MN 00 100 to 65 000 kV 00 400 kV Current transf 1 999 x A 1 000 x A G GU Rated voltage 5 to 125 10 to 480 V 100 400 V G GF Rated frequency 40 0 to 70 0 Hz 50 0 Hz Rated current 1 to 9 999 A 1 000 A Rated power 5 to 32 000 kW 500 kW Power measuring one phase three phase three phase s t s t CONTROL FUNCTIONS Y Synchronizing ON OFF ON ...

Page 107: ...Setpoint 50 to 125 V 70 to 440 V 100 400 V G GU Setpoint voltage min value 50 to 125 V 70 to 440 V 90 360 V Setpoint voltage max value 50 to 125 V 70 to 440 V 1190 440 V Setpoint voltage Gradiant 1 to 20 V S 2 V S G GU Setpoint voltage Ramp 1 to 20 V S 2 V S G GU Y Volt controller Dead band 0 1 to 15 0 V 0 5 to 60 0 V 3 0 V Volt controller Sens red 1 0 to 9 9 2 0 Volt controller Time pulse 20 to 2...

Page 108: ...frequency 2 Delay 0 02 to 99 98 s 0 04 s Overfrequency Hysteresis 0 01 to 9 99 Hz 0 05 Hz Underfrequency Monitoring ON OFF ON 1 0 1 0 Underfrequency 1 f 40 00 to 80 00 Hz 49 8 Hz Underfrequency 1 Delay 0 02 to 99 98 s 0 10 s Underfrequency 2 f 40 00 to 80 00 Hz 49 0 Hz Underfrequency 2 Delay 0 02 to 99 98 s 0 04 s U Underfrequency Hysteresis 0 01 to 9 99 Hz 0 05 Hz V Phase jump monitoring ON OFF O...

Page 109: ...sis 0 to 99 V 1 4 V Busbar frequency Monitoring ON OFF ON 1 0 1 0 Busbar overfreq f 40 00 to 80 00 Hz 50 2 Hz Busbar overfreq Delay 0 02 to 99 98 s 0 10 s Busbar underfrq f 40 00 to 80 00 Hz 51 0 Hz Busbar underfrq Delay 0 02 to 99 98 s 0 10 s US Busbar frequency Hysteresis 0 01 to 9 99 Hz 0 05 Hz RELAY CONFIGURATION External Clearing ON OFF ON 1 0 1 0 Auto clearing Relays ON OFF ON 1 0 1 0 U Rele...

Page 110: ... D df dt to relay 0 to 3 0003 IZ Overcurrent 1 to relay 0 to 3 0002 IZ Overcurrent 2 to relay 0 to 3 0002 PM Overload to relay 0 to 3 0003 PM Reverse power to relay 0 to 3 0003 PS Load unbalance to relay 0 to 3 0002 ZW Neg load jump to relay 0 to 3 0002 ZW Pos load jump to relay 0 to 3 0002 ZQ cap Reactive power to relay 0 to 3 0002 ZQ ind Reactive power to relay 0 to 3 0002 ZC Power factor 1 to r...

Page 111: ... of this parameter list i 0 50 Analog output 3 OFF 20 to 20mA 0 to 20 mA 4 to 20 mA 20 to 20mA OFF 20mA 0 20mA 4 20mA OFF 20mA 0 20mA 4 20mA A3 6 A4 8 OFF 10 to 10 V 0 to 10 V 10 to 10V OFF 10V 0 10V OFF 10V 0 10V Analog output 3 Current L1 Analog output 0 10 mA 0 4 20 mA 0 A A3 6 A4 8 Analog output 10 V 20 mA see table at the end of this parameter list 1000 A Analog output 4 OFF 20 to 20mA 0 to 2...

Page 112: ... parameter list 500 kvar Analog output 8 OFF 20 to 20mA 0 to 20 mA 4 to 20 mA 20 to 20mA OFF 20mA 0 20mA 4 20mA OFF 20mA 0 20mA 4 20mA A8 OFF 10 to 10 V 0 to 10 V 10 to 10V OFF 10V 0 10V OFF 10V 0 10V Analog output 8 Apparent power Analog output 0 10 mA 0 4 20 mA 0 kVA A8 Analog output 10 V 20 mA see table at the end of this parameter list 500 kVA INTERFACE CONFIGURATION S3964 Data block RK512 0 t...

Page 113: ...PC1 0 to 32 000 V Vol ph ph max 0 to 65 000 V LeoPC1 0 to 32 000 V Vol ph ph min 0 to 65 000 V LeoPC1 0 to 32 000 V Frequency 40 00 to 80 00 Hz Current L1 0 to 9 999 A Current L2 0 to 9 999 A Current L3 0 to 9 999 A Current AV 0 to 9 999 A Current max 0 to 9 999 A Current min 0 to 9 999 A Direct Cur 11 9 999 to 9 999 A Direct Cur 21 9 999 to 9 999 A Direct Cur 31 9 999 to 9 999 A Dir Current AV1 9...

Page 114: ...cases your problem can be resolved over the phone If not you can select which course of action you wish to pursue based on the available services listed in this section Returning Equipment for Repair If a control or any part of an electronic control is to be returned to Woodward for repair please contact Wood ward in advance to obtain a Return Authorization Number When shipping the unit s attach a...

Page 115: ...epartment in Stuttgart 49 711 789 54 0 They will help expedite the processing of your order through our distributors or local service facility To expedite the repair process contact Woodward in advance to obtain a Return Authoriza tion Number and arrange for issue of a purchase order for the unit s to be repaired No work can be started until a purchase order is received NOTE We highly recommend th...

Page 116: ... following international Woodward facilities to obtain the address and phone number of the facility nearest your location where you will be able to get information and service Facility Phone number USA 1 970 482 5881 India 91 129 409 7100 Brazil 55 19 3708 4800 Japan 81 476 93 4661 The Netherlands 31 23 566 1111 You can also contact the Woodward Customer Service Department or consult our worldwide...

Page 117: ... toll free or local phone numbers e mail us or use our website and refer ence technical support Product Training is available on site from several of our worldwide facilities at your location or from GE Global Controls Services depending on the product This training conducted by experienced personnel will as sure that you will be able to maintain system reliability and availability For information...

Page 118: ..._________________ Control see name plate Unit no and Revision P N ____________________ REV ____________ Unit type MFR 15____________________________________ Serial number S N _______________________________________ Description of your problem _______________________________________________________________ _______________________________________________________________ _____________________________...

Page 119: ...se 29 70565 Stuttgart Germany Phone 49 711 789 54 0 Fax 49 711 789 54 100 stgt info woodward com Homepage http www woodward com power Woodward has company owned plants subsidiaries and branches as well as authorized distributors and other authorized service and sales facilities throughout the world Complete address phone fax e mail information for all locations is available on our website www wood...

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