Gen part 6000 руководство по эксплуатации

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please help i need genpart 6000 control panel manual

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1

FG Wilson Product Training: 6000 Series Control System
Malachy Roscoe

2

Agenda Basics and Terminology of Synchronisation Load Control Methods
6000 Features 6000 Applications The 6000 Series Controller Reprogramming and Calibration Communications Options

3

Q. What do we mean by synchronisation?
In terms of power generation, synchronisation is the matching of the output voltage waveform of one alternating current electrical generator with the voltage waveform of another alternating current electrical system. For two systems to be synchronised, five conditions must be matched:

4

Q. What are the five conditions of synchronisation?
The number of phases in each system The direction of rotation of these phases The voltage amplitudes of the two systems The frequencies of the two systems The phase angle of the the voltage of the two systems

5

Number of Phases G Mains or Generator
The generating set of the oncoming system must have the same number of phases as those of the system it is to be paralleled: L1 L1 L2 L2 Mains or Generator G L3 L3

6

Phase Rotation Each generator or system being paralleled must be connected so that all phases rotate in the same direction.

7

Voltage Match The voltages generated by the systems being paralleled must be within a small percentage of one another, typically 1-5%. .

8

Voltage Match If two systems of unequal voltage are paralleled, the difference in voltages result in reactive currents and lowered efficiency If a generator is paralleled to the mains, a difference in voltage before paralleling will not change the voltage of the bus In the above instance, if the generator voltage is much lower than the bus voltage the generator could be motorised.

9

Frequency Match The voltages generated by the systems being paralleled must be within a small percentage of one another, typically 1-5%. .

10

Phase Angle Match The phase relationship between the voltages of the systems must be very close prior to paralleling. This match usually is within +/- 10 degrees.

11

Synchronisation Q. Why is synchronisation important?
When two or more systems are paralleled to the same distribution system, the power sources must be synchronised properly. Without proper synchronisation of the oncoming system, power surges and mechanical or electrical stresses will result when the breaker is closed.

12

Synchronisation Incorrect synchronisation under the worst conditions can lead to:- Voltage’s being twice the rated voltage One system can place a dead short on the other High currents placing both systems under stress Bent shafts and broken coupling discs Power surges which build on each other until both systems are disabled

13

Synchronisation Q. How is synchronisation accomplished?
Normally, one generating system is used to establish the common bus and then the oncoming generator is then synchronised by changing the speed of the prime mover driver the oncoming generator. This can be done manually or automatically.

14

Peak Load Control Peak Load Control refers to limiting the power purchased from the mains supplier. Electrical rates for large industrial users are usually calculated by the peak demand on the mains during a given time. Sometimes a peak demand lasting as brief as 15 minutes out of a 30 day period will determine the charge levelled for all the power purchased during that 30 day period. Peak Load Control can avoid over priced power bills by either: Load Shedding as power levels reach the max defined level Base loading Peak Shaving

15

Base-loading Power Demand
Base-loading is the operation of a generator at a constant output. When load demand exceeds the generator output capacity, power will be imported from the mains. If the base-loading exceeds the load demands, power may be exported to the mains grid. Power Demand Mains Supplied Load Generator Supplied Time

16

Peak Shaving Power Demand
Peak shaving is used to set a limit on the maximum amount of power taken from the mains. The example below shows a maximum import from the mains as 100kW. Load Power Demand Generator Supplied 100kW Mains Supplied Time

17

Import/Export Power Demand
Import Power and Export Power are terms used to describe power taken by the site load (import) or supplied to the mains grid (export) Load Power Demand Import Power Generator Capacity Site Demand Time

18

Import/Export Power Demand
Import Power and Export Power are terms used to describe power taken by the site load (import) or supplied to the mains grid (export) Power Demand Load Generator Capacity Export Power Site Demand Time

19

Zero Import (Export) Control
A generator — or series of generators — is able to supply all the site power demand. This situation usually relies on generators to start and stop as demand fluctuates — Automatic Sequencing. Load Generator System Capacity Site Demand Generator Supplied Time

20

Automatic Synchronisation
A system that will automatically synchronise two systems it must have the able to: Monitor the voltage and frequencies from both systems to be paralleled Bias the voltage on the alternator and speed of the engine Issue a breaker close command

21

Automatic Synchronisation
Bus Electronic Governor Engine Synchroniser Speed Bias Signal Alternator Close Breaker Signal Voltage Regulator Generator Voltage Breaker Typical Auto-Synch System Load

22

6000 Series Controller Automatic Synchroniser
Automatic Sequencing (up to 8 Generators) Proportional Load Sharing (kW/kVAr) 4 Applications for Parallel/No Parallel and Single/Multiple Engine & Generator Protections Available in 12 Languages

23

Language Options English German Swedish French Danish Italian Finnish
Icelandic Norwegian German French Italian Dutch Portuguese Spanish

24

Engine Monitoring Oil Pressure Over/Under Alarm/Shutdown Settings
Water Temperature Battery Voltage Overspeed Alarm/Shutdown Settings

25

Auto-Start Function Programmable Auto Start on Loss of Mains
All units in Auto mode with Loss of Mains detection enabled start and close onto load bus Multiple Crank Repeat Setpoint Crank Repeat Timer Crank Fail Alarm/Shutdown Crank Cutout (RPM) Preglow

26

Generator Monitoring 3 Phase Over/Under Voltage Over Current
Reverse Power Loss of Excitation Over/Under Frequency Stable Generator Determined by Being within Voltage and Frequency Limits for a given period of time

27

Mains Monitoring Over/Under Voltage Over/Under Frequency Load Surge
Programmable for Alarm/Loss of Mains Detect Loss of Mains Action Timer Stable Mains determined by being within Voltage and Frequency Limits for a Given period of time

28

Synchronising Phase Match Synchronisation 3 Mode Operation
run, check, permissive Voltage Matching Dead Bus Closing Synch Timer Reclose Attempt/Timer

29

Load Control Proportional Load Sharing
Integrating Base Load and Process Control Load Ramping Remote Contact Inputs to change Base Load and Process Setpoints with Raise/Lower ramp rates Unload Trip point Droop Load Control Capability

30

Sequencing Each Unit in the system has an assigned Priority
Master (Highest Priority) automatically sequences units on or off line as determined by system load. Higher priority units are sequenced on in order of their priority; taken off in reverse of priority

31

Sequencing System Load setpoints determine percent system load level at which additional units will be brought on, or taken off line Time setpoints determine period of delay for sequencing units on/off line Separate time delay for overload (100%+) system load levels so additional units can be sequenced on line quickly

32

Reactive Load Control Var or Power Factor Load Control in Mains Parallel operation Power Factor Sharing in Load Sharing, No Parallel operation Externally adjustable VAR/PF reference Manual Voltage Control Capability

33

Mains Transfer Functions
Loss of Mains Action Timer Fast Transfer Timer Sets transfer time to/from Mains Mains Stable Timer Gen Stable Timer Up to 8 generator system can re-synchronise across the mains tie on parallel transfer

35

6000 Series Controller Max No. Units Genset Parallel Mains Parallel
6101 1 NO NO 6201 8 YES NO 6301 1 YES NO 6401 8 YES YES

36

6000 Series Controller: 6100 Single Unit No Parallel-6100 Mode (AMF) G
LOAD

37

6000 Series Controller: 6100 Single Unit No Parallel-6100 Mode (AMF)
No Mains PT or Mains C.B. Aux Contact Volt Free Start Signal Load Transfer Functions and Mains Failure Detection Handled Externally Open Load Transfer (External Changeover) Isochronous Load Control Dead Bus Closing

38

6000 Series Controller Typical 6000 Switch Configuration AUTO TEST OFF
RUN

39

FG Wilson Schematic for 6000 Series Control Mode Switch

40

6000 Series Controller: 6100 Single Unit No Parallel-6100 Mode (AMF)
Auto Unit waits for external start signal (AMF) Test Starts engine — if mains fails will power load Run Same as Test

41

6000 Series Controller: 6100 Single Unit Prime Power G LOAD

42

6000 Series Controller: 6100 Single Unit Prime Power
No Mains PT Required No Mains Aux. Required Dead Bus Closing Isochronous Load Control

43

6000 Series Controller: 6100 Single Unit Prime Power Auto
Starts Engine and Runs On Load Test Same as Auto Run Same as Auto and Test

44

6000 Series Controller: 6200 Multi Unit, No Parallel-6200 Mode (AMF) G
Up to 8 Generators G G G LOAD

45

6000 Series Controller: 6200 Multi Unit, No Parallel-6200 Mode (AMF)
Redundancy of Master Units No Mains PT or C.B. Aux Required Dead Bus Closing Isochronous Load Sharing Load Transfer Functions and LOM Detection handled externally Load Dependant Auto Sequencing

46

6000 Series Controller: 6200 Multi Unit, No Parallel-6200 Mode (AMF)
Auto Awaits Volt Free Start Signal Enables Automatic Sequencing Enables Dead Bus Closing Test Starts Engine; no further action If Volt Free Start Signal received closes to bus Run Starts Unit, and Syncs to local bus or alternatively closes to dead bus

47

FG Wilson Schematic for 6000 Series Control Mode Switch for Master 6200

48

FG Wilson Schematic for 6000 Series Control Mode Switch for Master 6200
GST 1GSR 1GTR

49

6000 Series Controller: 6200 When the changeover system senses that the mains has failed relays GSR (Gen Start Relay) will switch its contacts to give the 6000 an AUTO input and also a RUN input through GTR (Generator Timer Relay). This is so that Auto Sequencing will not be enabled for a timed period, GST. Once the time delay on GST (Gen Start Timer) has expired 1GTR will energise and switch its contacts removing the RUN input to the 6000, this means that Auto Sequencing will be enabled and generators will sequence ON/OFF line as required.

50

6000 Series Controller: 6200 Multiple Unit-6200 Mode (Prime Power) G G
Up to 8 Generators G G LOAD

51

6000 Series Controller: 6200 Multiple Unit-6200 Mode (Prime Power)
No Mains PT No Mains Aux. Dead Bus Closing Load Dependant Auto Sequencing

52

6000 Series Controller: 6200 Multiple Unit-6200 Mode (Prime Power)
Auto Will Start the unit in Auto and it will close its gen breaker to the load Enables Auto Sequencing Enables Dead Bus Closing Test Same as Auto but engine always runs Run Starts Unit and allows unit to close gen breaker to the dead bus, or synchronize to a live bus if other generators are already on line. Unit cannot be sequenced off-line

53

6000 Series Controller: 6300 Single Unit Parallel — 6300 Mode G M M
LOAD

54

6000 Series Controller: 6300 Single Unit Parallel — 6300 Mode
Mains PT sensing Mains C.B. Aux Contact Auto input and software setpoints enable Loss Of Mains Detection Isochronous Load Control on isolated bus Dead Bus Closing Soft Re-Transfer from generator to mains on Return of Mains

55

6000 Series Controller: 6300 Single Unit Parallel — 6300 Mode
Auto Position on Control Switch Enables LOM Detection Test Position on Control Switch Starts Engine; no other action LOM Detection Enabled Run Position on Control Switch Synchronises and Ramps to Base Load

56

6000 Series Controller: 6300 Single Unit Parallel — 6300 Mode
Process Switch When individually selected No Action Process Switch ON and Run on Control Switch Synchronises and Ramps to Process Reference with LOM detection Enabled

57

6000 Series Controller: 6300 Single Unit Parallel — 6300 Mode
Process Switch OFF and Run on Control Switch Synchronises and Ramps to Base Load If “Load Control Mode” is set for Soft Transfer in configuration menu, unit will open mains breaker when base load reference is reached.

58

6000 Series Controller: 6300 Single Unit Parallel — 6300 Mode
Process Switch ON and Run on Control Switch Synchronises and Ramps to Process Reference Will open mains breaker/contactor upon reaching Process Reference if “Load Control Mode” setpoint in configuration menu is set for Soft Transfer.

59

6000 Series Controller: 6400 Multiple Unit, Mains Parallel (6400 Mode)
External PLC ControlLogic G M M M G G LOAD

60

6000 Series Controller: 6400 Multiple Unit, Mains Parallel (6400 Mode)
Redundancy of Masters Mains C.B. Aux to all units (through PLC control) Mains PT input to all units (through PLC control) Loss of Mains Detection (through PLC control) Dead Bus Closing Isochronous Load Sharing when Isolated from Mains Base Load, Process, or Soft Transfer Control while in parallel with mains Load Dependant Auto Sequencing in Load Sharing or Process Control

61

Controller Interface Two 16 character, 4 line back lit LCD displays with adjustable contrast Large Keys with tactile feedback Alarm/Shutdown LED indicator Operator Input Keys (up, down, commit, escape, etc.) maintain common functions throughout all controller displays and modes.

62

Hardware 12 or 24 VDC supply voltage
10 Amp /125 VAC (6 Amp 277 VAC) Relays Isolated Power Supply +/- 3VDC Speed Bias Output +/-1, 3 or 9 VDC Voltage Bias Output

63

Hardware RS-422 PC interface network
Multi Drop, Multi Unit access from PC RS-485 Load Sharing network Intercontrol communications 4 Control inputs determining operating mode Auto, Test, Run and Process

64

Keypad Detail Vertical Keys AlarmReset Commit Escape
Resets Alarms Enters Setpoints Escapes Setpoints Clears Alarm Ind Enters Menus Escapes Menus Commits Faults

65

Keypad Detail Horizontal Keys Up Key Down Key Left Key Right Key
Moves Cursor Moves Cursor Moves Cursor Moves Cursor Increments Val. Decrements Val.

66

Keypad Detail Right Hand Double Action Keys Upper Key
Selects Status Menu Two Presses Selects Control Overview Screen (From any Menu) Lower Key Selects Tuning Menu Selects Setpoint Entry

67

Screen Detail Top six lines (blue section) — Status Display
Bottom two lines (white section) — Tunables Display

68

Status Menus Status Menus CONTROL OVERVIEW ENGINE OVERVIEW
GEN OVERVIEW GEN PHASES SYNCHROSCOPE ALARM/EVENT LOG

69

Status Menus Status Menus (continued) I/O STATUS SEQUENCING
-Accessed by pressing the down arrow to scroll down through status menu screen.

70

Status Menus Control Overview Engine off Line UNIT: 1 ALARMS: 0
MAINS: GEN: AUTO OFF UNIT: 1 PRIORITY: 1

71

Status Menus Engine On Line on Isolated Bus UNIT: 1 ALARMS: 0
ENGINE: RUN MAINS: GEN: AUTO ISOCH UNIT: 1 PRIORITY: 1

72

Status Menus Engine Base Loaded To Mains UNIT: 1 ALARMS: 0 ENGINE: RUN
MAINS: GEN: AUTO BASELOAD UNIT: 1 PRIORITY: 1

73

Status Menus Multiple Unit Control Overview Screen UNIT: 1 ALARMS: 0
ENGINE: RUN MAINS: GEN: AUTO BASELOAD UNIT: PRIORITY:

74

Status Menus Engine Overview H2O OIL BATT XXC XXb XX.XV TIME DATE RPM
12: DD-MM KW-HRS RUN TIME 1996

75

Status Menus Engine Overview
To set the time and date in the engine overview menu, supervisor password clearance (2nd level), is required. If this password is used, then the commit key on the 6000 control can be used to access the time and date display. The displayed time and date are then changed using the up/down and left/right arrows on the Pressing the commit key saves these values.

76

Status Menus Gen Overview (Voltage Line to Line) #1 A B C
Hz: KW: 00.0 PF: 1.00 LAGGING (LOAD CONT. STATUS) 65

77

Status Menus Gen Phases (Voltage Line to Neutral) 1 A B C
KW kvar kva 66

78

Status Menus Synchroscope Slip Phase Volts **** **** ****
**** **** **** Mains/Bus: Mains Dead Bus: Yes (SYNCHRONIZER STATUS) A: U: 0.0 67

79

Status Menus Alarm/Event Log Unack Faults: 0 Faults Listing:
None Recorded 68

80

Status Menus Alarm/Event Log Unack Faults: 2 Faults Listing: OVERSPEED
: LOW OIL PRESSURE : 69

81

Status Menus Alarm/Event Log
Records and Logs Shutdown/Alarm events in chronological order. Most recent alarms appear at the top of the screen, with “oldest” alarms towards the bottom of the list. Requires Operator (1st level) security to acknowledge alarms. Use up/down arrows to scroll through multiple alarm log. 70

82

Status Menus Alarm/Event Log
Supervisor (2nd Level) Security Code required to clear alarms from Log Committing alarm/shutdown will save the alarm in the Log and allow unit to operate Clearing alarm/shutdown will remove the alarm from the Log and allow the unit to operate 71

83

Status Menus I/O Status (X Indicates Active input/output)
X X DO: X X Volt Bias: Speed Bias: 72

85

Discrete Inputs 1- Automatic Switch 2- Test Switch
3- Run with Load Switch 4- Volts Raise 5- Volts Lower 6- Speed Raise 7- Speed Lower 73

86

Discrete Inputs 8- Gen Circuit Breaker Aux Contact
9- Mains Circuit Breaker Aux Contact 10- Process Switch Remote Alarm/Shutdown Inputs 74

87

Discrete Outputs 1- Mains Breaker Close/Contactor Close
2- Gen. Breaker/Contactor Close 3- Engine Preglow 4- Fuel Solenoid 5- Engine Crank 6- Visual Alarm Relay 75

88

Discrete Outputs 7- Local Bus PT Connect 8- Mains PT Disconnect
9- Mains Breaker Trip 10- Gen Breaker Trip 11- Audible Alarm 76

89

Status Menus Sequencing Menu Unit: 1 Oper: Prty: 1 Master Unit: 1
Next On: All Next Off: 77

90

Status Menus Sequencing Menu (Multi-Unit) Unit: 1 2 3 4 5 6 7 8
Oper: X X X Prty: Master Unit: 1 Next On: 2 Next Off: 5 78

91

Program Setpoints for Single/Multiple operation
Parallel or No Parallel setpoints Multiple Level Security Codes Real Load Sharing, Soft Transfer, Base Load and Process Control Functions Reactive Load Sharing and Var/PF Control 20

92

Configuration Menus Security Code Required For Access
All Items in Configuration Menu must be Committed before engine operation will be allowed. Uncommitted items will have an asterisk (*) next to them on the screen. All Generator Parameters must be within ranges as defined by the following: PT and CT ratios Voltage Reference 79

93

Configuration Menus Security Code 4 Levels Of Access Operator (8448)
Access to Alarm Log and Network Priority Supervisor (3494) Allows access to Network Address and Time Set in addition to above access. Technician (9251) Allows access to all setpoints except calibration Factory (****) Allows access to all setpoints 80

94

Configuration Menus There are 8 menus that may be accessed (dependant on Password): Configuration Shutdowns and Alarms Engine Control Synchroscope Real Load Control Reactive Load Control Process Control Calibration Menu 80

95

Configure Menu Network Address (1 to Network Priority (1 to
Unique Address for Each Unit in the System Maximum of 8 units on network Network Priority (1 to Unique Priority for Each Unit in the System Lowest Active Priority is considered Master Sequencing effective from lowest to highest priority 81

96

Configure Menu Number of Poles (numeric) Number of Teeth (numeric)
Determines Speed/Frequency Relationship Used for Speed/Frequency Mismatch Alarm/Shutdown Number of Teeth (numeric) Determines RPM Scaling Engine Speed Readouts/Alarms 82

97

Configure Menu System Frequency (50/60 Hz.)
Used as a basis for generator waveform analysis Defines typical operating frequency of generator 83

98

Configure Menu Rated Speed (numeric)
Synchronous Speed Of Generator Set Used in Speed Calculation to determine “sample” period for MPU input Speed Governor sets this operating point on the engine 84

99

Configure Menu Rated KW (numeric) Rated KVA (numeric)
Rated KW of Generator Rated KVA (numeric) Used to determine Rated Current of Generator Equation: I=KVA/Rated Voltage 85

100

Configure Menu Rated KVAR (numeric) Rated KVAR of Unit
Typically 0.6 x Rated KVA 86

101

Configure Menu Rated KVA must be less than or equal to the Voltage Reference x CT Ratio Primary Rated KW must be less than or equal to the Rated KVA Rated KVAR must be less than or equal to the Rated KVA Any Values Falling out side of these ranges will appear on the screen with a pound sign (#) next to them. This indicates the value is out of range, and the engine will not operate until the # symbol is cleared by entering the correct values. 87

102

Configure Menu AC Power Triangle KVA KVAR KW 88

103

Configure Menu CT Ratio (numeric :5)
Scales sensed CT input for Amperage as seen at generator Used for Load Sensing Algorithm (KVA,KW,KVAR,PF) Used for Alarms/Shutdowns Over Current, KW Limits,Reverse Current, etc. 89

104

Configure Menu PT Ratio (numeric : 1)
Scales sensed PT input to Voltage Levels as measured at the Generator Used in Load Sensing Algorithm (KVA, KW, KVAR, PF) Used for Voltage Matching Used for Generator Frequency Detection Used for Alarm/Shutdown sensing Over/Under Frequency Over/Under Voltage KW Limits, etc. 90

105

Configure Menu 6000 Potential Transformer
50Vrms 320V 250V 130V 64V 0V Voltage into primary winding must never exceed tapping rating Use caution if reconnecting alternator winding and ensure that the PT Ratio settings reflect the tapping point used on transformers Primary Secondary

106

Configure Menu PT Ratio 250:50 PT Ratio = 5:1 G 6000 380/220 VAC
91

107

Configure Menu Voltage Input (Wye L-N, Delta L-L)
Set for sensing/transformer used between generator and Gen Part 6000. Defines which calculations will be used for KW, KVA, KVAR, etc. 92

108

Configure Menu Wye (Star) Generator or Transformer Connection 4 Wire
Volts Line to Neutral Delta Generator or Transformer Connection 3 Wire Volts Line to Line 93

109

Configure Menu 3 phase True RMS sensing of Voltages and Currents
Delta or Wye (Star) PT inputs 4 wire CT input Configurable for a wide range of 50/60 Hz. systems up to 30 MW per unit. Distortion/Harmonic filtering for accuracy 94

110

Configure Menu Voltage Reference (numeric)
Operating Voltage of Generator per Generator Spec. Used for Var/PF Sharing as the Reference that multiple generators share reactive load to. This maintains the voltage reference while in Power Factor Sharing mode on an isolated bus. 95

111

Configure Menu Load Control Mode Normal Soft Transfer Droop
Standard setting for load control and VAR/PF functions Soft Transfer Standard load control and VAR/PF functions, but unit will issue mains breaker open command while in process control if process reference is reached, or while in base load and base load reference is reached. Droop Manual Load and Voltage Control Used primarily for commissioning 96

112

Configure Menu Process Action (direct, indirect)
Defines action of speed bias when unit is operating in process control in parallel with the mains. Direct action = Unit increases speed bias (fuel) to increase process ma input Indirect action = Unit decreases speed bias (fuel) to increase process 4-20 ma input. 97

113

Configure Menu Process Import/Export Hardware
6000 Control Can take a 4-20 mA, or 1-5 VDC input signal from a transducer. Input signal conditioning is selected by a dip switch on the back of the control 8 7 6 5 4 3 2 1 Switch 8 ON for 4-20 mA input. OFF for 1-5 VDC input SW-2 101

114

Configure Menu Circuit Breaker Control (Breaker/Contactor)
Defines action of Generator and Mains closure command Breaker issues momentary close signal, momentary open signal independently. Contactor issues continuous close signal. Removes this signal to open contactor. 102

115

Configure Menu Check Mains Breaker (enabled/disabled)
Used to activate checking of mains c.b. aux. input when enabled If disabled, unit relies on other units with this setpoint enabled to broadcast state of mains c.b. aux. contact over network 104

116

Configure Menu Operating Mode Mains Parallel or No Parallel
Mains Parallel will allow the unit to synchronise to the mains, and carry load while in parallel with the mains as well. No Parallel will not allow the unit to operate with load until the mains breaker is sensed as being open All units operating in a load sharing system must be set for the same parameter, i.e. mains parallel, or no parallel. 105

117

Configure Menu Number of Units (single, multiple)
Defines whether unit is part of a mulitple unit system or not. If single unit, there is no auto starting, auto sequencing,load or pf sharing with other units under any circumstances. Unit displays “single unit no sequencing” on sequencing screen. If multiple unit, auto starting, auto sequencing, load and var/pf sharing are active between all units in multiple. Unit displays system sequencing information on sequencing screen. 106

118

Configure Menu Automatic Mode (enabled/disabled)
Enables or Disables Auto Sequencing for that unit Can be used to disable sequencing for a particular unit in a sequencing system if needed 107

119

Configure Menu 422 Protocol (Modbus, Servlink, Upload Setpoints)
Allows selection of how the 422 Protocol will be used. Modbus is selected when the industry standard protocol ModBus is required to be utilised, controller must be re-booted if this option is selected Servlink is selected when operating with PC Tools, controller must be re-booted if this option is selected Upload Setpoints is selected when an electronic copy of the configuration file is required and should only be used by FG Wilson personnel 107

120

Shutdowns & Alarm Menu Shutdowns and Alarms menu is used to configure the various safety functions of the Gen Part 6000. 108

121

Shutdowns & Alarm Menu Each alarm setpoint can be set for : Disabled
Warning LED on Control Flashes Visual Alarm LED Flashes, and Visual Alarm relay energises Audible Alarm LED Flashes, Visual and Audible Alarm relays energise 109

122

Shutdowns & Alarm Menu Soft Shutdown Hard Shutdown
LED Turns On, Visual and Audible Alarm relays energise, Unit soft unloads and cycles through cool down timer when applicable. Hard Shutdown Same as above, but immediately opens generator breaker and de-energises fuel solenoid 110

123

Shutdowns & Alarm Menu Loss of Mains /Loss of Mains w/Alarms
Additional alarm setpoint used in the following: Mains over/under voltage Mains over/under Frequency Load Surge 111

124

Shutdowns & Alarm Menu Load Surge (numeric %/sec)
Used only in Base Load or Process Control (Mains Parallel Operations) Set to trigger at a percent setpoint of total generator load shift per second while operating in Mains Parallel Can be set for Loss of Mains Detection Instantaneous Trigger 112

125

Shutdowns & Alarm Menu Main Volt High Limit (numeric)
Alarms when Mains Voltage exceeds Alarm Setpoint. Alarm can be set for Loss of Mains If Mains Voltage is above High Limit, Mains are not considered stable, and the 6000 control will not issue a mains breaker closure command. 113

126

Shutdowns & Alarm Menu Mains Volt Low Limit (numeric)
Alarms when Mains Voltage drops below setpoint Alarm can be set for Loss of Mains If Mains Voltage is below Low Limit, Mains are not considered stable, and the 6000 control will not issue a mains breaker closure command. 114

127

Shutdowns & Alarm Menu Main Freq. High Limit (numeric)
Alarms when Mains Frequency exceeds Alarm Setpoint. Alarm can be set for Loss of Mains If Mains Frequency is above High Limit, Mains are not considered stable, and the 6000 control will not issue a mains breaker closure command. 115

128

Shutdowns & Alarm Menu Mains Freq. Low Limit (numeric)
Alarms when Mains Frequency drops below setpoint Alarm can be set for Loss of Mains If Mains Frequency is below Low Limit, Mains are not considered stable, and the 6000 control will not issue a mains breaker closure command. 116

129

Shutdowns & Alarm Menu LOM Action Delay (numeric seconds)
Sets Time Delay for LOM Action to begin once Loss of Mains is detected. Typically Delay time From LOM to engine start command 117

130

Shutdowns & Alarm Menu Voltage Range Alarm (enabled, disabled)
Alarm/Shutdown point for an excess of voltage bias signal from the GCP to AVR Preset to trigger at +/- 100% voltage bias output. 118

131

Shutdowns & Alarm Menu Generator high/low voltage alarms
Generator High Voltage Limit (Voltage Bias Cutout) Rated Generator Voltage Operating Range Generator Low Voltage Limit (Voltage Bias Cutout) 119

132

Shutdowns & Alarm Menu Gen Volt High Limit (numeric)
Sets maximum allowable generator voltage level If voltage is above High Limit, generator is not considered stable, and is unfit for breaker closure. Gen Volt Low Limit (numeric) Sets minimum allowable generator voltage level If voltage is below Low Limit, generator is not considered stable, and is unfit for breaker closure 120

133

Shutdowns & Alarm Menu Generator High/Low Volt Limits
Even if the Alarm Setpoints for the High/Low Limits are Disabled, the Voltage Bias will not allow adjustment beyond these limits. The same is true for the synchroniser, which will not allow a gen breaker closure if the High or Low Voltage limits are met or exceeded. 121

134

Shutdowns & Alarm Menu Generator Freq High Limit (numeric)
Sets maximum allowable generator frequency level If frequency is above High Limit, generator is not considered stable, and is unfit for breaker closure. Generator Freq Low Limit (numeric) Sets minimum allowable generator frequency level If frequency is below Low Limit, generator is not considered stable, and is unfit for breaker closure 122

135

Shutdowns & Alarm Menu Generator Over/Under Frequency Opegrating Range
Generator High Frequency Limit (Speed Bias Cutout) Synchronous Speed (50/60 Hz) Opegrating Range Generator Low Frequency Limit (Speed Bias Cutout) 123

136

Shutdowns & Alarm Menu Generator High/Low Freq. Limits
Even if the Alarm Setpoints for the High/Low Limits are Disabled, the Speed Bias will not allow adjustment beyond these limits. The same is true for the synchronizer, which will not allow a gen breaker closure if the High or Low Frequency limits are met or exceeded. 124

137

Shutdowns & Alarm Menu Spd/Freq Mismatch (enabled/disabled)
Compares generator frequency to engine RPM and alarms on difference Used to indicate loss of MPU, or Loss of Generator Field Voltage 125

138

Shutdowns & Alarm Menu Overspeed (numeric)
Set for overspeed limit of engine Typically set for Hard Shutdown for safety Typically Set for 10% above Rated Speed of engine 126

139

Shutdowns & Alarm Menu Over Current Level (numeric) 3 Phase Sensing
Set for Per Phase Overcurrent Over Current Detection begins when current exceeds rated current as determined by Voltage Reference and Rated KVA values in Configuration menu Uses Inverse Time Function as basis for overcurrent detection. This allows different levels of overcurrent based on time span. 127

140

Shutdowns & Alarm Menu Overcurrent Inverse Time Function amps
Per Phase amps Overcurrent Trip Zone overcurrent level 100% rated current time overcurrent delay 128

141

Shutdowns & Alarm Menu Over Current Level High Current, Short Duration
amps Overcurrent Trip Zone overcurrent level time overcurrent delay 129

142

Shutdowns & Alarm Menu Overcurrent Level
Notice area of over current is the same amps Overcurrent Trip Zone overcurrent level time overcurrent delay 130

143

Shutdowns & Alarm Menu Reverse Power Level (numeric)
Reverse Power Condition begins when sensed KW on generator goes negative. Reverse Power Trip levels depend upon amplitude and duration of reverse power condition. Reverse Power Delay (numeric) Reverse Power also uses an inverse time function. 131

144

Shutdowns & Alarm Menu Reverse Power KW + Time KW — Reverse Power
Delay KW + Time KW — Reverse Power Reverse Power 132

145

Shutdowns & Alarm Menu Loss of Exictation (LOE) (numeric)
Set as a percentage of total KVAR load on the generator that can be applied as a block reactive load to the unit. If control senses changes in KVAR loads instantly applied greater than this value the LOE alarm triggers. Used to indicate loss of field excitation to the generator 133

146

Shutdowns & Alarm Menu Battery Volt High Limit (numeric)
Sensed DC voltage supply to 6000 control Can be used to detect faulty charging circuit Battery Voltage Low Limit (numeric) Used to detect weak battery/failed charger Automatically Disabled during engine cranking 134

147

Shutdowns & Alarm Menu Approaching High H2O Temp. (numeric)
Uses engine mounted temp sensor Active once Gen is considered stable Sensed in degrees C Low H2O Temp. (numeric) Useful for detection of failed jacket water heater Always Active 135

148

Shutdowns & Alarm Menu High Oil Pressure (numeric)
Uses Engine mounted pressure sensor Active when generator is stable Sensed in Bar Approaching Low Oil Pressure Used to sense failure of lube oil system 136

149

Shutdowns & Alarm Menu External Faults #1 through #6
Each fault is programmable for: disabled warning visual alarm audible alarm soft shutdown hard shutdown 137

150

Shutdowns & Alarm Menu External Faults #1 and #2
15 second delay for activation after reaching crank cutout speed. Used for oil pressure and water temp switch inputs External Faults #3 through #6 Instant action Always active 138

151

Engine Controls Menu Preglow Time
Time of preglow allowed prior to engine crank cycle Maintained through engine cranking Resets after every crank attempt 139

152

Engine Controls Menu Crank Time Crank Cutout Crank Delay
Maximum Allowable Time for Engine Cranking Crank Cutout Engine RPM level where crank command is canceled Crank Delay Time between Engine Crank Attempts 140

153

Engine Controls Menu Crank Repeats Crank Fail
Number of times 6000 control will attempt to re-start engine. Cranking attempts will equal the value of Crank Repeats +1. Crank Fail Alarm Setpoint Activates when Number of Crank Repeats is depleted. 141

154

Engine Controls Menu Cooldown Time
Time allowed for cooldown once engine achieves a stop cycle Must exceed Cooldown Limit (see next display) before activated 142

155

Engine Controls Menu Cooldown Limit
KVA setpoint at which, when exceeded, will cause the engine to go to a cooldown during a stop cycle 143

156

Engine Controls Menu Engine Run Time MW Hours
Hours of Run Time on Engine Increments in hours Retained in EE memory — Does not require power to maintain previous value MW Hours MW Hours on Generator Increments in .1 MWH Retained in EE memory 144

157

Synchroscope Menu Synchronizer Mode Permissive
Acts as a synch check device. 6000 will not issue speed or voltage bias commands, but if synchronization conditions are within spec (phase and voltage), control will issue a breaker close command. 145

158

Synchroscope Menu Check
Used for checking synchronizer prior to commisioning 6000 control actively synchronizes generator by issuing speed and voltage bias commands, but does not issue breaker closure command 147

159

Synchroscope Menu Run Normal operating mode
Actively synchronizes and issues breaker closure command 6000 control MUST be in RUN to operate as a dead bus closing device. In multiple unit systems 6000 control MUST have AUTO input active to enable dead bus closing 148

160

Synchroscope Menu Synchronizer Gain Synchronizer Stability
Sets Gain of Synchronizer speed bias output Synchronizer Stability Sets Stability of Synchronizer speed bias output Both Gain and Stability are used to tune the synchronizer dynamic response. 149

161

Synchroscope Menu Gain and Stability Gain (Output/Input)
Too little gain: Sluggish Response with Large Overshoot Phase Transient Low Gain Output Too much gain: Rapid cycling of engine speed High Gain Output 150

162

Synchroscope Menu Gain and Stability Stabililty (Integrator dx/dt)
phase match line Large value Long return to phase match condition phase match line Small value Rapid return to phase match condition 151

163

Synchroscope Menu Voltage Matching (enabled or disabled)
Enables/Disables Voltage Matching feature of 6000 control Enables VoltageWindow Setpoint Voltage Window (numeric) Overall percentage of error allowed between generator and bus, or generator and mains 6000 control will not issue a breaker closure if error is greater than voltagewindow 152

164

Synchroscope Menu Voltage Matching (1% setpoint) Gen Voltage High
Bus or Mains Voltage 381.9 VAC +0.5% 380 VAC 378.1 VAC — 0.5% Gen Voltage Low 153

165

Synchroscope Menu Max. Phase Window
Maximum allowable phase angle deviation from phase matched condition. 6000 Control will not issue breaker closure if phase angle between generator and bus, or generator and mains exceeds this window 154

166

Synchroscope Menu Max. Phase Window =10 degrees
-10 +10 Must be within +/- 10 deg window for breaker closure 155

167

Synchroscope Menu Dwell Time (numeric)
The period of time that the generator must be within the Max. Phase Window for before the 6000 control will issue a breaker closure Longer dwell times will give typically give better stability after the breaker closes Shorter dwell times reduce amount of time required to synchronize unit 156

168

Synchroscope Menu C.B. Hold Time Close Attempts
Time in Seconds that Breaker/Contactor Close output is held after breaker close command is issued Close Attempts Number of Close Attempts allowed while synchronizing Close attempt incremented if breaker does not send back continuous CB aux signal to 6000. 157

169

Synchroscope Menu Reclose Delay Synch Reclose Alarm
Time in Seconds before 6000 control attempts resynchronization after failed closure attempt Synch Reclose Alarm Alarm setpoint if number of close attempts is depleted 158

170

Synchroscope Menu Synchronizer Time Out
Sets time allowed for synchronization in seconds Begins timing when synchronizer activates Active for all gen and mains breaker open/close commands from 6000 control A setting of zero (0) seconds disables synch. timeout — infinite synch time allowed Synch Timeout Alarm Sets alarm mode if sych timeout is exceeded 159

171

Synchroscope Menu Dead Bus Closure
Enables/Disables Dead Bus Closing Feature Unit must be within voltage and frequency high/low limits to be considered for dead bus closure. Dead Bus Closure uses Token Passing Scheme to assure that only one unit in a networked system will close onto the dead bus at any given time. Mulitple unit systems must have Auto switch input to allow dead bus closing between networked units 160

172

Real Load Control Menu Load Control Gain Load Share Gain
Sets gain response of load control Active in load ramping and base load operations Load Share Gain Sets gain response of proportional load sharing Active in load sharing operations 161

173

Real Load Control Menu Load Stability Load Derivative
Sets Stability response of load control Active in load ramping and base load operations Load Derivative Sets Derivative response of load control 162

174

Real Load Control Menu Load Control Filter
Low Pass Filter used to attenuate higher frequency transients for better stability Active in proportional load sharing, load ramping, and base load control modes Higher values of filter will tend to make the unit more responsive to small, rapid transients Lower values of filter will tend to make the unit less responsive to small, rapid transients 163

175

Real Load Control Menu Base Load Unload Trip
Load Level Generator will automatically ramp to when operating in Base Load Unload Trip Load Level where Generator Breaker/Contactor open command will be issued when 6000 control is off loading generator set 164

176

Real Load Control Menu Load Droop Load Time
Percentage of KW droop used when 6000 control is operating in a droop mode Load Time Time in Seconds for generator to load from unload trip level to base load level. This rate is applied during any automatic loading function, including ramping to load sharing 165

177

Real Load Control Menu Unload Time
Time in Seconds for generator to unload from base load level to unload trip level. This ramp rate is applied during any automatic unload functions, including ramping from load sharing 166

178

Real Load Control Menu Raise Load Rate Lower Load Rate
Pecent Load per Second ramp rate used when the raise load contact input is used during base load operation. Lower Load Rate Percent per Second Ramp Rate used when the load lower input is active in base load control operation 167

179

Real Load Control Menu Gen. Load High Limit Gen High Limit Alarm
Maximum allowed load while operating in Base load or Process control modes Prevents overload of unit Gen High Limit Alarm Sets alarm mode when unit is at or above High Load Limit Active during all load control operations 168

180

Real Load Control Menu Gen. Load Low Limit Low Load Limit Alarm
Minimum allowed load while operating in Base load or Process control modes Prevents reverse current of unit Low Load Limit Alarm Sets Alarm Mode when unit is at or below Low Load Limit Active during all load control operations 169

181

Real Load Control Menu Fast Transfer Delay
Time required for a transition in switching from Mains to Generator operations, and from Generator to Mains operations. This includes transition times between bus and mains sensing. Mains Stable Delay Period of time required for the mains to be declared stable before transition from generator(s) to mains. 170

182

Real Load Control Menu Gen Stable Delay
Period of time generator must be declared stable before transition from Mains to Generator, as well as dead bus closing 171

183

Real Load Control Menu Next Genset Delay
Period of time that will pass before master auto sequences an additional generator on line. Delay is effective only in active master unit 172

184

Real Load Control Menu Max. Gen Load
% system load on all units with gen breakers closed, and on the same network, in Auto,and in Load Sharing or Process control modes, at which active master unit will begin timing to sequence next unit on line. 173

185

Real Load Control Menu Rated Load Delay
Delay when system load exceeds 100%, before master starts next genset in sequence Overload condition fast sequence operation Rated Load Delay function overrides load ramping on unit being sequenced on line. That unit will immediately assume its proportion of the system load. 174

186

Real Load Control Menu Max. Start Time
Time allowed by master to see next unit to be sequenced on line in an “active” condition, i.e. started and ready to load. This is determined by a flag, which indicates the unit is ready to load, is sent over the network by the unit being sequenced on by the master. If master does not detect this flag within the Max. Start Time allowed, it will go to the next lower priority unit and try starting it, or if no other units are available, it will retry the command on the same unit. 175

187

Real Load Control Menu Reduced Load Delay
Time in seconds which the active master waits before sequencing units off line. Delay is effective only on active master unit Lowest priority units are sequenced off line first 176

188

Real Load Control Menu Min. Gen. Load
% of system load at which active master begins timingto sequence units off line Master may have to wait until system load is below this level if unit next in line to be sequenced off will cause the system load to increase above the Max Gen Load setpoint of the Master. 177

189

Real Load Control Menu Max. Stop Time
Time in seconds allowed by master for slave to sequence off line Master begins sequencing next lowest priority unit off line if system load is still above Min. Gen. Load setpoint at the end of the Max Stop Time Limit 178

190

Reactive Load Control Menu
Var/PF Mode Disabled Unit does not PF share, or control PF under any circumstances VAR Control Unit PF shares in isolated bus load sharing mode Unit controls KVAR in Base Load and Process Control Modes PF Control Unit controls PF in Base Load and Process Control Modes 179

191

Reactive Load Control Menu
Var/PF Gain Controls Gain Response of unit in Var/PF control mode NOT active in PF sharing mode Var/PF Share Gain Not Active in any modes Var/PF Stability Controls Stability Response of unit in Var/PF control mode 180

192

Reactive Load Control Menu
Voltage Ramp Time Ramp time from 0 to +/-100% voltage bias output Controls response of units in PF sharing modes Controls ramp time of voltage during synchronization Controls ramp time of voltage during manual voltage adjust 181

193

Reactive Load Control Menu
KVAR Reference When KVAR control mode is selected, this references the amount of KVAR the generator will produce while in Base Load or Process control modes Can be set for generate or absorb levels of KVAR KVAR levels limited by Rated KVAR of unit 182

194

Reactive Load Control Menu
PF Reference PF level that will be maintained by the generator while in Base Load or Process control modes. Can be set for leading or lagging power factor Scaled from 0 (unity) to -.5 (.5 leading) to +.5 (.5 lagging) 183

195

Reactive Load Control Menu
PF Deadband +/- deadband around PF reference point set in PF Active in PF and PF sharing modes Can be used to stabilise units at low loads if needed 184

196

Process Control Menu Process Dynamics
Process Master Uses Process PID to control Gain, Stability, Derivate, Filter, Droop Slaves to the Process Master use Load Control PID Values to track master system load reference Load Gain, Stability, Derivate, Filter 185

197

Process Control Menu Process Gain
Sets system gain response while in process control Effective at active master unit only. Slaves rely on Load Control dynamic settings to control response to master load reference Should be set with maximum number of units operating in process control mode 186

198

Process Control Menu Process Stability
Sets system stability response while in process control Effective at active master unit only. Slaves rely on Load Control dynamic settings to control response to master load reference Should be set with maximum number of units operating in process control mode 187

199

Process Control Menu Process Derivative
Sets system derivative response while in process control Effective at active master unit only. Slaves rely on Load Control dynamic settings to control response to master load reference Should be set with maximum number of units operating in process control mode 188

200

Process Control Menu Process Droop
Introduces negative feedback on the process reference as the process input increases Used to add stability to marginally stable processes 189

201

Process Control Menu Process Filter
Low Pass Filter attenuates higher frequency transients on process 4-20 mA input signal The higher the filter is set, the more active the process control will be to higher frequency process transients The lower the filter is set, the less active, and more stable the process control will be to higher frequency process transients 190

202

Process Control Menu Process Reference
The reference point, in mA, at which the master will control the process input. Also used in Soft Transfer modes to set the level of process at which the transfer from mains to generator will occur 191

203

Process Control Menu Raise Rate
Rate, in mA/Sec., at which the process reference will change when the 6000 control receives a raise load contact input while operating in process control mode 192

204

Process Control Menu Lower Rate
Rate, in mA/Sec., at which the process reference will change when the 6000 control receives a lower load contact input while operating in process control mode 193

205

Process Control Menu Process High Limit Process High Limit Alarm
Maximum allowable process reference level. Set in mA Effective on active master unit only Process High Limit Alarm Sets alarm mode when process High Limit is reached 194

206

Process Control Menu Process Low Limit Process Low Limit Alarm
Maximum allowable process reference level. Set in mA Effective on active master unit only Process Low Limit Alarm Sets alarm mode when process reference reaches the Low Limit 195

207

Calibration Menu While each unit will be factory calibrated at FG Wilson prior to shipment, there are bound to be some inputs/outputs affected by external wiring and/or interfaces (relays, transformers, etc..) that will require calibration at the site during commissioning. The Calibration Menu allows calibration of all the analog inputs to the 6000 control, as well as the speed bias and voltage bias outputs. 196

208

Calibration Menu All calibration points in the 6000 control are used to make the actual value of an input, such as generator voltage, read out on the respective display screen of the 6000 control the proper value of the signal being monitored. Example: 380VAC measured line to line on the generator should read 380VAC in the line to line voltage measurement area of the 6000 control “generator overview” menu. Any differences between the measured and actual values can be corrected using the generator PT calibration points in the calibration menu. 197

209

Calibration Menu Process input Scale
Actual Input mA, or 1- 5VDC process signal from external transducer. Monitor the Pin (process in) reading in the Load Control Monitor menu Calibrate Process input scale until Pin reads accurately what measured process signal is. Engine must be in a test or run mode and operating to observe the Pin value in the Load Control Monitor menu 198

210

Calibration Menu Measured vs Monitored 380.2 VAC Measured L-L G
Monitored Volts L-L in Gen Control Overview 380.2 VAC Measured L-L A B C 380.2 380.2 PT phase A scale 2.356 Calibrate monitored to equal measured in Calibration menu. G 199

211

Calibration Menu Speed Bias Offset
Factory calibrated for 0VDC offset on +/- 3 VDC range. All Woodward Speed controls operate with this bias output, so no calibration should be required Calibration may be required for other manufacturer’s speed controls… 200

212

Calibration Menu Voltage Bias Offset Factory set for zero Volts DC.
Dip Switch selectable +/- 1VDC, +/- 3 VDC, +/- 9 VDC range. Some regulators require a positive voltage bias offset because they cannot recieve a negative voltage bias command. 6000 control will always reset to the voltage bias offset when off line. 201

213

Calibration Menu Typical AVR with Aux input +/- 1 VDC input from 6000
trim Trim Adj. Internal Trim adjustment potentiometer sets effective range of +/- 1 VDC bias from 6000 control. Usually a +/- 10% voltage change for the +/-1VDC input is more than sufficient for good VAR and PF control. Volts 202

214

Calibration Menu Typical AVR with external Voltage adjust Potentiometer +/- VDC input from 6000 Pot. Volts 203

215

Calibration Menu PT Phase B Scale; PT Phase C Scale PT Phase A Scale
Calibrates PT phase A voltage input Monitor Gen Overview (Volts L-L), or Gen Phases (Volts L-N) and adjust PT Phase A scale until these values match measured generator voltage on A phase PT Phase B Scale; PT Phase C Scale Same as above, but for B and C phases of Gen. 206

216

Calibration Menu CT Phase A Scale
calibrates CT Phase A sensing of 6000 control Load generator and monitor gen. currents in phase overview menu. Measure actual gen. currents with clamp on ammeter, or panel ammeter. Calibrate phase A CT reading in phase overview. 207

217

Calibration Menu CT Phase B Scale; CT Phase C scale
Same as CT setup for phase A. If CT polarity is reversed, that phase will read negative KW when loaded in the Phase overview menu. If CTs are on the incorrect phases, then KVAR readings in phase overview will be off. 208

218

Calibration Menu Bus PT Scale
Similar to Gen PT scaling, but this scale is for single phase bus PT input to the 6000 control. Put 6000 control synchroniser in “check” mode in synchroniser setup menu. Start engine in run/load mode to a live bus. Monitor Synchroscope status menu. Observe and calibrate U: volts reading until measured matches monitored. 209

219

Calibration Menu Synchroscope
Calibrates phase angle error detection of 6000 control. Factory calibrated for zero phase angle error between bus and A phase generator inputs With synchroniser in “check” mode, and a live bus, monitor the synchroscope menu of the 6000 control for “phase angle”. 210

220

Calibration Menu Synchroscope (continued)
Monitor Voltage across open gen contactor/breaker or panel synchroscope for phase angle error between generator and bus. Adjust synchroscope calibration for lowest voltage across gen breaker, or 12 o’clock reading on an external synchroscope. 211

221

Calibration Menu Analog inputs to VCOs (Voltage Controlled Osc.) Freq.
(Hz) Analog Input 212

222

Calibration Menu Voltage Controlled Oscillators Increasing offset
Freq. Decreasing offset Analog Input 213

223

Calibration Menu Voltage Controlled Oscillators Increasing gain
Decreasing gain 214

224

Calibration Menu Battery VCO Gain Battery VCO Offset
Sets slope of battery VCO over operating range Battery VCO Offset Sets level, or offset of Battery VCO over operating range Battery Voltage is a linear increasing type VCO function 215

225

Calibration Menu Battery VCO VCO Freq. Battery Voltage 216

226

Calibration Menu Ain1 VCO Gain Oil Pressure sensor input
0-200 ohm sensor on engine is a direct, mostly linear VCO function Sets slope of oil pressure input to VCO frequency Monitor Engine Overview menu of 6000 control and compare to measured oil pressure of engine with engine running at rated speed. Adjust gain for proper oil pressure reading while engine is operating 217

227

Calibration Menu Ain1 VCO Offset
Sets level, or offset of oil pressure input to VCO frequency Set to read 0 psi in Engine Overview menu of 6000 control with engine off. Gain and Offset DO affect each other, so it is neccessary to check adjustments at both ends of the scale (0 psi to operating psi) if an adjustment is made to either gain or offset. 218

228

Calibration Menu Oil Pressure VCO VCO Freq. Oil Presssure (OHMS) 219

229

Calibration Menu Ain2 VCO Gain Water Temperature VCO
Inverse, Non-Linear ohm engine mounted sensor Utilises Shunt resistor dip switches on back of GCP (SW-1 7 and 8 ON). These resistors help to linearize the sensor input 220

230

Calibration Menu Ain2 VCO Gain
Sets slope of water temp. input to VCO frequency Monitor Engine Overview menu of 6000 control and compare to measured water temperature of engine with at low operating temperature. Adjust gain for proper water temperature reading while engine is operating 221

231

Calibration Menu Ain2 VCO Offset
Sets level, or offset of VCO frequency to water temperature slope. Monitor Engine overview, and with engine operating at normal temperature, adjust Ain2 VCO offset for proper temperature reading This is an inverse function. Sensor resistance DECREASES as engine temp increases 222

232

Calibration Menu Water Temp VCO Sensor without shunt Sensor with shunt
Freq. Water Temperature 223

233

Calibration Menu Testing of a sample of Oil pressure sensors with the 6000 control has shown the typical sensor to require the following gain/offset for Ain1 in the calibration menu: Gain Offset 224

234

Calibration Menu Testing of a sample of Water Temp Sensors has shown the typical temp sensor to require following gain and offset settings: Gain Offset 246.0 Shunt Resistor Switches 7 and 8 closed on SW-1 of 6000 control 225

235

Calibration Menu NetComm Dropouts
The number of lost or corrupted network communications tolerated by the recieving unit. Excess numbers of NetComm Dropouts on network due to faulty wiring, improper shielding, or improper setup will result in the unit experiencing the dropouts to flash intermittantly in the Sequencing Menu of the 6000 control. Typically set at 5 to 10 dropouts. 226

236

Communications Two different versions of software — PC Tools Monitor only PC Tools Control & Monitor Three different pieces of hardware — Hardwired connection up to 500m — Modem for connection over telephone — Call back on alarm activation

237

Communications PC1: Provides remote monitoring up to 500 metres from generator PC2: Allows remote monitoring and control up to 500 metres from generator Difference is software

238

Communications Tel 1: Provides remote monitoring over the telephone system Tel 2: Allows remote monitoring and control over the telephone system Difference is software Hardware difference over PC panel is addition of modem

239

Communications Tel 3: Allows remote monitoring and control over the telephone system Same hardware as Tel 1 & 2 with addition of AutoDial unit Optional facility industry standard Modbus protocol interface allowing compatibility with most BMS or SCADA systems

240

Communications Screen shot from PC Tools: monitor only

241

Communications Screen shot from PC Tools: Control and monitor

242

Communications PC Tools has two different applications associated with it — Servlink and — GCP 6000

243

RS-485 & RS-422 Networks as shown on FG Wilson electrical schematic

244

RS-485 The RS-485 Network is used to connect all units in a multiple system ie 6200 or 6400. Wires 70 (RS-485 +),71 (RS-485-),72 (5vDC+) & 73 (5vDC-) should be connected to all machines. Switches 3/4, 3/7 & 3/8 should be set to ON, on the first and last machines only 8 7 6 5 4 3 2 1 8 RS-485 Termination + 7 RS-485 Termination — 4 RS vDC Pull Up SW 3

245

RS-422 The RS-422 Network is used to connect the 6000 control system to the PC or Tel panel when the remote communications option is selected. In a multiple unit application the connection from the PC/Tel connects only one machine and then each unit is connect in series using wires 61(RxD+), 62 (RxD-), 63(TxD+) & 64(TxD-). Switches 3/1, 3/2 & 3/3 should be set to On, on the first and last machines only 8 7 6 5 4 3 2 1 3 RS-422 Termination RxD- 2 RS vDC Pull Up 1 RS-422 Termination RxD+

• Contents

• Table of Contents

• Troubleshooting

• Bookmarks

Summary of Contents for Mi-T-M GEN-6000-0MH0

https://abespb. ru/press/articles/neispravnosti-dizel-generatora-i-ikh-ustranenie/

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