AGC 4 Manual

DEIF A/S · Frisenborgvej 33 · DK-7800 Skive · Tel.: +45 9614 9614 · Fax: +45 9614 9615 · [email protected] · www.deif.com



DESIGNER'S REFERENCE HANDBOOK

Automatic Genset Controller, AGC-4 Functional description Display unit and menu structure PID-controller Procedure for parameter setup Parameter list

Document no.: 4189340686ASW version: 4.0x.x or later

1. General information1.1. Warnings, legal information and safety................................................................................................13

1.1.1. Warnings and notes ....................................................................................................................131.1.2. Legal information and disclaimer ................................................................................................131.1.3. Safety issues ..............................................................................................................................131.1.4. Electrostatic discharge awareness .............................................................................................131.1.5. Factory settings ..........................................................................................................................13

1.2. About the Designer's Reference Handbook.........................................................................................141.2.1. General purpose .........................................................................................................................141.2.2. Intended users ............................................................................................................................141.2.3. Contents and overall structure ....................................................................................................14

2. General product information2.1. Introduction...........................................................................................................................................152.2. Type of product....................................................................................................................................152.3. Options.................................................................................................................................................152.4. PC utility software warning...................................................................................................................15

3. Functional descriptions3.1. Standard functions...............................................................................................................................16

3.1.1. Operation modes.........................................................................................................................163.1.2. Engine control..............................................................................................................................163.1.3. Generator protection (ANSI)........................................................................................................163.1.4. Busbar protection (ANSI).............................................................................................................163.1.5. Display.........................................................................................................................................163.1.6. M-Logic........................................................................................................................................16

3.2. Terminal strip overview........................................................................................................................173.2.1. Slot #1, #2, #5 and #6..................................................................................................................183.2.2. Slot #3, #4, #7 and #8..................................................................................................................19

3.3. Applications..........................................................................................................................................203.3.1. Applications and genset modes...................................................................................................203.3.2. AMF (no back synchronisation)...................................................................................................203.3.3. AMF (with back synchronisation).................................................................................................213.3.4. Island operation...........................................................................................................................223.3.5. Fixed power/base load.................................................................................................................223.3.6. Ramp up with load steps.............................................................................................................233.3.7. Freeze power ramp......................................................................................................................233.3.8. Peak shaving...............................................................................................................................243.3.9. Load takeover..............................................................................................................................263.3.10. Mains power export (fixed power to mains)...............................................................................27

3.4. Running mode description....................................................................................................................283.4.1. Semi-auto mode..........................................................................................................................283.4.2. Test mode....................................................................................................................................293.4.3. Simple test...................................................................................................................................303.4.4. Load test......................................................................................................................................303.4.5. Full test........................................................................................................................................303.4.6. Manual mode...............................................................................................................................303.4.7. Block mode..................................................................................................................................31

3.5. Single-line diagrams.............................................................................................................................323.5.1. Application illustration .................................................................................................................323.5.2. Automatic Mains Failure..............................................................................................................323.5.3. Island operation...........................................................................................................................323.5.4. Fixed power/base load.................................................................................................................333.5.5. Peak shaving...............................................................................................................................333.5.6. Load takeover..............................................................................................................................343.5.7. Mains power export.....................................................................................................................343.5.8. Multiple gensets, load sharing (option G3 required)....................................................................353.5.9. Multiple gensets, power management (option G5 required)........................................................35

AGC-4 manual, November 2011, UK

DEIF A/S Page 2 of 406

3.6. Flowcharts............................................................................................................................................393.6.1. Mode shift....................................................................................................................................403.6.2. MB open sequence......................................................................................................................413.6.3. GB open sequence......................................................................................................................423.6.4. Stop sequence.............................................................................................................................433.6.5. Start sequence.............................................................................................................................443.6.6. MB close sequence.....................................................................................................................453.6.7. GB close sequence......................................................................................................................463.6.8. Fixed power.................................................................................................................................473.6.9. Load takeover..............................................................................................................................483.6.10. Island operation.........................................................................................................................493.6.11. Peak shaving.............................................................................................................................503.6.12. Mains power export...................................................................................................................513.6.13. Automatic Mains Failure............................................................................................................523.6.14. Test sequence...........................................................................................................................53

3.7. Sequences...........................................................................................................................................543.7.1. Start sequence.............................................................................................................................543.7.2. Start sequence conditions...........................................................................................................563.7.3. Running feedback........................................................................................................................573.7.4. Stop sequence.............................................................................................................................603.7.5. Breaker sequences......................................................................................................................623.7.6. AMF timers..................................................................................................................................63

4. Display unit and menu structure4.1. Presentation.........................................................................................................................................654.2. Display unit (DU-2)...............................................................................................................................65

4.2.1. Push-button functions..................................................................................................................654.2.2. LED functions..............................................................................................................................66

4.3. Menu structure.....................................................................................................................................674.3.1. Entry window...............................................................................................................................674.3.2. View menu...................................................................................................................................684.3.3. Setup menu.................................................................................................................................69

4.4. Mode overview.....................................................................................................................................724.5. Mode selection.....................................................................................................................................734.6. Password..............................................................................................................................................74

4.6.1. Parameter access........................................................................................................................76

5. Additional functions5.1. Start functions......................................................................................................................................77

5.1.1. Digital feedbacks.........................................................................................................................775.1.2. Analogue tacho feedback............................................................................................................785.1.3. Oil pressure.................................................................................................................................79

5.2. Breaker types.......................................................................................................................................805.3. Breaker spring load time......................................................................................................................81

5.3.1. Principle.......................................................................................................................................825.4. Alarm inhibit..........................................................................................................................................83

5.4.1. Run status (6160)........................................................................................................................855.5. Access lock..........................................................................................................................................855.6. Overlap.................................................................................................................................................875.7. Digital mains breaker control................................................................................................................885.8. Command timers..................................................................................................................................895.9. Running output.....................................................................................................................................895.10. Frequency-dependent droop..............................................................................................................905.11. Power and cos phi offsets..................................................................................................................92

5.11.1. Power offsets.............................................................................................................................925.11.2. Cos phi offsets...........................................................................................................................92

5.12. Derate genset.....................................................................................................................................925.12.1. Input selection............................................................................................................................925.12.2. Derate parameters.....................................................................................................................93



5.12.3. Derate characteristic..................................................................................................................935.13. Idle running.........................................................................................................................................94

5.13.1. Description.................................................................................................................................945.13.2. Examples...................................................................................................................................955.13.3. Configuration of digital input......................................................................................................965.13.4. Inhibit.........................................................................................................................................975.13.5. Running signal...........................................................................................................................975.13.6. Idle speed flowcharts.................................................................................................................975.13.7. Start...........................................................................................................................................985.13.8. Stop...........................................................................................................................................99

5.14. Engine heater.....................................................................................................................................995.14.1. Engine heater alarm................................................................................................................100

5.15. Master clock.....................................................................................................................................1005.15.1. Compensation time..................................................................................................................101

5.16. Battery test.......................................................................................................................................1015.16.1. Input configuration...................................................................................................................1025.16.2. Auto configuration....................................................................................................................1025.16.3. Battery asymmetry (6430 Batt. asymmetry)............................................................................103

5.17. Ventilation.........................................................................................................................................1055.17.1. Max. ventilation alarm..............................................................................................................106

5.18. Summer/winter time.........................................................................................................................1065.19. Switchboard error.............................................................................................................................106

5.19.1. Block swbd error (menu 6500).................................................................................................1065.19.2. Stop swbd error (menu 6510)..................................................................................................107

5.20. Not in auto........................................................................................................................................1075.21. Fuel pump logic................................................................................................................................107

5.21.1. Fuel fill check...........................................................................................................................1085.22. Fail class..........................................................................................................................................109

5.22.1. Engine running.........................................................................................................................1095.22.2. Engine stopped........................................................................................................................1105.22.3. Fail class configuration............................................................................................................110

5.23. Trip of non-essential load (NEL).......................................................................................................1115.24. Service timers...................................................................................................................................1115.25. Wire fail detection.............................................................................................................................1125.26. Digital inputs.....................................................................................................................................114

5.26.1. Functional description..............................................................................................................1155.27. Outputs.............................................................................................................................................120

5.27.1. Functional description..............................................................................................................1205.28. Multi-inputs.......................................................................................................................................120

5.28.1. 4-20 mA...................................................................................................................................1215.28.2. 0-40V DC.................................................................................................................................1215.28.3. Pt100/1000..............................................................................................................................1215.28.4. VDO inputs..............................................................................................................................1215.28.5. VDO oil....................................................................................................................................1225.28.6. VDO water...............................................................................................................................1225.28.7. VDO fuel..................................................................................................................................1235.28.8. Illustration of configurable inputs.............................................................................................1245.28.9. Configuration...........................................................................................................................1255.28.10. Digital.....................................................................................................................................125

5.29. Manual governor and AVR control...................................................................................................1255.29.1. Manual mode...........................................................................................................................1255.29.2. Semi-auto mode......................................................................................................................1255.29.3. Auto and test mode..................................................................................................................126

5.30. Input function selection.....................................................................................................................1265.31. Language selection..........................................................................................................................1275.32. Texts in status line............................................................................................................................127

5.32.1. Standard texts..........................................................................................................................1285.32.2. Texts only related to power management (option G5).............................................................131

5.33. Service menu...................................................................................................................................132



5.34. Event log..........................................................................................................................................1335.34.1. Display.....................................................................................................................................133

5.35. Counters...........................................................................................................................................1335.36. Pulse input counters.........................................................................................................................1345.37. kWh/kVArh counters.........................................................................................................................1345.38. Quick setup......................................................................................................................................1355.39. Parameter ID....................................................................................................................................1365.40. M-Logic.............................................................................................................................................1365.41. GSM communication........................................................................................................................1375.42. USW communication........................................................................................................................1385.43. Nominal settings...............................................................................................................................1385.44. Step-up transformer.........................................................................................................................140

5.44.1. Applications.............................................................................................................................1405.45. Demand of peak currents.................................................................................................................141

5.45.1. I thermal demand.....................................................................................................................1415.45.2. I max. demand.........................................................................................................................142

5.46. Fan logic...........................................................................................................................................1425.46.1. Fan parameters.......................................................................................................................1435.46.2. Input for fan control..................................................................................................................1435.46.3. Fan start/stop...........................................................................................................................1445.46.4. Fan output................................................................................................................................1445.46.5. Fan start delay.........................................................................................................................1455.46.6. Fan failure................................................................................................................................1455.46.7. Fan priority (running hours).....................................................................................................1465.46.8. Fan priority update...................................................................................................................147

5.47. Oil renewal function..........................................................................................................................1475.48. Differential measurement.................................................................................................................148

6. Protections6.1. General...............................................................................................................................................1506.2. Voltage-dependent (restraint) overcurrent.........................................................................................151

7. PID controller7.1. Description of PID controller...............................................................................................................1537.2. Controllers..........................................................................................................................................1537.3. Principle drawing................................................................................................................................1547.4. Proportional regulator.........................................................................................................................154

7.4.1. Speed range..............................................................................................................................1557.4.2. Dynamic regulation area............................................................................................................1557.4.3. Integral regulator........................................................................................................................1567.4.4. Differential regulator..................................................................................................................156

7.5. Load share controller..........................................................................................................................1587.6. Synchronising controller.....................................................................................................................1587.7. Relay control......................................................................................................................................158

7.7.1. Relay adjustments.....................................................................................................................1607.7.2. Signal length..............................................................................................................................160

8. Synchronisation8.1. Synchronisation principles..................................................................................................................1628.2. Dynamic synchronisation...................................................................................................................162

8.2.1. Close signal...............................................................................................................................1638.2.2. Load picture after synchronising................................................................................................1638.2.3. Adjustments...............................................................................................................................164

8.3. Static synchronisation........................................................................................................................1658.3.1. Phase controller.........................................................................................................................1658.3.2. Close signal...............................................................................................................................1668.3.3. Load picture after synchronisation.............................................................................................1668.3.4. Adjustments...............................................................................................................................166

8.4. GB closing before excitation...............................................................................................................167



8.4.1. Flowchart 1, GB handling..........................................................................................................1698.4.2. Flowchart 2, TB handling (option G5)........................................................................................1708.4.3. Genset start actions...................................................................................................................1718.4.4. Breaker sequence......................................................................................................................1718.4.5. "Close before excitation" failure.................................................................................................172

8.5. Separate synchronising relay.............................................................................................................172

9. Parameter list9.1. Related parameters............................................................................................................................174

10. Voltage/VAr/PF control10.1. Description of option, ANSI numbers...............................................................................................17510.2. Description of option, Option D1......................................................................................................17510.3. Functional description, Running mode selection, AGC/PPM...........................................................175

10.3.1. Automatic selection..................................................................................................................17510.3.2. Manual selection......................................................................................................................17610.3.3. Input selection..........................................................................................................................176

10.4. Functional description, Regulation mode selecetion, GPC/PPU......................................................17610.4.1. Input selection..........................................................................................................................17710.4.2. Regulators...............................................................................................................................17810.4.3. External setpoint......................................................................................................................17810.4.4. AVR mode undefined (menu 2750).........................................................................................178

10.5. Functional description, Regulation mode selection, GPU................................................................17810.6. Functional description, AVR regulation failure.................................................................................17910.7. Functional description, Manual AVR control....................................................................................17910.8. Functional description, Voltage-dependent PF/Q control (y2(x2) droop..........................................17910.9. Parameters, Further information......................................................................................................181

11. Load sharing11.1. Description of option, ANSI numbers...............................................................................................18211.2. Description of option, Option G3......................................................................................................182

11.2.1. AGC.........................................................................................................................................18211.3. Description of option, Terminal description......................................................................................18211.4. Functional description, Load sharing................................................................................................182

11.4.1. Working principle.....................................................................................................................18311.5. Functional description, Island ramp up with load steps....................................................................18511.6. Functional description, Freeze power ramp.....................................................................................18511.7. Functional description, External analogue setpoints........................................................................18611.8. Functional description, Load sharing type........................................................................................186

11.8.1. Load sharing modules.............................................................................................................18711.8.2. Selco T4800 load sharer..........................................................................................................18711.8.3. Cummins PCC 3100................................................................................................................187

11.9. Parameters, Further information......................................................................................................189

12. Power management12.1. Description of options, ANSI numbers.............................................................................................19012.2. Description of options, Options G4, G5 and G8...............................................................................19012.3. Description of options, Terminal description....................................................................................19212.4. Description of options, Breaker feedbacks.......................................................................................193

12.4.1. Generator breaker...................................................................................................................19312.4.2. Mains breaker (MB) feedback..................................................................................................19312.4.3. Tie breaker (TB).......................................................................................................................193

12.5. Description of options, Wiring diagram.............................................................................................19412.6. Functional description, Power management functions.....................................................................19412.7. Functional description, Terminal strip overview...............................................................................196

12.7.1. AGC generator unit..................................................................................................................19612.7.2. AGC mains unit........................................................................................................................19812.7.3. AGC bus tie unit.......................................................................................................................200

12.8. Functional description, Applications.................................................................................................202



12.8.1. Island operation plant..............................................................................................................20312.8.2. Parallel with mains plant..........................................................................................................20412.8.3. Dual mains plant......................................................................................................................20512.8.4. ATS plant.................................................................................................................................20612.8.5. ATS plant, multiple start...........................................................................................................20612.8.6. ATS plant, mains unit...............................................................................................................20712.8.7. Multiple mains..........................................................................................................................207

12.9. Display units, DU for option G5........................................................................................................20812.10. Display units, Generator unit display..............................................................................................20812.11. Display units, Mains unit display....................................................................................................20812.12. Display units, BTB unit display.......................................................................................................20912.13. Power management setup, Initial power management setup........................................................209

12.13.1. Display setup.........................................................................................................................20912.13.2. PC software setup.................................................................................................................20912.13.3. Application design..................................................................................................................210

12.14. Power management setup, Remove unit from PM.........................................................................21212.14.1. Auxiliary supply OFF..............................................................................................................21212.14.2. Quick setup............................................................................................................................21312.14.3. Auxiliary supply ON...............................................................................................................213

12.15. Power management setup, CANbus failure handling.....................................................................21312.15.1. CAN failure mode..................................................................................................................21312.15.2. Redundant CANbus communication......................................................................................21512.15.3. CANbus alarms......................................................................................................................21512.15.4. CANbus fail class...................................................................................................................216

12.16. Power management setup, Quick setup........................................................................................21612.16.1. Limitations..............................................................................................................................217

12.17. Power management setup, 9180 Quick setup...............................................................................21812.17.1. 9190 Application broadcast...................................................................................................219

12.18. Power management functions, Command unit..............................................................................22012.19. Power management functions, Load-dependent starting and stopping.........................................220

12.19.1. Terminology...........................................................................................................................22112.19.2. Principle – available power method.......................................................................................22312.19.3. Principle – percentage method..............................................................................................22312.19.4. Adjusting load-dependent start..............................................................................................22412.19.5. Adjusting load-dependent stop..............................................................................................22512.19.6. Power window........................................................................................................................226

12.20. Power management functions, Load management........................................................................22612.20.1. Functionality description (refer to the diagram below)...........................................................227

12.21. Power management functions, Load sharing.................................................................................22812.22. Power management functions, Island ramp up with load steps.....................................................22912.23. Power management functions, Fixed power ramp up with load steps...........................................22912.24. Power management functions, freeze power ramp........................................................................23012.25. Power management functions, ATS applications...........................................................................230

12.25.1. AGC mains installed..............................................................................................................23012.25.2. ATS island mode...................................................................................................................231

12.26. Power management functions, Fail class.......................................................................................23112.27. Power management functions, Local/remote/timer operation........................................................231

12.27.1. Local selection.......................................................................................................................23212.27.2. Remote selection...................................................................................................................23212.27.3. Plant operation.......................................................................................................................23212.27.4. Timer selection......................................................................................................................23312.27.5. Principle.................................................................................................................................233

12.28. Power management functions, Multi-starting gensets....................................................................23412.28.1. Multi-start configuration.........................................................................................................23412.28.2. Numbers to start....................................................................................................................23512.28.3. Minimum numbers running....................................................................................................235

12.29. Power management functions, Priority selection...........................................................................23612.29.1. Manual...................................................................................................................................23612.29.2. Running hours.......................................................................................................................238



12.29.3. Fuel optimisation....................................................................................................................23912.30. Power management functions, Conditional connection of heavy consumers................................242

12.30.1. Power feedback from the heavy consumer...........................................................................24312.30.2. Engagement sequence for HCs with fixed load.....................................................................244

12.31. Power management functions, Ground relay.................................................................................24412.32. Power management functions, Stop of non-connected gensets....................................................24512.33. Power management functions, Secured mode..............................................................................24512.34. Power management functions, Base load......................................................................................24512.35. Power management functions, Asymmetric load sharing (LS).......................................................24612.36. Power management functions, Tie breaker configuration..............................................................246

12.36.1. Tie breaker selection.............................................................................................................24612.36.2. Tie breaker control.................................................................................................................24712.36.3. Tie breaker open point...........................................................................................................24712.36.4. Power capacity......................................................................................................................247

12.37. Power management functions, Island application with TB.............................................................24812.38. Power management functions, Multiple mains...............................................................................249

12.38.1. Definitions..............................................................................................................................25012.38.2. Configuration.........................................................................................................................25212.38.3. Plant mode handling..............................................................................................................253

12.39. Power management functions, Dual mains....................................................................................25412.39.1. Configuration.........................................................................................................................25512.39.2. Plant mode handling..............................................................................................................25612.39.3. Internal CAN ID......................................................................................................................25812.39.4. AGC mains unit redundancy..................................................................................................25812.39.5. Tie breaker configuration.......................................................................................................259

12.40. Power management functions, Configurable CAN IDs..................................................................26012.41. Power management functions, CAN flags......................................................................................26012.42. Power management functions, Common PF control......................................................................26112.43. Parameter lists, Common settings.................................................................................................262

13. Plant management13.1. Description of option, Option G7......................................................................................................26313.2. Functional description, Plant management......................................................................................263

13.2.1. Unit definitions.........................................................................................................................26413.2.2. Applications.............................................................................................................................265

13.3. Functional description, Plant mode descriptions..............................................................................26913.4. Functional description, Plant management functions.......................................................................273

13.4.1. Group controller start and stop................................................................................................27313.4.2. Power reference scaling..........................................................................................................27413.4.3. Cos phi-controlled export.........................................................................................................27413.4.4. Voltage support........................................................................................................................27713.4.5. Priority routine, load profile......................................................................................................28113.4.6. Offset of setpoints....................................................................................................................28413.4.7. Asymmetrical load sharing.......................................................................................................286

13.5. Functional description, Plant management toolbox..........................................................................28713.5.1. CAN flags.................................................................................................................................28713.5.2. Common settings.....................................................................................................................29113.5.3. Modbus addresses..................................................................................................................29313.5.4. AOP design..............................................................................................................................294

13.6. Parameters, Further information......................................................................................................29613.7. Appendix, Operating settings...........................................................................................................296

13.7.1. Fixed power operation.............................................................................................................29613.7.2. AMF operation.........................................................................................................................29813.7.3. Island mode operation with plant unit......................................................................................29913.7.4. Island mode operation without plant unit.................................................................................30113.7.5. Load takeover mode................................................................................................................30313.7.6. Mains power export mode.......................................................................................................30413.7.7. Peak shaving mode.................................................................................................................306



14. Analogue controller and transducer outputs14.1. Description of option, ANSI numbers...............................................................................................30814.2. Description of option, Option EF6....................................................................................................308

14.2.1. Terminal description................................................................................................................30814.3. Functional description, Analogue outputs........................................................................................30814.4. Functional description, Duty cycle....................................................................................................309

14.4.1. Principle of duty cycles............................................................................................................30914.5. Functional description, Analogue controller offset............................................................................31014.6. Functional description, Output limits................................................................................................31114.7. Parameters, further information........................................................................................................312

15. Configurable I/O extension cards, four 4-20 mA inputs15.1. Description of option, Option M15.x.................................................................................................313

15.1.1. Terminal description, M15.6....................................................................................................31315.1.2. Terminal description, M15.8....................................................................................................313

15.2. Functional description, Analogue input configuration.......................................................................31315.3. Functional description, Inverse proportional.....................................................................................31415.4. Functional description, PC utility software........................................................................................31515.5. Functional description, Wire failure detection...................................................................................315

15.5.1. Principle...................................................................................................................................31515.6. Parameters, Further information......................................................................................................316

16. Configurable I/O extension cards, 13 binary inputs, 4 relay outputs16.1. Description of option, Option M12....................................................................................................31716.2. Description of option, ANSI numbers...............................................................................................31716.3. Description of option, Terminal descriptions....................................................................................318

16.3.1. Terminal description, AGC.......................................................................................................31816.3.2. Terminal description, GPU/GPU Hydro...................................................................................319

16.4. Functional description, Digital inputs................................................................................................31916.5. Functional description, Protection/alarm inputs................................................................................320

16.5.1. Function input..........................................................................................................................32016.6. Functional description, Relay setup.................................................................................................32116.7. Functional description, External analogue setpoints........................................................................321

16.7.1. AGC.........................................................................................................................................32116.8. Parameters, Further information......................................................................................................322

17. Ethernet hardware17.1. Description of option, Hardware.......................................................................................................32317.2. Description of option, Option N configuration software....................................................................32317.3. Network configuration of the option N board, Network settings.......................................................32417.4. Network configuration of the option N board, Option N board setup................................................325

17.4.1. Modifying the network configuration from the option N configuration software.......................32617.5. TCP/IP Modbus communication, Further information......................................................................32817.6. SMS or e-mail alarms transfer..........................................................................................................32917.7. SMS or e-mail alarms transfer, SMS or e-mail alarms configuration...............................................33017.8. SMS or e-mail alarms transfer, Received message format..............................................................336

17.8.1. Alarm transfer function selection from the option N configuration software............................33717.9. Option N firmware upgrade..............................................................................................................338

17.9.1. Obtain the option N firmware from DEIF..................................................................................33817.9.2. How to write the option N firmware..........................................................................................340

17.10. Parameters, further information......................................................................................................342

18. Additional display and operator's panel18.1. Description of option, Option X2.......................................................................................................343

18.1.1. Rear side view.........................................................................................................................34318.1.2. Connectors..............................................................................................................................343

18.2. Description of option, Option X3.......................................................................................................34318.2.1. Rear side view.........................................................................................................................344



18.2.2. Connectors..............................................................................................................................34418.3. Description of option, Option X4.......................................................................................................344

18.3.1. Rear side view.........................................................................................................................34418.3.2. Connectors..............................................................................................................................344

18.4. Functional description, Additional displays and operator's panels...................................................34418.5. Functional description, Display unit - DU-2......................................................................................346

18.5.1. Wiring.......................................................................................................................................34618.5.2. End resistor..............................................................................................................................34718.5.3. CAN ID configuration...............................................................................................................34718.5.4. Protocol selection....................................................................................................................347

18.6. Functional description, Additional operator's panel - AOP-1............................................................34818.6.1. Front side view.........................................................................................................................34818.6.2. Wiring.......................................................................................................................................34818.6.3. CAN ID configuration...............................................................................................................34818.6.4. Programming...........................................................................................................................348

18.7. Functional description, Additional operator's panel - AOP-2............................................................34918.7.1. Front side view.........................................................................................................................34918.7.2. Wiring.......................................................................................................................................35018.7.3. End resistor..............................................................................................................................35118.7.4. CAN ID configuration...............................................................................................................35118.7.5. Status relay..............................................................................................................................35118.7.6. Programming...........................................................................................................................35118.7.7. Lamp test/dimmer....................................................................................................................351

18.8. Functional description, Error handling..............................................................................................35118.8.1. Duplicate CAN ID.....................................................................................................................351

19. Installation instructions19.1. General product information, AGC-3 product information................................................................353

19.1.1. Introduction..............................................................................................................................35319.1.2. Type of product........................................................................................................................35319.1.3. Options....................................................................................................................................353

19.2. General product information, Standard functions.............................................................................35319.2.1. Operation modes.....................................................................................................................35319.2.2. Engine control..........................................................................................................................35319.2.3. Generator protection (ANSI)....................................................................................................35319.2.4. Busbar protection (ANSI).........................................................................................................35419.2.5. Display.....................................................................................................................................35419.2.6. M-Logic....................................................................................................................................354

19.3. General product information, Standard and optional applications....................................................35419.3.1. Automatic Mains Failure, AMF.................................................................................................35419.3.2. Island operation.......................................................................................................................35519.3.3. Fixed power/base load.............................................................................................................35519.3.4. Peak shaving...........................................................................................................................35519.3.5. Load takeover..........................................................................................................................35619.3.6. Mains power export (fixed power to mains).............................................................................35619.3.7. Multiple gensets, load sharing.................................................................................................35619.3.8. Multiple gensets, power management.....................................................................................357

19.4. Mounting, AGC-3 mounting..............................................................................................................35719.4.1. Mounting of the unit.................................................................................................................35719.4.2. Panel cut-out............................................................................................................................35719.4.3. Mounting instructions...............................................................................................................357

19.5. Hardware, Board slot positions........................................................................................................35719.5.1. Unit top side overview..............................................................................................................35819.5.2. Terminal strip overviews..........................................................................................................35919.5.3. Input/output lists.......................................................................................................................36419.5.4. Slot #1, power supply PCB......................................................................................................36519.5.5. Slot #1, power supply PCB - AGC mains unit..........................................................................36619.5.6. Slot #2, serial communication (option H).................................................................................36619.5.7. Slot #2, external I/O module (option H8.2)..............................................................................368



19.5.8. Slot #3, load sharing control (option G3).................................................................................36919.5.9. Slot #3, 13 binary inputs and 4 relay outputs (option M12).....................................................37019.5.10. Slot #4, relay outputs (option M14.4, standard).....................................................................37119.5.11. Slot #4, analogue outputs for GOV/AVR or transducer (option E1)......................................37119.5.12. Slot #4, analogue outputs for GOV/AVR or transducer (option EF2)....................................37119.5.13. Slot #4, combination outputs for GOV/AVR or transducer (option EF4)................................37219.5.14. Slot #4, PWM output for GOV and combination output for AVR (option EF5).......................37219.5.15. Slot #4, PWM output for GOV and combination output for AVR (option EF6).......................37219.5.16. Slot #4, analogue outputs for GOV/AVR or transducer (option E2)......................................37319.5.17. Slot #5, AC measuring...........................................................................................................37319.5.18. Slot #5, AC measuring - AGC mains unit..............................................................................37419.5.19. Slot #5, AC measuring - AGC BTB unit.................................................................................37519.5.20. Slot #6, 7 digital inputs (option M13.6)..................................................................................37519.5.21. Slot #6, 4 relay outputs (option M14.6)..................................................................................37619.5.22. Slot #6, 4 analogue inputs (option M15.6).............................................................................37619.5.23. Slot #6, analogue outputs for GOV/AVR or transducer (option F1).......................................37619.5.24. Slot #7, engine interface card (standard)...............................................................................37719.5.25. Slot #7, engine interface card (standard) AGC mains/BTB...................................................37819.5.26. Slot #8, engine interface communication (option H5)............................................................37919.5.27. Slot #8, Cummins engine interface communication (option H6)............................................37919.5.28. Slot #8, 7 digital inputs (option M13.8)..................................................................................37919.5.29. Slot #8, 4 relay outputs (option M14.8)..................................................................................38019.5.30. Slot #8, external I/O module (option H8.8)............................................................................380

19.6. Wirings, AC connections..................................................................................................................38019.6.1. Neutral line (N).........................................................................................................................38019.6.2. Current transformer grounding................................................................................................38019.6.3. Fuses.......................................................................................................................................38119.6.4. Breaker wiring..........................................................................................................................38119.6.5. 3-phase....................................................................................................................................38119.6.6. Single phase............................................................................................................................38219.6.7. 2-phase L1L2...........................................................................................................................38319.6.8. 2-phase L1L3 (split phase)......................................................................................................38419.6.9. Island mode and power management (option G4/G5/G8).......................................................38519.6.10. Power management (option G5), AGC mains.......................................................................38619.6.11. Power management (option G5), dual mains - AGC mains...................................................38719.6.12. Power management (option G5), AGC BTB..........................................................................388

19.7. Wirings, DC connections..................................................................................................................38819.7.1. Load sharing lines (option G3).................................................................................................38819.7.2. Digital inputs............................................................................................................................38919.7.3. Analogue inputs.......................................................................................................................38919.7.4. Multi-inputs..............................................................................................................................39019.7.5. Digital inputs............................................................................................................................39119.7.6. Pt100/Pt1000...........................................................................................................................39119.7.7. VDO.........................................................................................................................................39119.7.8. 0-40V DC.................................................................................................................................39219.7.9. RPM input................................................................................................................................39219.7.10. Stop coil.................................................................................................................................39319.7.11. Transistor outputs (open collector outputs)...........................................................................393

19.8. Wirings, Communication..................................................................................................................39419.8.1. CANbus (option G4/G5/G8).....................................................................................................39419.8.2. Modbus (option H2).................................................................................................................39519.8.3. Profibus DP (option H3)...........................................................................................................39719.8.4. CANbus engine communication (option H5)............................................................................39719.8.5. Cummins GCS (option H6)......................................................................................................39919.8.6. CANbus engine communication (option H7)............................................................................40019.8.7. External I/O module (option H8)..............................................................................................40019.8.8. Display cable (option J)...........................................................................................................401

19.9. Technical information, AGC-3..........................................................................................................40219.9.1. Technical specifications ..........................................................................................................402



19.10. Technical information, Unit dimensions..........................................................................................40519.11. Technical information, Panel cut-out..............................................................................................405



1. General information1.1 Warnings, legal information and safety

1.1.1 Warnings and notesThroughout this document, a number of warnings and notes with helpful user information will be presented.To ensure that these are noticed, they will be highlighted as follows in order to separate them from the gener-al text.

Warnings

Warnings indicate a potentially dangerous situation, which could result in death, personal in-jury or damaged equipment, if certain guidelines are not followed.

Notes

Notes provide general information, which will be helpful for the reader to bear in mind.

1.1.2 Legal information and disclaimerDEIF takes no responsibility for installation or operation of the generator set. If there is any doubt about howto install or operate the engine/generator controlled by the Multi-line 2 unit, the company responsible for theinstallation or the operation of the set must be contacted.

The Multi-line 2 unit is not to be opened by unauthorised personnel. If opened anyway, the war-ranty will be lost.

DisclaimerDEIF A/S reserves the right to change any of the contents of this document without prior notice.

1.1.3 Safety issuesInstalling and operating the Multi-line 2 unit may imply work with dangerous currents and voltages. Therefore,the installation should only be carried out by authorised personnel who understand the risks involved in work-ing with live electrical equipment.

Be aware of the hazardous live currents and voltages. Do not touch any AC measurement in-puts as this could lead to injury or death.

1.1.4 Electrostatic discharge awarenessSufficient care must be taken to protect the terminal against static discharges during the installation. Once theunit is installed and connected, these precautions are no longer necessary.

1.1.5 Factory settingsThe Multi-line 2 unit is delivered from factory with certain factory settings. These are based on average valuesand are not necessarily the correct settings for matching the engine/generator set in question. Precautionsmust be taken to check the settings before running the engine/generator set.

AGC-4 manual, November 2011, UK General information


1.2 About the Designer's Reference Handbook

1.2.1 General purposeThis Designer's Reference Handbook mainly includes functional descriptions, presentation of display unit andmenu structure, information about the PID controller, the procedure for parameter setup and reference to pa-rameter lists.

The general purpose of this document is to provide useful overall information about the functionality of theunit and its applications. This document also offers the user the information he needs in order to successfullyset up the parameters needed in his specific application.

Please make sure to read this document before starting to work with the Multi-line 2 unit andthe genset to be controlled. Failure to do this could result in human injury or damage to theequipment.

1.2.2 Intended usersThis Designer's Reference Handbook is mainly intended for the panel builder designer in charge. On the ba-sis of this document, the panel builder designer will give the electrician the information he needs in order toinstall the Multi-line 2 unit, e.g. detailed electrical drawings. In some cases, the electrician may use these in-stallation instructions himself.

1.2.3 Contents and overall structureThis document is divided into chapters, and in order to make the structure simple and easy to use, eachchapter will begin from the top of a new page.

AGC-4 manual, November 2011, UK General information


2. General product information2.1 Introduction

This chapter will deal with the unit in general and its place in the DEIF product range.

The AGC is part of the DEIF Multi-line 2 product family. Multi-line 2 is a complete range of multi-function gen-erator protection and control products integrating all the functions you need into one compact and attractivesolution.

The concept of the AGC is to offer a cost-effective solution to genset builders, who need a flexible generatorprotection and control unit for medium to large genset applications. Being part of the Multi-line product family,the standard functions can be supplemented with a variety of optional functions.

2.2 Type of product

The Automatic Genset Controller is a micro-processor based control unit containing all necessary functionsfor protection and control of a genset.

It contains all necessary 3-phase measuring circuits, and all values and alarms are presented on the LCDdisplay.

2.3 Options

The Multi-line 2 product range consists of different basic versions which can be supplemented with the flexi-ble options needed to provide the optimum solution. The options cover e.g. various protections for generator,busbar and mains, voltage/VAr/PF control, various outputs, power management, serial communication, addi-tional operator display, etc.

A full options list is included in the data sheet, document no. 4921240396. Please seewww.deif.com

2.4 PC utility software warning

It is possible to remote control the genset from the PC utility software or M-Vision by use of amodem. To avoid personal injury, make sure that it is safe to remote control the genset.

AGC-4 manual, November 2011, UK General product information


3. Functional descriptions3.1 Standard functions

This chapter includes functional descriptions of standard functions as well as illustrations of the relevant appli-cation types. Flowcharts and single-line diagrams will be used in order to simplify the information.

In the following paragraphs the standard functions are listed.

3.1.1 Operation modes Automatic Mains Failure Island operation Fixed power/base load Peak shaving Load takeover Mains power export

3.1.2 Engine control Start/stop sequences Run and stop coil Relay outputs for governor control

3.1.3 Generator protection (ANSI) 2 x reverse power (32) 5 x overload (32) 6 x overcurrent (50/51) 2 x overvoltage (59) 3 x undervoltage (27) 3 x over-/underfrequency (81) Voltage-dependent overcurrent (51V) Current/voltage unbalance (60) Loss of excitation/overexcitation (40/32RV) Non-essential load/load shedding, 3 levels (I, Hz, P>, P>>) Multi-inputs (digital, 4-20 mA, 0-40V DC, Pt100, Pt1000 or VDO) Digital inputs

3.1.4 Busbar protection (ANSI) 3 x overvoltage (59) 4 x undervoltage (27) 3 x overfrequency (81) 4 x underfrequency (81) Voltage unbalance (60)

3.1.5 Display Prepared for remote mounting Push-buttons for start and stop Push-buttons for breaker operations Status texts

3.1.6 M-Logic Simple logic configuration tool Selectable input events Selectable output commands

AGC-4 manual, November 2011, UK Functional descriptions


3.2 Terminal strip overview

The terminal strip overview shows I/Os for selectable standard and optional hardware.

Refer to the data sheet for accurate information about possible configurations for the AGC.

Refer to the input/output lists in the installation instructions for detailed information aboutthe I/Os of the specific options.



3.2.1 Slot #1, #2, #5 and #6



3.2.2 Slot #3, #4, #7 and #8

The hardware shown in slot #3 is option M12 and G3. For a detailed description of these op-tions, please refer to the option descriptions.



3.3 Applications

3.3.1 Applications and genset modes

This section about applications is to be used for reference using the particular genset mode asstarting point. It is not suitable for reading from beginning to end.

The unit can be used for the applications listed in the table below.

Application Comment

Automatic Mains Failure (no back sync.) Standard

Automatic Mains Failure (with back sync.) Standard

Island operation Standard

Fixed power/base load Standard

Peak shaving Standard

Load takeover Standard

Mains power export (fixed power to mains) Standard

Multiple gensets, load sharing Requires option G3

Multiple gensets, power management Requires option G5

Remote maintenance Requires option H8.x and a remote maintenance box fromDEIF A/S

Genset mode Running mode

Auto Semi Test Man Block

Automatic Mains Failure (no back sync.) X X X X X

Automatic Mains Failure (with back sync.) X X X X X

Island operation X X X X X

Fixed power/base load X X X X X

Peak shaving X X X X X

Load takeover X X X X X

Mains power export X X X X X

Multiple gensets, load sharing (G3) X X X X X

Multiple gensets, power management X X (X) X X

Remote maintenance X X

For a general description of the available running modes, please refer to the chapter "Runningmode description".

3.3.2 AMF (no back synchronisation)Auto mode descriptionThe unit automatically starts the genset and switches to generator supply at a mains failure after an adjusta-ble delay time. It is possible to adjust the unit to change to genset operation in two different ways.



1. The mains breaker will be opened at genset start-up.2. The mains breaker will remain closed until the genset is running, and the genset voltage and frequency is

OK.

In both cases, the generator breaker will be closed when the generator voltage and frequency is OK, and themains breaker is open.

When the mains returns, the unit will switch back to mains supply and cool down and stop the genset. Theswitching back to mains supply is done without back synchronisation when the adjusted "Mains OK delay"has expired.

Semi-auto mode descriptionWhen the generator breaker is closed, the unit will use the nominal frequency as the setpoint for the speedgovernor. If AVR control (option D1) is selected, then the nominal voltage is used as setpoint.


3.3.3 AMF (with back synchronisation)Auto mode descriptionThe unit automatically starts the genset and switches to generator supply at a mains failure after an adjusta-ble delay time. It is possible to adjust the unit to change to genset operation in two different ways:

1. The mains breaker will be opened at genset start-up.2. The mains breaker will remain closed until the genset is running, and the genset voltage and frequency is

OK.

In both cases, the generator breaker will be closed when the generator voltage and frequency is OK, and themains breaker is open.

When the mains returns, the unit will synchronise the mains breaker to the busbar when the "Mains OK de-lay" has expired. Then the genset cools down and stops.

The automatic mains failure mode can be combined with the "Overlap" function. In that case,the generator breaker and the mains breaker will never be closed at the same time for a longerperiod than the adjusted "Overlap" time.

Semi-auto mode descriptionWhen the generator breaker is closed and the mains breaker is opened, the unit will use the nominal frequen-cy as the setpoint for the speed governor. If AVR control (option D1) is selected, the nominal voltage is usedas the setpoint.

When the generator is paralleled to the mains, the governor regulation will no longer be active. If AVR control(option D1) is selected, then the setpoint will be the adjusted power factor (7050 Fixed power set).




3.3.4 Island operationAuto mode descriptionThe unit automatically starts the genset and closes the generator breaker at a digital start command. Whenthe stop command is given, the generator breaker is tripped, and the genset will be stopped after a coolingdown period. The start and stop commands are used by activating and deactivating a digital input or with thetime-dependent start/stop commands. If the time-dependent start/stop commands are to be used, then theauto mode must also be used.

Semi-auto mode descriptionWhen the generator breaker is closed, the unit will use the nominal frequency as setpoint for the speed gov-ernor. If AVR control (option D1) is selected, the nominal voltage is used as setpoint.


3.3.5 Fixed power/base loadAuto mode descriptionThe unit automatically starts the genset and synchronises to the mains when the digital input "auto start/stop"is activated. After the generator breaker closure, the unit ramps up the load to the setpoint level. When thestop command is given, the genset is deloaded and stopped after the cooling down period. The start and stopcommands are used by activating and deactivating a digital input or with the time-dependent start/stop com-mands. If the time-dependent start/stop commands are to be used, then the auto mode must also be used.kW

Sta

rt s

ign

al

Sto

p s

ign

al

tRAMP-UP

t

Diagram, fixed power - principle

Semi-auto mode descriptionWhen the generator breaker is closed and the mains breaker is opened, the unit will use the nominal frequen-cy as the setpoint for the speed governor. If AVR control (option D1) is selected, the nominal voltage is usedas setpoint.

When the generator is paralleled to the mains, the generator power will be increased to the fixed power set-point. If AVR control (option D1) is selected, then the setpoint will be the adjusted power (7050 Fixed powerset).



Setpoints related to fixed power

2610 Power ramp upRamp speed: Defines the slope of the ramp up.Delay point: At this point, the ramp up is cancelled until the delay has expired.Delay: When this delay has expired, the ramp up is continued from the delay point.Enable: Enable load ramp steps.Steps: Defines the number of steps related to the delay point setting.

Po

we

r [k

Wh

]

Time [sec]GB closed

De

lay, ste

p 1

Power ramp

[%/s]

Power Set point

Ra

mp

do

wn

Stop signal

Ra

mp

up

, re

ad

Fro

m lo

ad

sh

are

line

De

lay, ste

p 2

De

lay, ste

p 3

De

lay, ste

p 4

De

lay, ste

p 5

3.3.6 Ramp up with load stepsWhen the GB is closed, the power setpoint continues to rise in ramp up steps, determined by the number ofsteps in menu 2615. If the delay point is set to 20% and the number of load steps is set to 3, the genset willramp to 20%, wait the configured delay time, ramp to 40%, wait, ramp to 60%, wait and then ramp to thepresent power setpoint.

3.3.7 Freeze power rampA way to define the ramp up steps is to use the freeze power ramp command in M-logic.

Freeze power ramp active:

1. The power ramp will stop at any point of the power ramp, and this setpoint will be maintained as long asthe function is active.

2. If the function is activated while ramping from one delay point to another, the ramp will be fixed until thefunction is deactivated again.



3. If the function is activated while the delay timer is timing out, the timer will be stopped and will not contin-ue until the function is deactivated again.

The delay starts running when the GB has been closed.

2620 Power ramp downRamp speed: Defines the slope of the ramp down.Breaker open: The amount of power accepted when opening the breaker.

7050 Fixed power setPower set: The amount of power the genset will produce.


3.3.8 Peak shavingAuto mode descriptionThe genset will start at a predefined mains import level and run at a fixed minimum load, e.g. 10%. When themains import increases above the maximum mains import setpoint, the genset will supply the extra load inorder to maintain the mains import at the maximum import level.

When the load drops below the maximum mains import setpoint, the genset will run at min. load again. Whenthe mains import and the generator load decrease below the stop setpoint, the genset will cool down andstop.

A 4-20 mA transducer is used for indication of the power imported from the mains.



tSTOP

Generator power

Mains power

Peak/total

power

Gen-set stop level

Max. mains import level

Gen-set start level

Gen-set minimum load

t

kW

Diagram, peak shaving – example

Semi-auto mode descriptionWhen the generator breaker is closed and the mains breaker is opened, the unit will use the nominal frequen-cy as setpoint for the speed governor. If AVR control (option D1) is selected, the nominal voltage is used assetpoint.

When the generator is paralleled to the mains, the generator will be controlled according to the peak shavingsetpoint. So the maximum mains import will not be exceeded in spite of the semi- auto mode. If AVR control(option D1) is selected, the setpoint is the adjusted power factor (7050 Fixed power set).

Setpoints related to peak shaving

7000 Mains powerDay and night: The mains power import limits for the peak shaving.Tmax and Tmin: The transducer range in kW which corresponds to the 4-20 mA transducer signal connec-

ted on multi-input 102.

7010 Daytime periodThese settings define the daytime period. The hours outside the daytime period are considered to be thenight-time period.

7020 Start generatorStart setpoint: The start setpoint is in percent of the day and night settings in menu 7000 Mains power.Delay: The genset will start when the start setpoint has been exceeded and this delay has expired.



7020 Start generatorLoad: The minimum load the genset will produce when parallel to mains.

7030 Stop generatorStop setpoint: The stop setpoint is in percent of the day and night settings in menu 7000 Mains power.Delay: The genset will stop when the stop setpoint has been exceeded and this delay has expired.


3.3.9 Load takeoverAuto mode description- Back synchronising ONThe purpose of the load takeover mode is to transfer the load imported from the mains to the genset for oper-ation on generator supply only.

When the start command is given, the genset will start and synchronise the generator breaker to the busbarthat is being supplied by the mains. When the generator breaker is closed, the imported load is decreased(the power is being transferred to the genset) until the load is at the open breaker point. Then the mainsbreaker opens.

When the stop command is given, the mains breaker is synchronised to the busbar and after closure the gen-set is deloaded, cooled down and stopped.

A 4-20 mA transducer is used for indication of the power imported from the mains.kW

Sta

rt s

ign

al

Sto

p s

ign

al

Mains power

Generator power

MB

op

en

s

GB

op

en

s

t

Diagram, load takeover - example

The load takeover mode can be combined with the overlap function. In that case, the generatorand the mains breakers will never be closed at the same time for a longer period than the ad-justed "overlap" time.



If the imported load is higher than the nominal genset power, an alarm appears and the loadtakeover sequence is paused.

- Back synchronising OFFWhen the start command is given, the genset will start. When the frequency and voltage is OK, the mainsbreaker is opened and the generator breaker is closed. Now, the generator supplies the load until the stopcommand is given. Then, the generator breaker opens and the mains breaker closes. The genset cools downand stops.

A 4-20 mA transducer is used for indication of the power imported from the mains.

If the imported load is higher than the nominal genset, an alarm appears and the load takeoversequence is paused.

Semi-auto modeWhen the generator breaker is closed and the mains breaker is opened, the unit will use the nominal frequen-cy as setpoint for the speed governor. If AVR control (option D1) is selected, the nominal voltage is used assetpoint.

When the generator is paralleled to the mains, it will be controlled so the imported power from the mains willbe kept at 0 kW. If AVR control (option D1) is selected, the setpoint is the adjusted power factor (7050 Fixedpower set).


3.3.10 Mains power export (fixed power to mains)Auto mode descriptionThe mains power export mode can be used to maintain a constant level of power through the mains breaker.The power can be exported to the mains or imported from the mains, but always at a constant level.

If a fixed level of imported power must be used, it is still the mains power export mode thatmust be selected! This mode covers import as well as export.

The genset starts as a result of a digital start command. It synchronises to the mains and will start to exportpower to the mains. The amount of power exported will be kept at a fixed level regardless of the load on thebusbar (the factory).

The stop command will cause the genset to deload and trip the generator breaker. Afterwards, it will cooldown and stop.

A 4-20 mA transducer is used for indication of the power exported from the mains.



Mains power export

setpoint

Ramp up

Ramp down

kW

t

Sta

rt s

ign

al

Sto

p s

ign

al

Diagram, mains power export - example

Please notice that the setpoint of the mains power export can be adjusted to 0 kW. This meansthat the genset will be parallel to the mains but no power import or export.

Semi-auto mode descriptionWhen the generator breaker is closed and the mains breaker is opened, the unit will use the nominal frequen-cy as setpoint for the speed governor. If AVR control (option D1) is selected, the nominal voltage is used assetpoint.

When the generator is paralleled to the mains, it will be controlled according to the mains power export set-point. If AVR control (option D1) is selected, the setpoint is the adjusted power factor (7050 Fixed powerset).


3.4 Running mode description

3.4.1 Semi-auto modeThe unit can be operated in semi-auto mode. Semi-auto means that the unit will not initiate any sequencesautomatically, as is the case with the auto mode. It will only initiate sequences, if external signals are given.

An external signal may be given in three ways:

1. Push-buttons on the display are used2. Digital inputs are used3. Modbus command

The standard AGC is only equipped with a limited number of digital inputs, please refer to "Dig-ital inputs" in this document and the data sheet for additional information about availability.



When the genset is running in semi-auto mode, the unit will control the speed governor and the AVR, if optionD1 is selected.

The following sequences can be activated in semi-auto:

Command Description Comment

Start The start sequence is initiated and continues until the genset starts or themaximum number of start attempts has been reached. The frequency(and voltage) will be regulated to make the GB ready to close.

Stop The genset will be stopped. After disappearance of the running signal,the stop sequence will continue to be active in the ‘"extended stop time"period. The genset is stopped with cooling down time.

The coolingdown time iscancelled if thestop button isactivated twice.

Close GB The unit will close the generator breaker if the mains breaker is open,synchronise and close the generator breaker if the mains breaker isclosed.

When AMFmode is selec-ted, the unit willnot regulate afterbreaker closure.

Open GB The unit will ramp down and open the generator breaker at the breakeropen point if the mains breaker is closed. The unit will open the genera-tor breaker instantly if the mains breaker is open or the genset mode isisland mode.

Close MB The unit will close the mains breaker if the generator breaker is open,synchronise and close the mains breaker if the generator breaker isclosed.

Open MB The unit opens the mains breaker instantly.

ManualGOV UP

The regulator is deactivated and the governor output is activated as longas the GOV input is ON.

ManualGOVDOWN

The regulator is deactivated and the governor output is activated as longas the GOV input is ON.

ManualAVR UP

The regulator is deactivated and the governor output is activated as longas the AVR input is ON.

Option D1 is re-quired.

ManualAVRDOWN

The regulator is deactivated and the governor output is activated as longas the AVR input is ON.

Option D1 is re-quired.

3.4.2 Test modeThe test mode function is activated by selecting test with the MODE push-button on the display or by activat-ing a digital input.

The settings for the test function are set up in menu

7040 Test

Setpoint: Load setpoint when paralleling to mains.



7040 Test

Timer: Engine run time during the test period.

Return: When the test is completed, the unit will return to the selected mode (semi-auto or auto).

Type: Selection of one of the three types of tests: Simple, Load or Full.

If the timer is set to 0.0 min., the test sequence will be infinite.

If the DG unit is in the stop sequence in test mode and the mode is changed to semi-auto, theDG will continue to run.

Test mode in island operation (genset mode selected to island mode) can only run "Simple"and "Full" test.

3.4.3 Simple testThe simple test will only start the genset and run it at nominal frequency with the generator breaker open. Thetest will run until the timer expires.

3.4.4 Load testThe load test will start the genset and run it at nominal frequency, synchronise the generator breaker and pro-duce the power typed in the setpoint in menu 7041. The test will run until the timer expires.

To run the load test, it is required that "Sync to Mains" is enabled in menu 7084.

When running a load test sequence, the overlap function is ignored.

3.4.5 Full testThe full test will start the genset and run it at nominal frequency, synchronise the generator breaker andtransfer the load to the generator before opening the mains breaker. When the test timer expires, the mainsbreaker will be synchronised and the load is transferred back to the mains before the generator breaker isopened and the generator is stopped.

To run the full test, it is required that "Sync to Mains" is enabled in menu 7084.

3.4.6 Manual modeWhen manual mode is selected, the genset can be controlled from the display and with digital inputs. Thefollowing commands are possible:



Command Description Comment

Start The start sequence is initiated and continues until the genset startsor the maximum number of start attempts has been reached.

No regulation.

Stop The genset will be stopped. After disappearance of the running sig-nal, the stop sequence will continue to be active in the "extendedstop time" period. The genset is stopped with cooling down time.

Close GB The unit will close the generator breaker if the mains breaker isopen, and synchronise and close the generator breaker if the mainsbreaker is closed.

No regulation.Sync. failure is de-activated.

Open GB The unit will open the generator breaker instantly.

Close MB The unit will close the mains breaker if the generator breaker isopen, and synchronise and close the mains breaker if the generatorbreaker is closed.

No regulation.Sync. failure is de-activated.

Open MB The unit will open the mains breaker instantly.

Manual GOVUP

The unit gives increase signal to the speed governor.

Manual GOVDOWN

The unit gives decrease signal to the speed governor.

Manual AVRUP

The unit gives increase signal to the AVR. Option D1 is re-quired.

Manual AVRDOWN

The unit gives decrease signal to the AVR. Option D1 is re-quired.

It is possible to open and close both the generator breaker and the mains breaker in manualmode.

3.4.7 Block modeWhen the block mode is selected, the unit is locked for certain actions. This means that it cannot start thegenset or perform any breaker operations.

To change the running mode from the display, the user will be asked for a password before the change canbe made. It is not possible to select "block mode" when running feedback is present.

The purpose of the block mode is to make sure that the genset does not start for instance during mainte-nance work.

If the digital inputs are used to change the mode, then it is important to know that the input configured toblock mode is a constant signal. So, when it is ON, the unit is in a blocked state, and when it is OFF, it returnsto the mode it was in before block mode was selected.

If block mode is selected using the display after the digital block input is activated, the AGCwill stay in block mode after the block input is deactivated. The block mode must now bechanged using the display. The block mode can only be changed locally by display or digitalinput.

Before the running mode is changed, it is important to check that persons are clear of the gen-set and that the genset is ready for operation.



Alarms are not influenced by block mode selection.

The genset can be started from the local engine control panel, if such is installed. Therefore,DEIF recommends avoiding local cranking and starting of the genset.

The genset will shut down if block mode is selected while the genset is running.

3.5 Single-line diagrams

3.5.1 Application illustrationIn the following, the various applications are illustrated in single-line diagrams.

3.5.2 Automatic Mains Failure

G

Controller

Load

3.5.3 Island operation

G

Controller

Load



3.5.4 Fixed power/base load

G

Controller

Load

3.5.5 Peak shaving

G

Controller

Load

P/4-20 mA

TRANSDUCER



3.5.6 Load takeover

G

Controller

Load

P/4-20 mA

TRANSDUCER

3.5.7 Mains power export

G

Controller

Load

P/4-20 mA

TRANSDUCER



3.5.8 Multiple gensets, load sharing (option G3 required)

G

Controller

Load

G

Controller

3.5.9 Multiple gensets, power management (option G5 required)- Island mode application

G

Generator

breaker

(GB 1)

Diesel generator set 1

Busbar

G

Generator

breaker

(GB 2)


CANbus

Controller

Display 1

Controller

Display 2



- Parallel to mains application

G

Generator

breaker

(GB 1)


Busbar

G

Generator

breaker

(GB 2)


CANbus

Tie

Breaker

(GB)

Mains

breaker

(MB)

Mains

Consumers

Controller

Display 1

Controller

Display 2

Controller

Display mains



- Parallel with two mains with a tie breaker (the tie breaker is optional)

G

Generator

breaker

(GB 1)


Busbar

G

Generator

breaker

(GB 2)


CANbus

Tie

Breaker

(GB)

Mains

breaker

(MB 1)

Mains 1

Consumers

Mains

breaker

(MB 2)

Mains 2

Optional Optional

Controller

Display 1

Controller

Display 2

Controller

Display mains 1B

Controller

Display mains 2A

Controller

Display mains 2B

Controller

Display mains 1A



- Multi mains with two mains, two tie breakers, one bus tie breaker and four gensets

Generator

breaker

(GB 1)

BTB 33

Controller

Display BTB 33

Display

Tie

Breaker

(TB 17)

Mains

breaker

(MB 17)

Mains 17

Load

Display

Controller

CANbus

CANbus

CANbus

Display

Tie

Breaker

(TB 18)

Mains

breaker

(MB 18)

Mains 18

Load

Display

Controller

G

Generator

breaker

(GB 3)


Busbar

G

Generator

breaker

(GB 4)


CANbus

Controller

Display 3

Controller

Display 4

G


Busbar

G

Generator

breaker

(GB 2)


CANbus

Controller

Display 1

Controller

Display 2

AOP 1 AOP 2 AOP 2AOP 1

Optional Optional

The diagram shows four generators, but the system supports up to 16 generators. Please referto the option G5 manual for further description of multi mains.



- ATS plant, mains unitDisplay

Tie

Breaker

(TB)

Mains

Consumers

Controller

G


Controller

Display 3

G


Busbar

G


CANbus

Controller

Display 1

Controller

Display 2

ATSON/OFF

Mains okay

- Remote maintenance

LOAD

G

Controller

Relay

The diagram shows a setup using the remote maintenance box. Please refer to the operator’smanual of the remote maintenance box for further description.

3.6 Flowcharts

Using flowcharts, the principles of the most important functions will be illustrated in the next sections. Thefunctions included are:

Mode shift MB open sequence GB open sequence Stop sequence Start sequence MB close sequence



GB close sequence Fixed power Load takeover Island operation Peak shaving Mains power export Automatic Mains Failure Test sequence

The flowcharts on the following pages are for guidance only. For illustrative purposes, theflowcharts are simplified in some extent.

3.6.1 Mode shift

Start

Plant mode not

Island and AMF

Mains failure

Initiate AMF

sequence

End

No

No

Yes

Yes

Mode shift

enabled

No

Yes

Mains OK timer

timed out

Initiate mains

return sequence

MB close

sequence

Continue in

selected mode

YesNo



3.6.2 MB open sequence

Start

Load take

over

Load = 0

Open MB

End

No

No

Yes

MB closedNo

Yes

MB openedAlarm ”MB

open failure”

Yes

No

Mains failure

Deload MB

Load too

highAlarm

Yes

No

Yes



3.6.3 GB open sequence

Start

Is GB

closed

Load < open

set point

Open GB

End

No

No

Yes

Stop conditions

OK

No

Yes

GB opened Alarm

Yes

No

Failclas

shutdown

Deload DG

Ramp down

timer expired

Yes

No

Yes

Soft open

Yes

No



3.6.4 Stop sequence

Start

GB open

seq OK

Run coil

Deactivate

”stop” relay

End

No

No

Yes

Stop conditions

OK

No

Yes

Genset

stoppedAlarm

Yes

No

Yes

AUTO

mode

Yes

No

Cooldown

timer run out

Stop relay

Activate stop

relay

Yes

No



3.6.5 Start sequence

Start

Start prepare

timer

Stop relay timer

timed out

Off relay

ON

End

No

No

Yes

Start condition

OK

No

Yes

Max start

attempts

Ready to

close GB

Yes

No

Yes

Start relay timer

timeout

Yes

No

Start relay

ON

Start failure

alarm

Alarm

F/U OK

Run feedback

detected

Genset startedNo

Yes

No

No

Yes

Yes



3.6.6 MB close sequenceStart

Voltage on

mains/bus

Synchronised

Sync MB

End

No

No

Yes

Is MB open

No

Yes

MB closedClose failure

alarm

Yes

Yes

GB closed

Yes

No

Alarm sync.

failure

Sync timer

runout

GB open

sequence

YesNo

Yes

Voltage on

gen

Back sync ON

Close MB

Alarm GB

open failure

Direct close OK

No

Yes

Yes

No

No

No



3.6.7 GB close sequence

Voltage on bus

Single DG

application

Start

Start seq OK

End

NoIs GB open

Yes

Yes

Island mode

Yes

No

MB close TB Present

All GBs OFF

TB open

Voltage on

busbar

MB open

Direct closing

OKSync GB Time runout

DG freq match

BB freq

Close GB

GB closed

Alarm sync

failure

Alarm

No

No

No

No

No

Yes

Yes

Yes

Yes

Yes

No

Yes

No

Yes

No

No

No

Yes

Yes

No

Yes Yes

No

Yes



3.6.8 Fixed power

Start

Deactivate

start input

End

OperationRamp-up to

load set-point

Activate start

input

Start

sequence

GB close

sequence

GB open

sequence

Stop

sequence



3.6.9 Load takeover

Start

MB open

sequence

End

Ramp-up

genset load

Activate start

input

Start

sequence

GB close

sequence

Deactivate

start input

MB close

sequence

Mains load = 0 kW

Yes

No

Genset

operation

GB open

sequence

Stop

sequence




Start

End

Operation

Start input

deactivated

Start input

active

Start

sequence

GB close

sequence

GB open

sequence

Stop

sequence



3.6.11 Peak shaving

Start

End

Operation:

produce power

above set point

Mains power

below stop

set point

Mains power

above start

set point

Start

sequence

GB close

sequence

GB open

sequence

Stop

sequence



3.6.12 Mains power export

Start

End

operation

Activate start

input

Start

sequence

Close GB

sequence

Deactivate

start input

GB open

sequence

Stop

sequence

Ramp up to

MPE set point



3.6.13 Automatic Mains Failure

Start

#7065: start

eng + open MB

End

Mains failureNo

Yes

MB close

sequence

Open MB

Start sequence

GB close

sequence

Mains ok

Time out

Start sequence

Open MB

GB close

sequence

No

Yes

No

Yes



3.6.14 Test sequence

Start

Timer run out

Engine stopped

Return to

running mode,

menu 7043

End

No

Ramp up to

P set point

Yes

No

Stop sequnce

P Mains = 0kW Open MB

Yes

No

Yes

Select test

mode

Start sequnce

Test timer

Engine running

Freq/voltage OK

Opening og MB

allowed

Sync of GB

allowed

Sync GB

Yes

No

Yes

Yes

No

No

No



3.7 Sequences

The following contains information about the sequences of the engine, the generator breaker and, if installed,the mains breaker. These sequences are automatically initiated if the auto mode is selected, or if the com-mands are selected in the semi-auto mode.

In the semi-auto mode, the selected sequence is the only sequence initiated (e.g. press the START push-button: The engine will start, but no subsequent synchronising is initiated).

The following sequences will be illustrated below:

START sequence STOP sequence Breaker sequences

If island operation is selected, the digital input "MB closed" must NOT be activated with a 12/24 volt inputsignal. A "mains breaker failure" will occur if the wiring of the mains breaker feedback inputs is wrong.

Refer to our application notes or installation instructions for information about the requiredbreaker wiring.

We recommend not using small relays for stop coil output. If small relays are used, a resistormust be mounted across the relay coil to prevent undesirable closing of the relay. This iscaused by the wirebreak function.

3.7.1 Start sequenceThe following drawings illustrate the start sequences of the genset with normal start prepare and extendedstart prepare.



No matter the choice of start prepare function, the running coil is activated 1 sec. before the start relay (start-er).

Start sequence:

Normal start prepare

tOFF tOFF

1 sec.

2nd start attempt1st start attempt 3rd start attempt

Crank (starter)

Start prepare

Stop coil

Run coil

Running feedback



Start sequence:

Extended start prepare

tOFF tOFF

1 sec.

2nd start attempt1st start attempt 3rd start attempt

Crank (starter)

Start prepare

Stop coil

Run coil

Running feedback

Run coil can be activated from 1...600 sec. before crank (starter) will be executed. In the aboveexample, the timer is set to 1 sec. (menu 6150).

3.7.2 Start sequence conditionsThe start sequence initiation can be controlled by the following conditions:

VDO 102 (oil pressure) VDO 105 (water temperature) VDO 108 (fuel level)

This means that if e.g. the oil pressure is not primed to the sufficient value, then the crank relay will not en-gage the starter motor.

The selection is made in setting 6185. For each of the VDO settings, the rule is that the value (oil pressure,fuel level or water temperature) must exceed the setpoint of setting 6186 before starting is initiated.

If the value in 6186 is set to 0.0, the start sequence is initiated as soon as it is requested.

The diagram below shows an example where the VDO signal builds up slowly and starting is initiated at theend of the third start attempt.



Start sequence

Cranking depends on VDO

Start prepare

(3 start attempts)

Stop relay

Running feedback

Crank relay

Run coil

VDO

measurement OK

VDO value

Cranking starts

1 2 3

3.7.3 Running feedbackDifferent types of running feedback can be used to detect if the motor is running. Refer to menu 6170 for se-lection of the running feedback type.

The running detection is made with a built-in safety routine. The running feedback selected is the primaryfeedback. At all times all the types of running feedback is used for running detection. If, for some reason, theprimary choice is not detecting any running feedback, the starter relay will stay activated for 1 additional sec-ond. If a running feedback is detected based on one of the secondary choices, the genset will start. This way,the genset will still be functional even though a tacho sensor is damaged or dirty.

As soon as the genset is running, no matter if the genset is started based on the primary or secondary feed-back, the running detection will be made based on all available types.

The sequence is shown in the diagram below.



Running feedback failure

Primary running

feedback

Start relay (crank)

Secondary running

feedback

Alarm

tAlarm

1sec

Interruption of start sequenceThe start sequence is interrupted in the following situations:

Event Comment

Stop signal

Start failure

Remove starter feedback Tacho setpoint.

Running feedback Digital input.

Running feedback Tacho setpoint.

Running feedback Frequency measurement above 32 Hz.The frequency measurement requires a voltage measurement of 30% ofUNOM.The running detection based on the frequency measurement can replacethe running feedback based on tacho or digital input or engine communica-tion.

Running feedback Oil pressure setpoint (menu 6175).

Running feedback EIC (engine communication) (option H5 or H7).

Emergency stop

Alarm Alarms with shutdown" or "trip and stop" fail class.

Stop push-button on display Only in semi-auto or manual mode.

Modbus stop command Semi-auto or manual mode.

Binary stop input Semi-auto or manual mode.

Deactivate the "auto start/stop"

Auto mode in the following genset modes:Island operation, fixed power, load takeover or mains power export mode.

Running mode It is not possible to change the running mode to "block" as long as the gen-set is running.

If the MPU input is to be used to remove the starter, it has to be set up in menu 6174.



The only protections that can stop the genset/interrupt the start sequence when the "shutdownoverride" input is activated, are the digital input "emergency stop" and the alarm "overspeed2". Both of these must have the fail class "shut down".

Setpoints related to the start sequence- Crank failure alarm (4530 Crank failure)If MPU is chosen as the primary running feedback, this alarm will be raised if the specified rpm is not reachedbefore the delay has expired.

- Run feedback failure (4540 Run feedb. fail)If running is detected on the frequency (secondary), but the primary running feedback, e.g. digital input, hasnot detected running, this alarm will be raised. The delay to be set is the time from the secondary runningdetection and until the alarm is raised.

- Hz/V failure (4550 Hz/V failure)If the frequency and voltage are not within the limits set in menu 2110 after the running feedback is received,this alarm is raised when the delay has expired.

- Start failure alarm (4570 Start failure)The start failure alarm occurs, if the genset has not started after the number of start attempts set in menu6190.

- Start prepare (6180 Starter)Normal prepare: The start prepare timer can be used for start preparation purposes, e.g. prelubrication orpreglowing. The start prepare relay is activated when the start sequence is initiated and deactivated when thestart relay is activated. If the timer is set to 0.0 s, the start prepare function is deactivated.

Extended prepare: The extended prepare will activate the start prepare relay when the start sequence is initi-ated and keep it activated when the start relay activates until the specified time has expired. If the ext. pre-pare time exceeds the start ON time, the start prepare relay is deactivated when the start relay deactivates. Ifthe timer is set to 0.0 s, the extended prepare function is deactivated.

Start ON time: The starter will be activated for this period when cranking.

Start OFF time: The pause between two start attempts.



3.7.4 Stop sequenceThe drawings illustrate the stop sequence.

tCOOL

text

Run coilStop sequence

Cooling down time

Run coil

Running feedback

Sequence initiated

tCOOL

text

Stop coilStop sequence

Cooling down time

Stop coil

Running feedback

Sequence initiated

The stop sequence will be activated if a stop command is given. The stop sequence includes the coolingdown time if the stop is a normal or controlled stop.



Description Coolingdown

Stop Comment

Auto mode stop X X

Trip and stop alarm X X

Stop button on display (X) X Semi-auto or manual. Cooling down is interrupted if thestop button is activated twice.

Remove "auto start/stop" X X Auto mode: Island operation, fixed power, load takeover,mains power export.

Emergency stop X Engine shuts down and GB opens.

The stop sequence can only be interrupted during the cooling down period. Interruptions can occur in thesesituations:

Event Comment

Mains failure AMF mode selected (or mode shift selected ON) and auto mode selected.

Start button is pressed Semi-auto mode: Engine will run in idle speed.

Binary start input Auto mode: Island operation and fixed power, load takeover or mains powerexport.

Exceeding setpoint Auto mode: Peak shaving.

GB close button is pressed Semi-auto mode only.

The stop sequence can only be interrupted during the cooling down period.

When the engine is stopped, the analogue speed governor output is reset to the offset value.Please refer to the mentioned option descriptions.

Setpoints related to the stop sequence

- Stop failure (4580 Stop failure)A stop failure alarm will appear if the primary running feedback or the generator voltage and frequency arestill present after the delay in this menu has expired.

- Stop (6210 Stop)Cooling down:The length of the cooling down period.

Extended stop:The delay after the running feedback has disappeared until a new start sequence is allowed. The extendedstop sequence is activated any time the Stop button is pressed.

Cool down controlled by engine temperature:The engine temperature-controlled cool down is to ensure that the engine is cooled down below the setpointin menu 6214 "Cool down temperature" before the engine is stopped. This is particularly beneficial if the en-gine has been running for a short period of time and therefore not reached normal cooling water temperature,as the cool down period will be very short or none at all. If the engine has been running for a long period, itwill have reached normal running temperature, and the cool down period will be the exact time it takes to getthe temperature below the temperature setpoint in menu 6214.



If, for some reason, the engine cannot get the temperature below the temperature setpoint in 6214 within thetime limit in parameter 6211, the engine will be shut down by this timer. The reason for this could be highambient temperature.

If the cooling down timer is set to 0.0 s, the cooling down sequence will be infinite.

If the cooling down temperature is set to 0 deg., the cooling down sequence will be entirelycontrolled by the timer.

3.7.5 Breaker sequencesThe breaker sequences will be activated depending on the selected mode:

Mode Genset mode Breaker control

Auto All Controlled by the unit

Semi-auto All Push-button

Manual All Push-button

Block All None

Before closing the breakers it must be checked that the voltage and frequency are OK. The limits are adjus-ted in menu 2110 Sync. blackout.

Setpoints related to MB control

7080 MB controlMode shift: When enabled, the AGC will perform the AMF sequence in case of a mains failure re-

gardless of the actual genset mode.

MB close delay: The time from GB OFF to MB ON when back synchronisation is OFF.

Back sync.: Enables synchronisation from mains to generator.

Sync. to mains: Enables synchronisation from generator to mains.

Load time: After opening of the breaker, the MB ON sequence will not be initiated before this de-lay has expired. Please refer to the description of "Breaker spring load time".

If no MB is represented, then the relays and inputs normally used for MB control become con-figurable. The power plant constructor (USW) is used for configuration of the plant design ifthe application does not include an MB.

AGC without back synchronisation: The GB can only be closed if the mains breaker is open.The MB can only be closed if the generator breaker is open.

AGC with back synchronisation: If the GB or MB push-button is activated, the AGC will startsynchronising if the generator or mains voltage is present. The GB can close directly if the MBis open. The MB can close directly if the GB is open.



- AMF MB opening (7060 U mains failure)

It is possible to select the functionality of the mains breaker closing function. This is necessary if the unit op-erates in Automatic Mains Failure (AMF).

The possibilities are:

Selection Description

Start engine and openmains breaker

When a mains failure occurs, the mains breaker opens, and the engine starts atthe same time.

Start engine When a mains failure occurs, the engine starts. When the generator is runningand the frequency and voltage are OK, the MB opens and the GB closes.

3.7.6 AMF timersThe time charts describe the functionality at a mains failure and at mains return. Back synchronisation is de-activated. The timers used by the AMF function are indicated in the table below:

Timer Description Menu number

tFD Mains failure delay 7070 f mains failure7060 U mains failure

tFU Frequency/voltage OK 6220 Hz/V OK

tFOD Mains failure OK delay 7070 f mains failure7060 U mains failure

tGBC GB ON delay 6230 GB control

tMBC MB ON delay 7080 MB control

The timer tMBC is only active if back synchronisation is deactivated.

Example 1:7065 Mains fail control: Start engine and open MB

GB On

MB On

Mains failure

detected

Gen start seq

tFD

Gen stop seq

Mains OK

Mains OK

tFOD

tFU

tMBC

Gen running

Gen f/U OK



Example 2:7065 Mains fail control: Start engine

tGBC

GB On

MB On

Mains failure

detected

Gen start seq

tFD

Gen stop seq

Mains OK

Mains OK

tFOD

tFU

tMBC

Gen running

Gen f/U OK

Conditions for breaker operationsThe breaker sequences react depending on the breaker positions and the frequency/voltage measurements.

The conditions for the ON and OFF sequences are described in the table below:

Conditions for breaker operations

Sequence Condition

GB ON, direct closing Running feedbackGenerator frequency/voltage OKMB open

MB ON, direct closing Mains frequency/voltage OKGB open

GB ON, synchronising Running feedbackGenerator frequency/voltage OKMB closedNo generator failure alarms

MB ON, synchronising Mains frequency/voltage OKGB closedNo generator failure alarms

GB OFF, direct opening MB open

MB OFF, direct opening Alarms with fail classes:Shut down or Trip MB alarms

GB OFF, deloading MB closed

MB OFF, deloading Alarms with fail class:Trip and stop



4. Display unit and menu structure4.1 Presentation

This chapter deals with the display unit including the push-button and LED functions. In addition, the unitmenu structure will be presented.

4.2 Display unit (DU-2)

The display has four different lines, each with 20 characters, and holds a number of push-button functions.

Display dimensions are H x W = 115 x 220 mm (4.528” x 9.055”).

4.2.1 Push-button functionsThe display unit holds a number of push-button functions which are described below:

Automatic Gen-set Controller

VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

MODE

JUMP

START

INFO

STOP

Alarm

Alarm

multi-line AGC

On On

Load

Run

G

AMF SEMI-AUTOG-L1 50.0 HzG 0.90I PFSETUP

400V150kW

V3V2V1

15

14

13

12

1 2 3 4

5

6

78911 10

1. Shifts the first line displaying in the setup menus. Push 2 sec. to switch to master display in case morethan one display is connected.

2. Moves the cursor left for manoeuvring in the menus.3. Inreases the value of the selected setpoint (in the setup menu). In the daily use display, this button func-

tion is used for scrolling the View lines in V1 or the second line (in the setup menu) displaying of genera-tor values.

4. Selects the underscored entry in the fourth line of the display.5. Moves the cursor right for manoeuvring in the menus.6. Decreases the value of the selected setpoint (in the setup menu). In the daily use display, this button

function is used for scrolling the second line displaying of generator values.7. Changes the menu line (line four) in the display to mode selection.8. Jumps one step backwards in the menu (to previous display or to the entry window).

AGC-4 manual, November 2011, UK Display unit and menu structure


9. Displays the LOG SETUP window where you can choose between the Event, Alarm and Battery logs.The logs are not deleted when the auxiliary supply is switched off.

10. Manual activation of close breaker and open breaker sequence if "SEMI-AUTO" is selected.11. Manual activation of close breaker and open breaker sequence if "SEMI-AUTO" is selected.12. Stop of the genset if "SEMI-AUTO" or "MANUAL" is selected.13. Start of the genset if "SEMI-AUTO" or "MANUAL" is selected.14. Enters a specific menu number selection. All settings have a specific number attached to them. The

JUMP button enables the user to select and display any setting without having to navigate through themenus (see later).

15. Shifts the display three lower lines to show the alarm list.

4.2.2 LED functionsThe display unit holds 10 LED functions. The colour is green or red or a combination in different situations.The display LEDs are indicating as follows:


VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

MODE

JUMP

START

INFO

STOP

Alarm

Alarm

multi-line AGC

On On

Load

Run

G

AMF SEMI-AUTOG-L1 50.0 HzG 0.90I PFSETUP

400V150kW

V3V2V1

10

1

9

2

3

4

7 6 58

1. LED indicates that the auxiliary supply is switched on.2. LED indicates that the unit is OK.3. Please refer to "Alarm inhibit" in the chapter "Additional functions".4. LED indicates that auto mode is selected.5. LED is green if the mains is present and OK. LED is red at a measured mains failure. LED is flashing

green when the mains returns during the "mains OK delay" time.6. LED indicates that the mains breaker is closed. LED is flashing yellow if the "MB spring loaded" signal

from the breaker is missing or the MB load time has not expired.7. LED green light indicates that the generator breaker is closed. LED yellow light indicates that the genera-

tor breaker has received a command to close on a black bus, but the breaker is not yet closed due tointerlocking of the GB. LED is flashing yellow if the "Enable GB black close" or the "GB spring loaded"signal is missing or the GB load time has not expired.

8. LED green light indicates that the voltage/frequency is present and OK.9. LED indicates that the generator is running.10. LED flashing indicates that unacknowledged alarms are present. LED fixed light indicates that ALL alarms

are acknowledged, but some are still present.



4.3 Menu structure

The display includes two menu systems which can be used without password entry:

View menu systemThis is the commonly used menu system. 15 windows are configurable and can be entered by usingthe arrow push-buttons.

Setup menu systemThis menu system is used for setting up the unit, and if the user needs detailed information that is notavailable in the view menu system. Changing of parameter settings is password protected.

4.3.1 Entry windowWhen the unit is powered up, an entry window appears. The entry window is the turning point in the menustructure and as such the gateway to the other menus. It can always be reached by pressing the BACK push-button three times.

The event and alarm list will appear at power up if an alarm is present.

The priority "P00", shown in the lower right corner, is related to the power management optionG4 and G5.



4.3.2 View menuThe view menus (V1, V2 and V3) are the most commonly used menus of the unit.

1

2

3

4


multi-line AGC

G-L1 50 Hz 440VSETUP V3 V2 V1

G 400 400 400VG-L1 50 Hz 440V

1. First display line: Operational status or measurements2. Second display line: Measurements relating to operational status3. Third display line: Measurements relating to operational status4. Fourth display line: Selection of setup and view menus

In the view menus various measured values are on display.

The menu navigating starts from the fourth display line in the entry window and is carried out using the

, , and push-buttons.

The entry window displays view 3 (in the illustration above the window where "manual" is displayed).

Moving the cursor left or right offers the following possibilities.

Setup menu – access to the following sub-menus: Protection setup Control setup I/O setup System setup

View 3 – window displays operational status and selectable measurements View 2 – window displays selectable measurements. The same as view 1 View 1 – access to up to 15 selectable windows displaying selectable measurements

The factory settings for view 1 and view 2 are identical.



4.3.3 Setup menuThe setup menu system is used for parameter setup of the unit, and if the user needs detailed informationthat is not available in the view menu system. So, this menu can be used for both daily use and setup purpo-ses. The menu is entered from the entry window by selecting the entry SETUP in the fourth display line.


multi-line AGC

G 400 400 400V

PROTECTION SETUPPROT CTRL I/O SYST

f-L1 50.00HZ

1

2

3

4

1.First display line(Daily use) The first line is used to display generator and bus values

2.Second display line(Daily use) Various values can be displayed(Menu system) Information about the selected channel number(Alarm/event list) The latest alarm/event is displayed

3.Third display line(Daily use) Explanation for the fourth line cursor selection(Setup menu) Presents setting of the selected function, and, if changes are made, the possible max.

and min. values for the setting

4.Fourth display line(Daily use) Entry selection for the setup menu. Press SEL to enter the underscored menu(Setup menu) Sub-functions for the individual parameters, e.g. limit



Possible values in second display line

View line/second display line configuration

For generator For bus/mains

G f-L1 frequency L1 (Hz) M f-L1 frequency L1 (Hz)



Gen. active power (kW) Mains active power (kW)

Gen. reactive power (kVAr) Mains reactive power (kVAr)

Gen. apparent power (kVA) Mains apparent power (kVA)

Power factor Power factor

Voltage angle between L1-L2 (deg.) Voltage angle between L1-L2 (deg.)



BB U-L1N BB U-L1N

BB U-L2N BB U-L2N

BB U-L3N BB U-L3N

BB U-L1L2 BB U-L1L2

BB U-L2L3 BB U-L2L3

BB U-L3L1 BB U-L3L1

BB U-MAX BB U-MAX

BB U-Min BB U-Min

BB f-L1 BB f-L1

BB AngL1L2-180.0deg BB AngL1L2-180.0deg

BB-G Ang -180.0deg BB-M Ang -180.0deg

U-Supply (power supply V DC) U-Supply (power supply V DC)

Energy counter, total (kWh) Energy counter, total (kWh)

Energy counter, daily (kWh) Energy counter, daily (kWh)

Energy counter, weekly (kWh) Energy counter, weekly (kWh)

Energy counter, monthly (kWh) Energy counter, monthly (kWh)

G U-L1N (voltage L1-N) M U-L1N (voltage L1-N)



G U-L1L2 (voltage L1-L2) M U-L1L2 (voltage L1-L2)



G U-Max (voltage max.) M U-Max (voltage max.)

G U-Min (voltage min.) M U-Min (voltage min.)

G I-L1 (current L1) M I-L1 (current L1)



View line/second display line configuration



Run abs. (absolute run time)

Run rel. (relative run time)

Next prio (next priority shift)

Run ShtD O (shutdown override run time)

Mains power A102 P TB A105

Number of GB operations Number of TB operations

Start attempts

P available P available

P mains P mains

P DGs tot P DGs tot

Number of MB operations Number of MB operations

Service timer 1

Service timer 2

MPU

Multi-input 1 Multi-input 1



Battery asym 1 Battery asym 1

Battery asym 2 Battery asym 2

Power factor Power factor

Cos Phi Cos Phi

Cos Phi reference (current) Cos Phi reference (current)

Power reference (actual)

Power reference (current) Power reference (current)



Setup structure

2010-01-02 09.35.54SETUP V3 V2 V1

AGC V.4.00.0

PROT CTRL I/O SYST

G 400 400 400V

f-L1 50.00HZPROTECTION SETUP

f-L1 50.00HZCONTROL SETUP

G 400 400 400V

PROT CTRL I/O SYST

f-L1 50.00HZINPUT/OUTPUT SETUP

G 400 400 400V

PROT CTRL I/O SYST

f-L1 50.00HZSYSTEM SETUP

G 400 400 400V

PROT CTRL I/O SYST

SP DEL OA OB ENA FC

1000 G -P> 1Setpoint -5.0%

G 400 400 400V

SYNC REG

CONTROL SETUP

SYNCHRONISE SETUP

G 400 400 400V

BIN AIN OUT

INPUT/OUTPUT SETUP

BINARY INPUT SETUP

G 400 400 400V

GEN MAINS COMM PM

SYSTEM SETUP

GENERAL SETUP

G 400 400 400V

BACK SEL

BACK SEL BACK SEL BACK SEL BACK SEL

Setup exampleThe following example illustrates how a specific setting is changed in the setup menu. In this case Reversepower is the selected parameter.

First entry

Increase no.

Decrease no.

Increases setting

Decreases setting

Moves the cursor

YES

NO

PROT CTRL I/O SYST

G 400 400 400VG f-L1 50.00HZPROTECTION SETUP

G 400 400 400V

SP DEL OA OB ENA FC

1000 G -P> 1Setpoint -5.0%

G 400 400 400V

SP DEL OA OB ENA FC

1010 G -P> 2Setpoint -5.0%

ENTER

Enter passw. 2010G 400 400 400V

RESET SAVE

1001 G -P> 1-50.0 -5.0 0.0%

G 400 400 400V

BACK

BACK

4.4 Mode overview

The unit has four different running modes and one block mode. For detailed information see chapter "Applica-tion".

AutoIn auto mode the unit will operate automatically, and the operator cannot initiate any sequences manually.



Semi-autoIn semi-auto mode the operator has to initiate all sequences. This can be done via the push-button functions,Modbus commands or digital inputs. When started in semi-automatic mode, the genset will run at nominalvalues.

TestThe test sequence will start when the test mode is selected.

ManualWhen manual mode is selected, the binary increase/decrease inputs can be used (if they have been config-ured) as well as the start and stop push-buttons. When starting in manual mode, the genset will start withoutany subsequent regulation.

BlockWhen the block mode is selected, the unit is not able to initiate any sequences, e.g. the start sequence.

Block mode must be selected when maintenance work is carried out on the genset.

The genset will shut down if block mode is selected while the genset is running.

4.5 Mode selection

The following drawings illustrate how the mode selection is carried out.

Pushing the MODE push-button will change the displayed text. After pushing "MODE", the fourth display lineindicates the selectable modes. In the third display line, the underscored (fourth line) selection will be dis-played.

Two possibilities are now available:

If "BACK" is pushed, the display returns to the original text without changing the mode.

SETUP MENUSETUP V3 V2 V1

AGC V 4.00.02010-01-02 13:45:18

SEMI-AUTO MODESEMI TST AUT MAN BLK

AGC V 4.00.02010-01-02 13:45:18

2. push1. push

MODEBACK

or

PROTECTION SETUP PROT CTRL I/O SYST

G 0 0 0VF-L1 0.00HZ


G 0 0 0VF-L1 0.00HZ

2. push1. push

MODEBACK

If "SEL" is pushed, the underlined mode is selected, and the display returns to the original text. In this exam-ple the SEMI-AUTO mode is selected.



SETUP MENUSETUP V3 V2 V1

AGC V 4.00.02010-01-02 13:45:18


AGC V 4.00.02010-01-02 13:45:18

4. push3. push

MODESEL

or

PROTECTION SETUP PROT CTRL I/O SYST

G 0 0 0VF-L1 0.00HZ


G 0 0 0VF-L1 0.00HZ

4. push3. push

MODE SEL

4.6 Password

The unit includes three password levels. All levels can be adjusted in the PC software.

Available password levels:

Password level Factory setting Access

Customer Service Master

Customer 2000 X

Service 2001 X X

Master 2002 X X X

A parameter cannot be entered with a too low ranking password. But the settings can be displayed withoutpassword entry.



Each parameter can be protected at a specific password level. To do so, the PC utility software must beused. Enter the parameter to be configured and select the correct password level.

The password level can also be changed from the parameter view in the column Level.



4.6.1 Parameter accessTo gain access to adjust the parameters, the password level must be entered:

If the password level is not entered, it is not possible to enter the parameters.

The customer password can be changed in menu 9116. The service password can be changedin menu 9117. The master password can be changed in menu 9118.

The factory passwords must be changed if the operator of the genset is not allowed to changethe parameters.

It is not possible to change the password at a higher level than the password entered.



5. Additional functions5.1 Start functions

The unit will start the genset when the start command is given. The start sequence is deactivated when theremove starter event occurs or when the running feedback is present.

The reason for having two possibilities to deactivate the start relay is to be able to delay the alarms with runstatus.

If it is not possible to activate the run status alarms at low revolutions, the remove starter function must beused.

An example of a critical alarm is the oil pressure alarm. Normally, it is configured according to the shutdownfail class. But if the starter motor has to disengage at 400 RPM, and the oil pressure does not reach a levelabove the shutdown setpoint before 600 RPM, then, obviously, the genset would shut down if the specificalarm was activated at the preset 400 RPM. In that case, the running feedback must be activated at a highernumber of revolutions than 600 RPM.

t

RPM

Oil

pre

ssu

re

400

1000

RPM

600

Ru

nn

ing

Re

mo

ve

sta

rte

r

5.1.1 Digital feedbacksIf an external running relay is installed, then the digital control inputs for running detection or remove startercan be used.

Running feedbackWhen the digital running feedback is active, the start relay is deactivated and the starter motor will be disen-gaged.

AGC-4 manual, November 2011, UK Additional functions


t

RPMRPMNOM

Run. feedback

RPM

Firing speed

The diagram illustrates how the digital running feedback (terminal 117) is activated when the engine hasreached its firing speed.

Remove starterWhen the digital remove starter input is present, the start relay is deactivated and the starter motor will bedisengaged.

t

RPMRPMNOM

Remove starter

Run. feedback

RPM

Firing speed Running

The diagram illustrates how the remove starter input is activated when the engine has reached its firingspeed. At the running speed, the digital running feedback is activated.

The remove starter input must be configured from a number of available digital inputs.

The running feedback is detected by either the digital input (see diagram above), frequencymeasurement above 32 Hz, RPM measured by magnetic pick-up or EIC (option H5/H7).

5.1.2 Analogue tacho feedbackWhen a magnetic pick-up (MPU) is being used, the specific level of revolutions for deactivation of the startrelay can be adjusted.

Running feedbackThe diagram below shows how the running feedback is detected at the firing speed level. The factory settingis 1000 RPM (6170 Running detect.).



t

RPMRPMNOM

Run. feedback,

menu 4301

RPM

Firing speed

Notice that the factory setting of 1000 RPM is higher than the RPM level of starter motors oftypical design. Adjust this value to a lower value to avoid damage of the starter motor.

Remove starter inputThe drawing below shows how the setpoint of the remove starter is detected at the firing speed level. Thefactory setting is 400 RPM (6170 Running detect.).

t

RPMRPMNOM

Remove starter,

menu 6161

RPM


Run. feedback,

menu 4301

The number of teeth on the flywheel must be adjusted in menu 6170 when the MPU input isused.

5.1.3 Oil pressureThe multi-inputs on terminals 102, 105 and 108 can be used for the detection of running feedback. The termi-nal in question must be configured as a VDO input for oil pressure measurement.

When the oil pressure increases above the adjusted value (6175 Pressure level) then the running feedbackis detected and the start sequence is ended.



Running feedback

t

RPMRPMNOM

Run detection

Oil pressure

menu 6175

RPM / Oil pressure

Firing speed

Remove starter inputThe drawing below shows how the setpoint of the "remove starter input" is detected at the firing speed level.The factory setting is 400 RPM (6170 Running detect.).

t

RPMRPMNOM

Remove starter,

menu 6161

RPM / Oil pressure


Run detection

Oil pressure

menu 6175

The remove starter function can use the MPU or a digital input.

5.2 Breaker types

There are five possible selections for the setting of breaker type for both mains breaker and generator break-er.

Continuous NE and Continuous NDThis type of signal is most often used combined with a contactor. When using this type of signal, the AGC willonly use the close breaker relays. The relay will be closed for closing of the contactor and will be opened foropening of the contactor. The open relay can be used for other purposes. Continuous NE is a normally ener-gised signal, and Continuous ND is a normally deenergised signal.

PulseThis type of signal is most often used combined with circuit breaker. With the setting pulse the AGC will usethe close command and the open command relay. The close breaker relay will close for a short time for clos-ing of the circuit breaker. The open breaker relay will close for a short time for opening of the breaker.

External/ATS no controlThis type of signal is used to indicate the position of the breaker, but the breaker is not controlled by the AGC.



CompactThis type of signal will most often be used combined with a compact breaker, a direct controlled motor drivenbreaker. With the setting compact the AGC will use the close command and the open command relay. Theclose breaker relay will close for a short time for the compact breaker to close. The breaker off relay will closefor the compact breaker to open and hold it closed long enough for the motor in the breaker to recharge thebreaker. If the compact breaker is tripped externally, it is recharged automatically before next closing.

If compact breaker is selected, the length of breaker open signal can be adjusted. This can bedone in menu 2160/2200.

5.3 Breaker spring load time

To avoid breaker close failures in situations where breaker ON command is given before the breaker springhas been loaded, the spring load time can be adjusted for GB/TB and MB.

The following describes a situation where you risk getting a close failure:

1. The genset is in auto mode, the auto start/stop input is active, the genset is running and the GB is closed.2. The auto start/stop input is deactivated, the stop sequence is executed and the GB is opened.3. If the auto start/stop input is activated again before the stop sequence is finished, the GB will give a GB

close failure as the GB needs time to load the spring before it is ready to close.

Different breaker types are used, and therefore there are two available solutions:

1. Timer-controlledA load time setpoint for the GB/TB and MB control for breakers with no feedback indicating that the spring isloaded. After the breaker has been opened it will not be allowed to close again before the delay has expired.The setpoints are found in menus 6230, 7080 and 8190.

On the AGC mains unit (option G5), the spring load feedback from the tie breaker can be con-nected instead of the GB spring load feedback.

2. Digital inputTwo configurable inputs to be used for feedbacks from the breakers: One for GB/TB spring loaded and onefor MB spring loaded. After the breaker has been opened it will not be allowed to close again before the con-figured inputs are active. The inputs are configured in the ML-2 utility software. When the timers are counting,the remaining time is shown in the display.

If the two solutions are used together, both requirements are to be met before closing of the breaker is al-lowed.

Breaker LED indicationTo alert the user that the breaker close sequence has been initiated but is waiting for permission to give theclose command, the LED indication for the breaker will be flashing yellow in this case.

If the breaker needs time to reload the spring after it has opened, then the AGC can take this delay into ac-count. This can be controlled through timers in the AGC or through digital feedbacks from the breaker, de-pending on the breaker type.



5.3.1 PrincipleThe diagram shows an example where a single AGC in island mode is controlled by the AUTO start/stop in-put.

This is what happens: When the AUTO start/stop input deactivates, the GB opens. The AUTO start/stop isreactivated immediately after the GB has opened, e.g. by the operator through a switch in the switchboard.However, the AGC waits a while before it issues the close signal again, because the spring load time mustexpire (or the digital input must be activated - not shown in this example). Then the AGC issues the closesignal.

Spring load time

GB closed

GB open

Auto Start/stop ON

Auto Start/stop OFF

t [sec]



5.4 Alarm inhibit

In order to select when the alarms are to be active, a configurable inhibit setting for every alarm has beenmade. The inhibit functionality is only available via the PC utility software. For every alarm there is a drop-down window where it is possible to select which signals that have to be present in order to inhibit the alarm.



Selections for alarm inhibit:

Function Description

Inhibit 1 M-logic outputs: Conditions are programmed in M-logic

Inhibit 2

Inhibit 3

GB ON (TB ON) The generator breaker is closed

GB OFF (TB ON) The generator breaker is open

Run status Running detected and the timer in menu 6160 expired

Not run status Running not detected or the timer in menu 6160 not expired

Generator voltage > 30% Generator voltage is above 30% of nominal

Generator voltage < 30% Generator voltage is below 30% of nominal

MB ON The mains breaker is closed

MB OFF The mains breaker is open

Parallel Both GB and MB are closed

Not parallel Either GB or MB is closed, but not both

The timer in 6160 is not used if binary running feedback is used.

Inhibit of the alarm is active as long as one of the selected inhibit functions is active.

In this example, inhibit is set to Not run status and GB ON. Here, the alarm will be active when the generatorhas started. When the generator has been synchronised to the busbar, the alarm will be disabled again.

The inhibit LED on the unit and on the display will activate when one of the inhibit functions isactive.

Function inputs such as running feedback, remote start or access lock are never inhibited. On-ly alarm inputs can be inhibited.



The tie breaker unit has no running detection that can be configured, so the only inhibit func-tions are the binary input and the TB position.

5.4.1 Run status (6160)Alarms can be adjusted to activate only when the running feedback is active and a specific time delay hasexpired.

The diagram below illustrates that after activation of the running feedback, a run status delay will expire.When the delay expires, alarms with Run status will be activated.

t

tRUN

Run. feedback

Alarms active

The timer is ignored if binary running feedback is used.

5.5 Access lock

The purpose of access lock is to deny the operator the possibility to configure the unit parameters andchange the running modes.

The input to be used for the access lock function is defined in the ML-2 PC utility software (USW).

Access lock will typically be activated from a key switch installed behind the door of the switchboard cabinet.



Button Button status Comment

INFO Active It is possible to read all alarms, but it is not possible to acknowledge any ofthem.

JUMP Not active

START Not active

STOP Not active

GB ON Not active

MB ON Not active

VIEW Active

LOG Active

LEFT Active

UP Active

SELECT Not active If the access lock is activated when the view menu system is displayed, thenthe button is not active.

SELECT Active If the access lock is activated when the setup menu system is displayed, thenthe button is active.

DOWN Active

BACK Active

RIGHT Active

MODE Active If the access lock is activated when the view menu system is displayed, thebutton is not active.

MODE Active If the access lock is activated when the setup menu system is displayed, thenthe button is active.

After three minutes, the display returns to the view menu system. The setup menu system canonly be entered again if the access lock is deactivated.

The stop push-button is not active in semi-auto mode when the access lock is activated. Forsafety reasons it is recommended to install an emergency stop switch.



The following digital input functions are affected when access lock is activated:

Input name Input status Comment

Remote start Not active

Remote stop Not active

Semi-auto Not active

Test Not active

Auto Not active

Manual Not active

Block Not active

Remote GB ON Not active

Remote GB OFF Not active

Remote MB ON Not active

Remote MB OFF Not active

Remote TB ON Not active

Remote TB OFF Not active

AOP buttons are not locked when access lock is activated.

5.6 Overlap

The purpose of the overlap function is to be able to define a maximum paralleling time between the generatorand the mains supply.

The function is typically used if there are local requirements to maximum allowed paralleling time.

The overlap function is only available in the automatic mains failure and load takeover gensetmodes.

MB

GB

t

t

t

The diagram shows that when the generator breaker is synchronised, the mains breaker will be opened auto-matically after a time delay (t). Later the mains breaker is synchronised, and the generator breaker is openedafter the time delay (t).

The time delay is measured in seconds and can be adjusted from 0.10 to 99.90 seconds.



The same time delay is used for both generator and mains breaker synchronisation.

If the function is used in a Power Management (option G5) application, then the overlap will oc-cur between the mains breaker and the tie breaker on the AGC mains.

The time delay typed in the setpoint is a maximum time. This means that if 0.10 seconds areused, the two breakers will never be closed at the same time for a longer delay than the set-point.

The short time parallel function is set up in 2760 Overlap.

5.7 Digital mains breaker control

The unit will normally execute the automatic mains failure sequence based on the settings adjusted in thesystem setup. Besides these settings it is possible to configure a digital input that can be used to control themains return sequence. This input is the "mains OK" input. The purpose of this function is to let an externaldevice or an operator control the mains return sequence. The external device can e.g. be a PLC.

The flowchart below shows that if the input is configured, it needs to be activated (by a pulse) in order to ini-tiate the mains return sequence. The load will continue on generator supply if the input is not activated.

The mains OK delay is not used at all when the "Mains OK" input is configured.

Mains OK

Mains OK

delay

MB input

configured

Expired

MB control

input

ON

MB and GB

operation

Sequence

YesNo

No No

Yes Yes



5.8 Command timers

The purpose of the command timers is to be able to e.g. start and stop the genset automatically at specifictimes each weekday or certain weekdays. If auto mode is activated, this function is available in island opera-tion, load takeover, mains power export and fixed power operation. Up to four command timers can be usedfor e.g. start and stop. The command timers are available in M-logic and can be used for other purposes thanstarting and stopping the genset automatically. Each command timer can be set for the following time peri-ods:

Individual days (MO, TU, WE, TH, FR, SA, SU) MO, TU, WE, TH MO, TU, WE, TH, FR MO, TU, WE, TH, FR, SA, SU SA, SU

To start in AUTO mode, the "Auto start/stop" command can be programmed in M-logic or in theinput settings.

The time-dependent commands are flags that are raised when the command timer is in the ac-tive period.

5.9 Running output

6160 Run status can be adjusted to give a digital output when the genset is running.

Select the correct relay number in output A and output B and enable the function. Change the relay functionto limit in the I/O menu. Then the relay will activate, but no alarm will appear.



If the relay function is not changed to "limit" function, an alarm will appear at every runningsituation.

5.10 Frequency-dependent droop

This droop function can be used when the genset is parallel to the mains. In case the frequency drops orrises due to instability of the mains, the curve for frequency-dependent droop is made to compensate thepower setpoint.

Example:With a nominal frequency of 50 Hz and an actual frequency of 51.5 Hz, there is a deviation of 1.5 Hz which isequal to a 3% deviation from the nominal setting. The genset will then droop to 400 kW according to the be-low vector diagram.



(Fnom-fact)*100/fact [%]

MIN

MAX

P [KW]

DBH

DBL

HYSL

HYSH

SLPH

SLPL

0%1%2%3%4% 1% 2% 3% 4% 5%5%

Fixed Power Setpoint

6%7%8%9%10% 6% 7% 8% 9% 10%

The above vector diagram is configured with the parameter settings as in the following table.

The curve can be designed inside MIN/MAX [kW] area.

Menu Settings Name Description

7051 450 kW Fixed power setpoint

7121 2 DBL[%] Dead band low in percentages of nominal frequency.

7122 2 DBH[%] Dead band high in percentages of nominal frequency.

7123 1 HYSL[%] Hysterese low in percentages of nominal frequency. If HYSL is setabove DBL, the hysteresis low is disabled.

7124 1 HYSH[%] Hysterese high in percentages of nominal frequency. If HYSH is setabove DBH, the hysteresis high is disabled.

7131 150 MIN[kW] Minimum output of droop handling.

7132 900 MAX[kW] Maximum output of droop handling.

7133 50 SLPL[kW/%] Slope low. The setting determines the increase/decrease of power refer-ence per percentage the actual frequency drops below nominal frequen-cy.

7134 -50 SLPH[kW/%] Slope high. The setting determines the increase/decrease of power ref-erence per percentage the actual frequency rises above nominal fre-quency.

7143 ON Enable Enable droop curve function.

The frequency-dependent droop is only available in fixed power mode.



5.11 Power and cos phi offsets

5.11.1 Power offsetsCan be set in menu 7220-7225. The enabled power offsets will be added/subtracted from the fixed power set-point in menu 7051, which refers to Pnom.

The adjusted fixed power setpoint will be limited to be inside the values in menu 7023 "Mini-mum load", and maximum value is Pnom.

5.11.2 Cos phi offsetsCan be set in menu 7241-7245. The enabled cos phi offsets will be added/subtracted from the fixed cos phisetpoint in menu 7052.

The adjusted fixed cos phi setpoint will be limited to be inside the values in menu 7171 "Cosphi (x2)", and maximum value is in menu 7173 "Cos phi (x2)".

Power and cos phi offsets can be enabled via M-logic.

5.12 Derate genset

The purpose of the derate function is to be able to reduce the maximum output power of the genset if specificconditions require this. An example of such a condition is the ambient temperature. If the ambient tempera-ture increases to a level where the cooling water coolers decrease in cooling capacity, it will be necessary toreduce the power of the genset. If the genset is not derated, alarms and shutdown events will very likely oc-cur. Up to three derate curves can be made to derate the genset independent of each other. The first curveactive will derate the genset to the adjusted setpoint.

The derate function is typically used when cooling problems are expected.

5.12.1 Input selectionThe derate function can be configured to one of the following inputs:

Input Comment

Multi-input 102 0-40V DC4-20 mAPt100/1000VDODigital

Multi-input 105

Multi-input 108

EIC Water temp.Oil temp.

M-logic

Select the needed inputs in 6240-6250-6260 Power derate.



Refer to the type label for information about engine interface selection.

5.12.2 Derate parametersThe parameters that define the derate characteristics are the following:

Start derate point (6240/6250/6260 Power derate)

This is the setting where the derating must start. The setting can be in mA (max. 20 mA) or in centi-grades ºC (max. 200ºC).

Slope (6243/6253/6263 Power derate)

Adjust the derating speed. The adjustment is in percent per unit, i.e. if the 4-20 mA input is used, thenthe derating will be in %/mA, and if the Pt100/Pt1000/VDO input is used, then the derating will be in %/C.

Be aware that the 4-20 mA input can be configured with different minimum and maximum set-tings. In this case the settings "start derate point" and "slope" use these new settings.

Derate limit (6246/6256/6266 Power derate)

This is the lowest derate level.

PNOM

PLIMIT

P

Start

derate

16100 20

mA

5.12.3 Derate characteristicIt can be selected whether the characteristic of the derating should be proportional or inverse proportional.The drawing above shows the inverse characteristic.

The proportional characteristic is illustrated below.



PNOM

PLIMIT

P

Start

increase

16100 20

mA

The genset is derated when the control value is lower than the setpoint (in the example above the controlvalue is an mA signal).

The derate characteristic is selected in 6240/6250/6260 Power derate

Setting OFF: Inverse characteristicSetting ON: Proportional characteristic

5.13 Idle running

The purpose of the idle run function is to change the start and stop sequences to allow the genset to operateunder low temperature conditions.

It is possible to use the idle run function with or without timers. Two timers are available. One timer is used inthe start sequence, and one timer is used in the stop sequence.

The main purpose of the function is to prevent the genset from stopping. The timers are available to make thefunction flexible.

The speed governor must be prepared for the idle run function if this function is to be used.

The function is typically used in installations where the genset is exposed to low temperatures which couldgenerate starting problems or damage the genset.

5.13.1 DescriptionThe function is enabled and configured in 6290 Idle running. It has to be noted that the governor itself musthandle the idle speed based on a digital signal from the unit (see the principle diagram below).



When the function is enabled, two digital inputs are used for control purposes:

No. Input Description

1 Low speed input This input is used to change between idle speed and nominal speed. This inputdoes not prevent the genset from stopping - it is only a selection between idleand nominal speed.

2 Temperature con-trol input

When this input is activated, the genset will start. It will not be able to stop aslong as this input is activated.

If the idle run function is selected by means of timer, the low speed input is overruled.

The input must be configured through the PC software at commissioning.

One extra relay output must be available on the unit. Notice that this is option-dependent.

Turbo chargers not originally prepared for operating in the low speed area can be damaged ifthe genset is running in "idle run" for too long.

Low speed

input

Multi-line 2

Temperature

control input

relayIdle run input

GOVERNOR

Actuator

Start/stop

gen-set

High/low

speed

selection

5.13.2 ExamplesIdle speed during starting and stoppingIn this example both the start and the stop timers are activated.

The start and stop sequences are changed in order to let the genset stay at the idle level before speeding up.It also decreases the speed to the idle level for a specified delay time before stopping.



Start Stop

RPM

300

1500

t

tSTART tSTOP

Idle speed, no stoppingIn this example both timers are deactivated.

If the genset is to be prevented from stopping, then the digital input "temp control" must be left ON at alltimes. In that case the characteristic looks like this:

Start Stop

RPM

300

1500

t

The oil pressure alarm (VDO oil) will be enabled during idle run if set to "ON".

5.13.3 Configuration of digital inputThe digital input is configured via the PC software.



5.13.4 InhibitThe alarms that are deactivated by the inhibit function are inhibited in the usual manner, except for the oilpressure alarms; VDO oil 102, 105 and 108 which are active during "idle run" as well.

5.13.5 Running signalThe running feedback must be activated when the genset is running in idle mode.

5.13.6 Idle speed flowchartsThe flowcharts illustrate the starting and stopping of the genset by use of the inputs "temp control" and "lowspeed".



5.13.7 StartStart

Temp control ON

End

NoAuto

start/stop

ON

No

Yes

Idle timer on

Yes Lowspeed ON

No starting

Start the

Genset

Start the

Genset

Timer expired

Genset running

at f NomGenset running

at idle speed

No

Yes

No

Yes

Yes

No



5.13.8 StopStart

Temp control

OFF

End

NoAuto

start/stop

OFF

No

Yes

Idle timer on

YesLowspeed ON

Genset stop

sequence

Idle timer

expired

Genset running

at idle speed

No

Yes

No

Yes

Yes

Genset running

at idle speed

Genset stop

sequence

No

5.14 Engine heater

This function is used to control the temperature of the engine. A sensor measuring the cooling water tempera-ture is used to activate an external heating system to keep the engine at a minimum temperature.

The setpoints adjusted in menu 6320 are:

Setpoint: This setpoint +/- the hysteresis is the start and stop points for the engine heater.

Output A: The relay output for the engine heater.

Input type: Multi-input to be used for temperature measurement.

Hysteresis: This decides how big a deviation from the setpoint is needed to activate/deactivate the engineheater.

Enable: Enables the engine heater function.



Principle diagram:

43°C

37°C

Engine heater

relay

Start attempt

DG running

The engine heater function is only active when the engine is stopped.

5.14.1 Engine heater alarmIf the temperature keeps dropping after the start setpoint has been exceeded, an alarm will be raised if con-figured in menu 6330.

5.15 Master clock

The purpose of the master clock is to control the frequency of the genset in order to obtain the correct num-ber of periods.

This function can only be used if island operation is selected.

In a 50 Hz system one period lasts 20 ms. If this changes, e.g. due to the dead band setting of the frequencycontroller, a difference will exist between the actual number of periods and the theoretical number of periods.

Equipment that works based on the zero crossings will be affected by the surplus or missing zero crossings.The most common example of such equipment is alarm clocks.

The unit’s internal clock is a timekeeper which is included in the battery backed memory circuit. The time-keeper function works based on an oscillating crystal instead of zero crossings of the AC measurements. Dueto the accuracy of the timekeeper, it is recommended to synchronise the clock on a regular basis, e.g. onceevery month.



Setting Description Comment

6401 Start Start time. The compensation period starts atthe adjusted time.

6402 Stop Stop time. The compensation period stops atthe adjusted time.

6403 Difference The setpoint in seconds that initiates thecompensation.

6404 Compensation Frequency difference when the compensa-tion is initiated.

+/- value.

6405 Enable Enables the function.

The compensation frequency must be adjusted to a value higher than the dead band setting.

5.15.1 Compensation timeThe time for the compensation can easily be calculated at a given adjustment of 6403 and 6404 (example):

6403 = 30 seconds 6404 = +/- 0.1 Hz

5.16 Battery test

This function gives the possibility to test the condition of the battery. The battery test can be initiated with adigital input and is available when the genset is in semi-auto and auto mode.

If a mains failure occurs during the battery test sequence, the test will automatically be interrupted, and theautomatic mains failure start up sequence will be activated.

During the test, the battery voltage will decrease, and an alarm will occur if it drops to the setpoint.

tBAT TEST tBAT TEST

Cancel test

UBATTERY

t

Alarm

Test 2Test 1

The drawing shows that test #1 is carried out without a large voltage drop of the battery voltage, whereas test#2 reaches the alarm setpoint.



As there is no reason to wear the battery down even more, the test stops when the battery test alarm occurs.

The test is typically used at periodical intervals, e.g. once every week. The engine must be at a standstillwhen the test is started. Otherwise, the test command will be ignored.

The stop relay will act depending on the coil type:

Stop coil: The stop relay activates during the test.Run coil: The stop relay stays deactivated during the test.

The drawing below shows that when the test is started, the start relay activates making the engine turn.

Start relay

Run coil

Stop coil

or

Start test

5.16.1 Input configurationIf this function is to be used, it is necessary to configure a digital input that initiates the function. This is donein the dialogue box below.

If AUTO mode is selected, the mains failure sequence will be initiated if a mains failure occursduring the battery test.

5.16.2 Auto configurationIf the automatic battery test is used, the function has to be enabled in menu 6420. When the function is ena-bled, the battery test will be carried out with a specified interval, e.g. once a week. Completed battery testswill be logged in a separate battery test log.



The factory setting in menu 6424 is 52 weeks. This means that the automatic battery test will beexecuted once a year.

If application 3, 6 or 7 is used, it is expected that one of the multi-inputs is used for the batterytest of the starter battery.

It is expected that the multi-inputs used for the battery test are configured to "0-40V DC".

5.16.3 Battery asymmetry (6430 Batt. asymmetry)The reason for making the battery asymmetry test is to determine if one of the batteries is getting weak. Thebattery asymmetry is a combination of measurements and calculations.

Setpoints available:

T1: The input type to be used for calculation of battery asymmetry 1.RF1: Reference of asymmetry measurement no. 1.T2: The input type to be used for calculation of battery asymmetry 2.RF2: Reference of asymmetry measurement no. 2.

The following seven battery applications are supported. The shown applications are merely examples – thechoice of multi-input (MI) or power supply input is configurable in menu 6410.

Multi-line 2

Application 1:

Start/Manoeuvre

battery

AUX

- +

A E B

- +

MI 1

Multi-line 2

Application 2:

Start/Manoeuvre

battery

AUX

- +

A F B

- +

MI 1MI 2

- + - +

E



Multi-line 2

Application 3:

Start battery

AUX

- +

A B

- +

MI 1

E

MI 3

- + - +

C D

Manoeuvre battery

Multi-line 2

Application 4:

Manoeuvre battery

AUX

- +

A B

- +

MI 1

E

Multi-line 2

Application 5:

Manoeuvre battery

AUX

- +

A F B

- +

MI 1MI 2

- + - +

E

Multi-line 2

Application 6:

Start battery

AUX

- +

A B

- +

MI 1

E

MI 3

- +

C D

Manoeuvre battery

MI 2

F

- + - + - +

- +

- +

Multi-line 2

Application 7:

Start battery

AUX

- +

A B

- +

MI 1

E

MI 3

- + - +

C D

Manoeuvre battery

MI 2

F

- + - + - + - +



Looking at battery application 1 as an example:

Multi-line 2

Application 1:

Start/Manoeuvre

battery

AUX

- +

A E B

- +

MI 1

The power supply measurement is used as the reference RF1 (point A and B) in menu 6432 and multi-input 1is used as the type T1 (point A and E) in menu 6431. By making these measurements it is possible to calcu-late the voltage between E and B. This gives a full picture of battery voltages, e.g.:

Measured value A/B (RF1) = 21V DCMeasured value A/E (T1) = 12V DCCalculated value E/B (RF1 – T1) = 9V DC

Battery asymmetry = E/B – (RF1*1/2) = 9 – (21*1/2) = -1.5V DC

It is expected that the multi-inputs used for the battery asymmetry are configured to "0-40VDC".

The selection power supply is referring to the supply on terminals 1 and 2.

Battery asymmetry alarmAlarms for battery asymmetry 1 and 2 are set up in menus 6440 and 6450.

The setpoint in menus 6440 and 6450 is only set in positive values, however, it will also triggerif the battery asymmetry calculation results in a negative value.

5.17 Ventilation

This function can be used to control the cooling of the engine. The purpose is to use a multi-input for measur-ing the cooling water temperature and that way activate an external ventilation system to keep the engine be-low a maximum temperature. The functionality is shown in the below diagram.

Setpoints available (6460 Max ventilation):

Setpoint: The limit for activation of the relay set in OA.

Output A (OA): The relay activated when the setpoint is exceeded.

Hysteresis: The number of degrees the temperature has to be below the setpoint in order to deacti-vate the relay set in OA.

Enable: Enable/disable the ventilation function.



The type of input to use for the temperature measurement is selected in menu 6323 Engineheater.

95°C

85°C

Relay

5.17.1 Max. ventilation alarmTwo alarms can be set up in menu 6470 and menu 6480 to activate if the temperature keeps rising after thestart setpoint has been reached.

5.18 Summer/winter time

This function is used to make the AGC unit automatically adjust the clock in the unit according to summer andwinter time. The function is enabled in menu 6490.

The function only supports the Danish rules.

5.19 Switchboard error

The switchboard error function is handled in two different menus: 6500 "Block swbd error" and 6510 "StopSwbd error". The functions are activated by using one configurable input (switchboard error) which is config-ured with the PC utility software

The functionality of the “switchboard error” input is active as soon as the input is configured.The “enable” in menus 6500 and 6510 only refers to the alarm function.

5.19.1 Block swbd error (menu 6500)When activated, this function will block the start sequence of the genset in case the genset is not running.


Delay: When the input is active, the alarm will be activated when this delay has expired.

Parallel: OFF: Only AMF start sequence is blocked when the input is active.ON: All start sequences, regardless of running mode, are blocked when the input is active.

Output A: Relay to activate when the delay has expired.



Output B: Relay to activate when the delay has expired.

Enable: Enable/disable the alarm function.

Fail class: The fail class of the alarm.

5.19.2 Stop swbd error (menu 6510)When activated, this function will stop the genset if the genset is running in Auto mode.


Delay: When the input is active and the delay has expired, the genset will trip the breaker, cooldown and stop. The function is active regardless of the "Enable" setting.

Output A: Relay to activate when the delay has expired.

Output B: Relay to activate when the delay has expired.



5.20 Not in auto

This function can be used for indication or to raise an alarm in case the system is not in Auto. The function isset up in menu 6540.

5.21 Fuel pump logic

The fuel pump logic is used to start and stop the fuel supply pump to maintain the fuel level in the servicetank at predefined levels. The start and stop limits are detected from one of the three multi-inputs.

Setpoints available in menu 6550:

Setpoint 1: Start level.

Setpoint 2: Stop level.

Delay: If the fuel level has not increased by 2% within this delay, a Fuel fill alarm will be raised.

Output A (OA): The relay to be used for control of the fuel pump. The selected relay activates belowthe start limit and deactivates above the stop level.

Type: The multi-input to be used for the fuel level sensor.

Fail class: The fail class of the Fuel fill alarm.

The fuel pump relay can be activated via M-logic.



The output relay should be configured as a limit relay, otherwise, an alarm will be raised when-ever the output is activated.

The below drawing shows how the fuel pump is activated when the level reaches 20% and stopped againwhen the level has reached 80%.

Fuel pump start level

Fuel level

80 %

20 %

Time

Fuel service tank level

Fuel pump stop level

5.21.1 Fuel fill checkThe fuel pump logic includes a Fuel fill check function.

When the fuel pump is running, the fuel level must increase by 2% within the fuel fill check timer set in menu6553. If the fuel level does not increase by 2% within the adjusted delay time, then the fuel pump relay deacti-vates and a Fuel fill alarm occurs.

tFill check

∆ level, 2%

∆ level, 2%

The level of increase is fixed at 2% and cannot be changed.



5.22 Fail class

All activated alarms must be configured with a fail class. The fail classes define the category of the alarmsand the subsequent alarm action.

Eight different fail classes can be used. The tables below illustrate the action of each fail class when the en-gine is running or stopped.

5.22.1 Engine running

Fail class Action Alarmhorn re-

lay

Alarmdisplay

Deload Trip ofgen.

breaker

Trip ofmains

breaker

Cooling-down

genset

Stopgenset

1 Block X X

2 Warning X X

3 Trip GB X X X

4 Trip + stop X X X X X

5 Shutdown X X X X

6 Trip MB X X X

7 Safety stop X X (X) X X X

8 Trip MB/GB X X (X) X

The table illustrates the action of the fail classes. If, for instance, an alarm has been configured with the "shut-down" fail class, the following actions occur.

The alarm horn relay will activate The alarm will be displayed in the alarm info screen The generator breaker will open instantly The genset is stopped instantly The genset cannot be started from the unit (see next table)

The fail class "Safety stop" will only deload the genset before opening the breaker if option G4or G5 (power management) is used. If power management is not active, the "Safety stop" willhave the same function as "Trip and stop".

The fail class "Trip MB/GB" will only trip the generator breaker if there is no mains breakerpresent.



5.22.2 Engine stopped

Fail class Action Block engine start Block MB sequence Block GB sequence

1 Block X

2 Warning

3 Trip GB X X

4 Trip + stop X X

5 Shutdown X X

6 Trip MB X

7 Safety stop X

8 Trip MB/GB (X) X (X)

In addition to the actions defined by the fail classes, it is possible to activate one or two relayoutputs if additional relays are available in the unit.

The fail class "Trip MB/GB" will only block engine start and GB sequence if there is no mainsbreaker present.

5.22.3 Fail class configurationThe fail class can be selected for each alarm function either via the display or the PC software.

To change the fail class via the PC software, the alarm function to be configured must be selected. Select thedesired fail class in the fail class roll-down panel.



5.23 Trip of non-essential load (NEL)

The two terms "trip of non-essential load" and "load shedding" describe the same functionali-ty.

The trip of Non Essential Load (NEL) groups (load shedding) is carried out in order to protect the busbaragainst an imminent blackout situation due to either a high load/current or overload on a generator set or alow busbar frequency.

The unit is able to trip three NEL groups due to:

the measured load of the generator set (high load and overload) the measured current of the generator set the measured frequency at the busbar

The load groups are tripped as three individual load groups. This means that the trip of load group no. 1 hasno direct influence on the trip of load group no. 2. Only the measurement of either the busbar frequency orthe load/current on the generator set is able to trip the load groups.

Trip of the NEL groups due to the load of a running generator set will reduce the load on the busbar and thusreduce the load percentage on the running generator set. This may prevent a possible blackout at the busbarcaused by an overload on the running generator set. The current trip will be selected in case of inductiveloads and unstable power factor (PF <0.7) where the current is increased.

Trip of the NEL groups due to a low busbar frequency will reduce the real power load at the busbar and thusreduce the load percentage on the generator set. This may prevent a possible blackout at the busbar.

For output setup, please refer to the description of outputs.

5.24 Service timers

The unit is able to monitor the maintenance intervals. Two service timers are available to cover different inter-vals. The service timers are set up in menus 6110 and 6120.

The function is based on running hours. When the adjusted time expires, the unit will display an alarm. Therunning hours is counting when the running feedback is present.

Setpoints available in menus 6110 and 6120:


Running hours: The number of running hours to activate the alarm. The service timer alarm will be acti-vated as soon as the running hours have been reached.

Day: The number of days to activate the alarm – if the running hours are not reached beforethis number of days, the alarm will still be activated. The service timer alarm will be ac-tivated at 8:00 AM on the day the alarm expires.




Output A: Relay to be activated when the alarm is activated.

Reset: Enabling this will reset the service timer to zero. This must be done when the alarm isactivated.

5.25 Wire fail detection

If it is necessary to supervise the sensors/wires connected to the multi-inputs and analogue inputs, then it ispossible to enable the wire break function for each input. If the measured value on the input is outside thenormal dynamic area of the input, it will be detected as if the wire has made a short circuit or a break. Analarm with a configurable fail class will be activated.

Input Wire failure area Normal range Wire failure area

4-20 mA < 3mA 4-20 mA > 21 mA

0-40V DC ≤ 0V DC - N/A

VDO Oil, type 1 < 1.0 ohm - > 195.0 ohm

VDO Oil, type 2 < 1.0 ohm - > 195.0 ohm

VDO Temp, type 1 < 4.0 ohm - > 488.0 ohm



VDO Fuel, type 1 < 0.6 ohm - > 97.0 ohm

VDO Fuel, type 2 < 1.0 ohm - > 195.0 ohm

VDO configurable < lowest resistance - > highest resistance

P100 < 82.3 ohm - > 194.1 ohm

P1000 < 823 ohm - > 1941 ohm

Level switch Only active if the switch is open

PrincipleThe illustration below shows that when the wire of the input breaks, the measured value will drop to zero.Then the alarm will occur.

Wire failure

Wire failure

Wire break

Lower failure

limit

Upper failure

limit

Input signal

(mA, °C,b, %)

t



MPU wire break (menu 4550)The MPU wire break function is only active when the genset is not running. In this case an alarm will beraised if the wire connection between the AGC and MPU breaks.

Stop coil wire break (menu 6270)The alarm will occur when the stop coil is not activated (generator is running) and the input is deenergised.



5.26 Digital inputs

The unit has a number of binary inputs some of which are configurable and some are not.

Engine interface card Available digital inputs – not configura-ble

Available digital inputs– configu-rable

M4 (standard) 1 6

Input function Auto Semi Test Man Block Configurable Input type

1 Shutdown override X X X X X Configurable Constant

2 Access lock X X X X X Configurable Constant

3 Running feedback X X X X X Configurable Constant

4 Remote start X X Configurable Pulse

5 Remote stop X X Configurable Pulse

6 Semi-auto X X X X Configurable Pulse

7 Test X X X X Configurable Pulse

8 Auto X X X X Configurable Pulse

9 Manual X X X Configurable Pulse

10 Block X X X X Configurable Constant

11 Remote GB ON X Configurable Pulse

12 Remote GB OFF X Configurable Pulse

13 Remote MB ON X Configurable Pulse

14 Remote MB OFF X Configurable Pulse

15 Remote alarm acknowledge X X X X X Configurable Constant

16 Auto start/stop X Configurable Constant

17 Remove starter X X X X Configurable Constant

18 Reset analogue GOV/AVR out-puts

X X X X X Configurable Pulse

19 Manual GOV up X X X X Configurable Constant

20 Manual GOV down X X X X Configurable Constant

21 Manual AVR up X X X X Configurable Constant

22 Manual AVR down X X X X Configurable Constant

23 GB position ON X X X X X Not configurable Constant

24 GB position OFF X X X X X Not configurable Constant

25 MB position ON X X X X X Not configurable Constant

26 MB position OFF X X X X X Not configurable Constant

27 Emergency stop X X X X X Not configurable Constant

28 Low speed X X X Configurable Constant

29 Temperature control X X X Configurable Constant

30 Battery test X X Configurable Pulse



Input function Auto Semi Test Man Block Configurable Input type

31 Mains OK X X X X X Configurable Pulse

32 External f control X X X Configurable Constant

33 External P control X X X Configurable Constant

34 External PF control X X X Configurable Constant

35 External U control X X X Configurable Constant

36 External Q power X X X Configurable Constant

37 MB close inhibit X X X X X Configurable Constant

38 Enable mode shift X X X X X Configurable Constant

39 Enable GB black close X X X X X Configurable Constant

40 Enable sep. sync. X X X X X Configurable Constant

41 Start enable X X X X Configurable Constant

42 Alternative start X X X X X Configurable Constant

43 Switchboard error X X X X X Configurable Constant

44 Total test X X X X X Configurable Constant

45 GB spring loaded X X X X X Configurable Constant

46 MB spring loaded X X X X X Configurable Constant

47 1st priority mains X X X X X Configurable Constant

48 Ext. MB pos. OFF X X X X X Configurable Constant

49 Heavy consumer 1 request X X X X X Configurable Constant

50 Heavy consumer 2 request X X X X X Configurable Constant

51 Deload X Configurable Constant

52 GB OFF and BLOCK X Configurable Pulse

53 HC 1 fixed load feedback X X X X X Configurable Constant

54 HC 2 fixed load feedback X X X X X Configurable Constant

55 Secured ON X X X X X Configurable Pulse

56 Secured OFF X X X X X Configurable Pulse

57 Base load X Configurable Constant

5.26.1 Functional description1. Shutdown overrideThis input deactivates all protections except the overspeed protection and the emergency stop input. Thenumber of start attempts is seven by default, but it can be configured in 6180 Start. Also a special cool downtimer is used in the stop sequence after an activation of this input.

2. Access lockActivating the access lock input deactivates the control display push-buttons. It will only be possible to viewmeasurements, alarms and the log.

3. Running feedbackThe input is used as a running indication of the engine. When the input is activated, the start relay is deactiva-ted.



4. Remote startThis input initiates the start sequence of the genset when semi-auto or manual mode is selected.

5. Remote stopThis input initiates the stop sequence of the genset when semi-auto or manual mode is selected. The gensetwill stop without cooling down.

6. Semi-autoChanges the present running mode to semi-auto.

7. TestChanges the present running mode to test.

8. AutoChanges the present running mode to auto.

9. ManualChanges the present running mode to manual.

10. BlockChanges the present running mode to block.

When block mode is selected, the running mode cannot be changed by activating the digitalinputs.

11. Remote GB ONThe generator breaker ON sequence will be initiated and the breaker will synchronise if the mains breaker isclosed, or close without synchronising if the mains breaker is opened.

12. Remote GB OFFThe generator breaker OFF sequence will be initiated. If the mains breaker is opened, then the generatorbreaker will open instantly. If the mains breaker is closed, the generator load will be deloaded to the breakeropen limit followed by a breaker opening.

13. Remote MB ONThe mains breaker ON sequence will be initiated and the breaker will synchronise if the generator breaker isclosed, or close without synchronising if the generator breaker is opened.

14. Remote MB OFFThe mains breaker OFF sequence will be initiated, and the breaker will open instantly.

15. Remote alarm acknowledgeAcknowledges all present alarms, and the alarm LED on the display stops flashing.

16. Auto start/stopThe genset will start when this input is activated. The genset will be stopped if the input is deactivated. Theinput can be used when the unit is in island operation, fixed power, load takeover or mains power export andthe AUTO running mode is selected.

17. Remove starterThe start sequence is deactivated. This means the start relay deactivates, and the starter motor will disen-gage.



18. Reset analogue GOV/AVR outputsThe analogue +/-20 mA controller outputs will be reset to 0 mA.

All analogue controller outputs are reset. That is the governor output and the AVR output if op-tion D1 is selected.

If an offset has been adjusted in the control setup, then the reset position will be the specificadjustment.

19. Manual GOV upIf manual mode is selected, then the governor output will be increased.

20. Manual GOV downIf manual mode is selected, then the governor output will be decreased.

21. Manual AVR upIf manual mode is selected, then the AVR output will be increased.

22. Manual AVR downIf manual mode is selected, then the AVR output will be decreased.

The manual governor and AVR increase and decrease inputs can only be used in manualmode.

23. Generator breaker closed feedback (GB position ON)The input function is used as an indication of the generator breaker position. The unit requires this feedbackwhen the breaker is closed or a position failure alarm occurs.

24. Generator breaker open feedback (GB position OFF)The input function is used as an indication of the generator breaker position. The unit requires this feedbackwhen the breaker is opened or a position failure alarm occurs.

25. Mains breaker closed feedback (MB position ON)The input function is used as an indication of the mains breaker position. The unit requires this feedbackwhen the breaker is closed or a position failure alarm occurs.

26. Mains breaker open feedback (MB position OFF)The input function is used as an indication of the mains breaker position. The unit requires this feedbackwhen the breaker is opened or a position failure alarm occurs.

27. Emergency stopThe input shuts down the engine immediately. At the same time it opens the generator breaker.

The shutdown fail class must be selected.

28. Low speedDisables the regulators and keeps the genset running at a low RPM.

The governor must be prepared for this function.



29. Temperature controlThis input is part of the idle mode function. When the input is high, then the genset starts. It starts at high orlow speed, depending on the activation of the low speed input. When the input is deactivated, then the gensetgoes to idle mode (low speed = ON), or it stops (low speed = OFF).

30. Battery testActivates the starter without starting the genset. If the battery is weak, the test will cause the battery voltageto drop more than acceptable, and an alarm will occur.

31. Mains OKDisables the "mains OK delay" timer. The synchronisation of the mains breaker will happen when the input isactivated.

32. External frequency controlThe nominal frequency setpoint will be controlled from the analogue inputs terminal 40/41. The internal set-point will not be used.

33. External power controlThe power setpoint in fixed power will be controlled from the analogue inputs terminal 40/41. The internal set-point will not be used.

34. External power factor controlThe power factor setpoint will be controlled from the analogue inputs terminal 41/42. The internal setpoint willnot be used.

35. External voltage controlThe nominal voltage setpoint will be controlled from the analogue inputs terminal 41/42. The internal setpointwill not be used.

36. External reactive powerThe reactive power setpoint will be controlled from the analogue inputs terminal 41/42. The internal setpointwill not be used.

37. MB close inhibitWhen this input is activated, then the mains breaker cannot close.

38. Enable mode shiftThe input activates the mode shift function, and the AGC will perform the AMF sequence in case of a mainsfailure. When the input is configured, the setting in menu 7081 (mode shift ON/OFF) is disregarded.

39. Enable GB black closeWhen the input is activated, the AGC is allowed to close the generator on a black busbar, providing that thefrequency and voltage are inside the limits set up in menu 2110.

40. Enable separate sync.Activating this input will split the breaker close and breaker synchronisation functions into two different relays.The breaker close function will remain on the relays dedicated for breaker control. The synchronisation func-tion will be moved to a configurable relay dependent on the options configuration.

This function is option-dependent. Option M12 or M14.x is required.



41. Start enableThe input must be activated to be able to start the engine.

When the genset is started, the input can be removed.

42. Alternative startThis input is used to simulate an AMF failure and this way run a full AMF sequence without a mains failureactually being present.

43. Switchboard errorThe input will stop or block the genset depending on running status.

44. Total testThis input will be logged in the event log to indicate that a planned mains failure has been made.

45. GB spring loadedThe AGC will not send a close signal before this feedback is present.

46. MB spring loadedThe AGC will not send a close signal before this feedback is present.

47. 1st priority mainsThis input is used in G5 applications with two mains connections to select which mains connection has 1st

priority.

48. Ext. MB pos. OFFThis input is used in G5 applications with two mains connections to tell the AGC mains units that the mainsbreaker not controlled by them has been tripped.

49. Heavy consumer 1 requestThis input is used in G5 applications with two generators or more to request heavy consumer 1 to start.

50. Heavy consumer 2 requestThis input is used in G5 applications with two generators or more to request heavy consumer 2 to start.

51. DeloadA running genset will start to ramp down the power.

52. GB OFF and BLOCKThe generator breaker will open, the genset will activate the stop sequence and when the genset is stopped,it will be blocked for start.

53. HC 1 fixed load feedbackHC 1 is running and consuming 100% power.

54. HC 2 fixed load feedbackHC 2 is running and consuming 100% power.

55. Secured mode ONSecured mode adds an extra generator to the system, i.e. one generator too many will be running when com-paring with the actual power requirement.



56. Secured mode OFFEnds secured running mode (see 55).

57. Base loadThe generator set will run base load (fixed power) and not participate in frequency control. Should the plantpower requirement drop, the base load will be lowered so the other generator(s) on line produces at least10% power.

The input functions are set up with the PC utility software, please refer to "Help" in this.

5.27 Outputs

The unit has a number of output functions which can be configured to any available relay.

Output function Auto Semi Test Man Block Configurable Output type

1 HC 1 ack. X Configurable Pulse

2 HC 2 ack. X Configurable Pulse

3 Trip NEL 1 X X X X X Configurable Pulse



5.27.1 Functional description1. HC 1 ack.This output is used in G5 applications with two or more generators to acknowledge the heavy consumer re-quested.

2. HC 2 ack.This output is used in G5 applications with two or more generators to acknowledge the heavy consumer re-quested.

Please refer to the option G4/G5/G8 manual for reference.

3. Trip NEL 1This output is used to trip load groups.



Please refer to the description of NEL.

5.28 Multi-inputs

The AGC unit has three multi-inputs which can be configured to be used as the following input types:



1. 4-20 mA2. 0-40V DC3. Pt1004. Pt10005. VDO oil6. VDO water7. VDO fuel8. Digital

The function of the multi-inputs can only be configured in the PC utility software.

For each input two alarm levels are available, the menu numbers of the alarm settings for each multi-input iscontrolled by the configured input type as seen in the following table.

Input type Multi-input 102 Multi-input 105 Multi-input 108

4-20 mA 4120/4130 4250/4260 4380/4390

0-40V DC 4140/4150 4270/4280 4400/4410

Pt100/Pt1000 4160/4170 4290/4300 4420/4430

VDO oil 4180/4190 4310/4320 4440/4450

VDO water 4200/4210 4330/4340 4460/4470

VDO fuel 4220/4230 4350/4360 4480/4490

Digital 3400 3410 3420

Only one alarm level is available for the digital input type.

5.28.1 4-20 mAIf one of the multi-inputs has been configured as 4-20 mA, the unit and range of the measured value corre-sponding to 4-20 mA can be changed in the PC utility software in order to get the correct reading in the dis-play.

5.28.2 0-40V DCThe 0-40V DC input has primarily been designed to handle the battery asymmetry test.

5.28.3 Pt100/1000This input type can be used for heat sensor, e.g. cooling water temp. The unit of the measured value can bechanged from Celsius to Fahrenheit in the PC utility software in order to get the desired reading in the dis-play.

5.28.4 VDO inputsThe unit can contain up to three VDO inputs. The inputs have different functions, as the hardware design al-lows for several VDO types.

These various types of VDO inputs are available for all multi-inputs:



VDO oil: Oil pressureVDO water: Cooling water temperatureVDO fuel: Fuel level sensor

For each type of VDO input it is possible to select between different characteristics including a configurable.

5.28.5 VDO oilThis VDO input is used for measuring the lubricating oil pressure.

VDO sensor type

Pressure Type 1 Type 2 Type 3

Bar psi Ω Ω Ω

0 0 10.0 10.0

0.5 7 27.2

1.0 15 44.9 31.3

1.5 22 62.9

2.0 29 81.0 51.5

2.5 36 99.2

3.0 44 117.1 71.0

3.5 51 134.7

4.0 58 151.9 89.6

4.5 65 168.3

5.0 73 184.0 107.3

6.0 87 124.3

7.0 102 140.4

8.0 116 155.7

9.0 131 170.2

10.0 145 184.0

The configurable type is configurable with eight points in the range 0-480 Ω. The resistance aswell as the pressure can be adjusted.

If the VDO input is used as a level switch, then be aware that no voltage must be connected tothe input. If any voltage is applied to the VDO inputs, it will be damaged. Please refer to theApplication Notes for further wiring information.

5.28.6 VDO waterThis VDO input is used for measuring the cooling water temperature.



VDO sensortype

Temperature Type 1 Type 2 Type 3 Type 4

°C °F Ω Ω Ω Ω

40 104 291.5 480.7 69.3

50 122 197.3 323.6

60 140 134.0 222.5 36.0

70 158 97.1 157.1

80 176 70.1 113.2 19.8

90 194 51.2 83.2

100 212 38.5 62.4 11.7

110 230 29.1 47.6

120 248 22.4 36.8 7.4

130 266 28.9

140 284 22.8

150 302 18.2

The configurable type is configurable with eight points in the range 0-480 Ω. The temperatureas well as the resistance can be adjusted.


5.28.7 VDO fuelThis VDO input is used for the fuel level sensor.

VDO sensor type

Type 1

Value Resistance

0% 78.8 Ω

100% 1.6 Ω

VDO sensor type

Type 2

Value Resistance

0% 3 Ω

100% 180 Ω




VDO sensor type

Value Type configurable

% Resistance

0

10

20

30

40

50

60

70

80

90

100

The configurable type is configurable with eight points in the range 0-480 Ω. The value as wellas the resistance can be adjusted.

5.28.8 Illustration of configurable inputs

Setpoints

Setpoint 1Setpoint 2

Setpoint 3

Setpoint 4

Setpoint 5

Setpoint 6

Setpoint 7

8 7 6 54 3 2 1

Value

(bar, °C or %)

Resistance

(Ω)

Setpoint 8



5.28.9 ConfigurationThe eight curve settings for the configurable VDO inputs cannot be changed in the display, but only in the PCutility software. The alarm settings can be changed both in the display and in the PC utility software. In thePC utility software the configurable inputs are adjusted in this dialogue box:

Adjust the resistance of the VDO sensor at the specific measuring value. In the example above the adjust-ment is 10 Ω at 0.0 bar.

5.28.10 DigitalIf the multi-inputs are configured to "Digital", they become available as a configurable input.

5.29 Manual governor and AVR control

This function can be activated by pressing more than two seconds, or by activating the digital inputs orAOP buttons for governor or AVR control in semi-auto mode. The intention of this function is to give the com-missioning engineer a helpful tool for adjustment of the regulation.

The function of the regulation window depends on the selected mode:

G 0 0 0V

P-Q Reg. 50% 60%GOV AVR

P-Q Setp 100% 100%

5.29.1 Manual modeIn manual mode the regulation is deactivated. When activating the up or down arrows, the output value toGOV or AVR is changed, this is the Reg. value in the display. The up and down arrows have the same func-tion as the digital inputs or AOP buttons for governor and AVR control when the window is open. To exit theregulation window press "back".

5.29.2 Semi-auto modeAs in manual mode, the up and down arrows have the same function as the digital inputs or AOP buttons forgovernor or AVR control when the window is open.



The value Setp can be changed by pressing the arrow up or down. When GOV is underlined, the governorsetpoint will be changed, and vice versa when the AVR is underlined. When changing the Setp value, an off-set will be added to or subtracted from the nominal value. The Reg. value is the output value from the regula-tor. If the genset is running in parallel, the active or reactive nominal power setpoint value will be changed. If itis a stand-alone genset not parallel to the mains, the nominal frequency or voltage setpoint will be changedand also displayed. When the "back" button is activated, the regulation setpoint returns to nominal.

If the digital inputs or AOP buttons are activated in semi-auto, the regulation window is auto-matically opened.

5.29.3 Auto and test modeLike semi-auto, except from the fact that activating the digital inputs or AOP buttons for governor or AVR con-trol will change the regulation setpoint but not open the regulation window. When the digital inputs or AOPbuttons are deactivated, the regulation setpoint returns to nominal.

AVR setpoint manipulation requires option D1.

Regarding AOP setup, please refer to "Help" in the PC utility software.

5.30 Input function selection

Digital input alarms can be configured with a possibility to select when the alarms are to be activated. Thepossible selections of the input function are normally open or normally closed.

The drawing below illustrates a digital input used as an alarm input.

1. Digital input alarm configured to NC, normally closedThis will initiate an alarm when the signal on the digital input disappears.

2. Digital input alarm configured to NO, normally openThis will initiate an alarm when the signal on the digital input appears.

The relay output function can be selected to be ND (Normally Deenergised), NE (Normally Ener-gised), Limit or Horn.



Dig in

Multi-line 2

Com

+ V DC

Alarm

input

Relayout

5.31 Language selection

The unit has the possibility to display different languages. It is delivered with one master language which isEnglish. This is the default language, and it cannot be changed. In addition to the master language 11 differ-ent languages can be configured. This is done via the PC utility software.

The languages are selected in the system setup menu 6080. The language can be changed when connectedto the PC utility software. It is not possible to make language configuration from the display, but the alreadyconfigured languages can be selected.

5.32 Texts in status line

The status texts must be self-explanatory. If the operator does something wrong, then the status line mustindicate it. The table below indicates the texts in the status line.



5.32.1 Standard texts

Status text Condition Comment

BLOCK Block mode is activated

SIMPLE TEST Test mode is activated

LOAD TEST

FULL TEST

SIMPLE TEST ###.#min Test mode activated and test timer counting down

LOAD TEST ###.#min

FULL TEST ###.#min

ISLAND MAN Genset stopped or running and no other action takingplaceISLAND SEMI

READY ISLAND AUTO Genset stopped in Auto

ISLAND ACTIVE Genset running in Auto

AMF MAN Genset stopped or running and no other action takingplaceAMF SEMI

READY AMF AUTO Genset stopped in Auto

AMF ACTIVE Genset running in Auto

FIXED POWER MAN Genset stopped or running and no other action takingplaceFIXED POWER SEMI

READY FIXED P AUTO Genset stopped in Auto

FIXED POWER ACTIVE Genset running in Auto

PEAK SHAVING MAN Genset stopped or running and no other action takingplacePEAK SHAVING SEMI

READY PEAK SHAV AUTO Genset stopped in Auto

PEAK SHAVING ACTIVE Genset running in Auto

LOAD TAKEOVER MAN Genset stopped or running and no other action takingplaceLOAD TAKEOVER SEMI

READY LTO AUTO Genset stopped in Auto

LTO ACTIVE Genset running in Auto

MAINS P EXPORT MAN Genset stopped or running and no other action takingplaceMAINS P EXPORT SEMI

READY MPE AUTO Genset stopped in Auto

MPE ACTIVE Genset running in Mains power export mode

DG BLOCKED FOR START Generator stopped and active alarm(s) on the genera-tor

GB ON BLOCKED Generator running, GB open and an active "Trip GB"alarm

SHUTDOWN OVERRIDE The configurable input is active




ACCESS LOCK The configurable input is activated, and the operatortries to activate one of the blocked keys

GB TRIP EXTERNALLY Some external equipment has tripped the breaker An external trip islogged in theevent log

MB TRIP EXTERNALLY Some external equipment has tripped the breaker An external trip islogged in theevent log

IDLE RUN The "Idle run" function is active. The genset will notstop until a timer has expired

IDLE RUN ###.#min The timer in the "Idle run"’ function is active

COMPENSATION FREQ. Compensation is active The frequency isnot at the nomi-nal setting

Aux. test ##.#V ####s Battery test activated

DELOAD Decreasing the load of the genset in order to open thebreaker

START DG(s) IN ###s The start genset setpoint is exceeded

STOP DG(s) IN ###s The stop genset setpoint is exceeded

START PREPARE The start prepare relay is activated

START RELAY ON The start relay is activated

START RELAY OFF The start relay is deactivated during the start sequence

MAINS FAILURE Mains failure and mains failure timer expired

MAINS FAILURE IN ###s Frequency or voltage measurement is outside the limits The timer shownis the Mains fail-ure delay.Text inmains units

MIANS U OK DEL ####s Mains voltage is OK after a mains failure The timer shownis the Mains OKdelay

MAINS f OK DEL ####s Mains frequency is OK after a mains failure The timer shownis the Mains OKdelay

Hz/V OK IN ###s The voltage and frequency on the genset is OK When the timerruns out it is al-lowed to operatethe generatorbreaker

COOLING DOWN ###s Cooling down period is activated

COOLING DOWN Cooling down period is activated and infinite Cooling downtimer is set to 0.0s




GENSET STOPPING This info is shown when cooling down has finished

EXT. STOP TIME ###s

PROGRAMMING LAN-GUAGE

This info is shown if the language file is downloadedfrom the PC utility software

TOO SLOW 00<------------- Generator running too slow during synchronising

-----------> 00 TOO FAST Generator running too fast during synchronising

EXT. START ORDER A planned AMF sequence is activated There is no fail-ure on the mainsduring this se-quence

QUICK SETUP ERROR Quick setup of the application failed

MOUNT CAN CONNECTOR Connect the power management CAN line

ADAPT IN PROGRESS The AGC is receiving the application that it has justbeen connected to

SETUP IN PROGRESS The new AGC is being added to the existing application

SETUP COMPLETED Successful update of the application in all AGC units

REMOVE CAN CONNEC-TOR

Remove the power management CAN lines

RAMP TO #####kW The power ramp is ramping in steps, and the next stepthat will be reached after the timer has expired will bedisplayed

DERATED TO #####kW Displays the ramp down setpoint

PREPARING ETHERNET Preparing Ethernet connection

PROGRAMMING MLOGIC Downloading M-logic to the unit



5.32.2 Texts only related to power management (option G5)


DG unit

BLACKOUT ENABLE This info is shown if a CAN failure is present in a pow-er management application.

UNIT STANDBY If redundant mains units are present, this message isshown on the redundant unit.

DELOADING BTB XX DG units are load sharing asymmetrically to deloadBTB XX dividing two sections in an island application.

BTB XX DIVIDING SEC. BTB XX is dividing two sections in an island applica-tion.

SYNCHRONISING TB XX TB XX is synchronising.

SYNCHRONISING MB XX MB XX is synchronising.

SYNCHRONISING BTB XX BTB XX is synchronising.

Mains unit

UNIT STANDBY If redundant mains units are present this message isshown on the redundant unit.

TB TRIP EXTERNALLY Some external equipment has tripped the breaker. An external trip islogged in the eventlog.

BTB unit

DIVIDING SECTION A BTB unit is dividing two sections in an island appli-cation.

READY AUTO OPERATION BTB unit in Auto and ready for breaker operation (noactive BTB trip" alarm).

SEMI OPERATION BTB unit in Semi.

AUTO OPERATION BTB unit in Auto, but not ready for breaker operation(active "BTB trip" alarm).

BLOCKED FOR CLOSING Last open BTB in a ring bus.

BTB TRIP EXTERNALLY Some external equipment has tripped the breaker. An external trip islogged in the eventlog.

All units

BROADCASTING APPL. # Broadcast an application through the CAN line. Broadcasts one ofthe four applica-tions from one unitto the rest of theAGCs in the powermanagement sys-tem.

RECEIVING APPL. # AGC receiving an application.




BROADCAST COMPLE-TED

Successful broadcast of an application.

RECEIVE COMPLETED Application received successfully.

BROADCAST ABORTED Broadcast terminated.

RECEIVE ERROR Application is not received correctly.

5.33 Service menu

The purpose of the service menu is to give information about the present operating condition of the genset.The service menu is entered using the "JUMP" push-button (9120 Service menu).

Use the service menu for easy troubleshooting in connection with the event log.

Entry windowThe entry shows the possible selections in the service menu.

Available selections:

AlarmShows the alarm timer and the remaining time. The indicated remaining time is minimum remaining time. Thetimer will count downwards when the setpoint has been exceeded.

IN (digital input)Shows the status of the digital inputs.

OUT (digital output)Shows the status of the digital outputs.

MISC (miscellaneous)Shows miscellaneous messages.



5.34 Event log

The logging of data is divided in three different groups:

Event log containing 150 loggings. Alarm log containing 30 loggings. Battery test log containing 52 loggings.

The logs can be viewed in the display or in the PC utility software. When the individual logs are full, each newevent will overwrite the oldest event following the "first in - first out" principle.

5.34.1 DisplayIn the display it looks like this when the "LOG" push-button is pressed:

Now it is possible to select one of the three logs.

If the "Event" is selected, the log could look like this:

The specific alarm or event is shown in the second line. In the example above the fuel level alarm has occur-red. The third line shows the time stamp.

If the cursor is moved to "INFO", the actual value can be read when pressing "SEL":

The first event in the list will be displayed if the cursor is placed below "FIRST" and "SEL" is pressed.

The last event in the list will be displayed if the cursor is placed below "LAST" and "SEL" is pressed.

The keyUP and keyDOWN push-buttons are used for navigating in the list.

5.35 Counters

Counters for various values are included, and some of these can be adjusted if necessary, for instance if theunit is installed on an existing genset or a new circuit breaker has been installed.

The table shows the adjustable values and their function in menu 6100:



Description Function Comment

6101 Running time Offset adjustment of the total running hourscounter.

Counting when the running feedbackis present.

6102 Running time Offset adjustment of the total running thou-sand hours counter.

Counting when the running feedbackis present.

6103 GB opera-tions

Offset adjustment of the number of genera-tor breaker operations.

Counting at each GB close command.

6104 MB opera-tions

Offset adjustment of the number of mainsbreaker operations.

Counting at each MB close command.

6105 kWh reset Resets the kWh counter. Automatically resets to OFF after thereset. The reset function cannot be leftactive.

6106 Start at-tempts

Offset adjustment of the number of start at-tempts.

Counting at each start attempt.

Additional counters for "Running hours" and "Energy" can be read out from the PC utility soft-ware.

5.36 Pulse input counters

Two configurable digital inputs can be used for counter input. The two counters can be used for e.g. fuel con-sumption or heat flow. The two digital inputs can ONLY be configured for pulse inputs via M-logic, as shownin the example below.

Scaling of pulse input can be set in menu 6851/6861. It is possible to determine the scale value to be pulse/unit or unit/pulse.

Counter values can be read out in display, and the number of decimals can be adjusted in menu 6853/6863.

5.37 kWh/kVArh counters

The AGC has two transistor outputs, each representing a value for the power production. The outputs arepulse outputs, and the pulse length for each of the activations is 1 second.

Term. number Output

20 kWh

21 kVArh

22 Common terminal



The number of pulses depends on the actual adjusted setting of the nominal power:

Generator power Value Number of pulses (kWh) Number of pulses (kVArh)

PNOM <100 kW 1 pulse/kWh 1 pulse/kVArh

PNOM 100-1000 kW 1 pulse/10 kWh 1 pulse/10 kVArh

PNOM >1000 kW 1 pulse/100 kWh 1 pulse/100 kVArh

The kWh measurement is shown in the display as well, but the kVArh measurement is onlyavailable through the transistor output.

Be careful - the maximum burden for the transistor outputs is 10 mA.

5.38 Quick setup

Both the PC utility software and the quick setup menu can be used to set up a plant.

The quick setup menu is made to provide easy setup of a plant. Entering the quick setup menu 9180 via theDU-2 display gives the possibility to add or remove e.g. mains and MB without using the utility software. It isonly possible to do the same basic setup as via the application configuration in the utility software.

Menu 9180 Quick setup

9181: Mode.

OFF: When the mode menu is set to "OFF", the existing application of the genset will not bechanged.

Setup plant: The setup plant mode is used in G5 applications.

Please refer to the option G5 manual.

Setup stand-alone:

When the mode menu is set to "Setup stand-alone", the AGC will change the applicationconfiguration. The settings in menu 9182-9185 are used for the new configuration.



If "Setup stand-alone" is activated while the genset is running, an info text, "Quick setup er-ror", will appear.

5.39 Parameter ID

This parameter can be used to identify which parameter file is used in the unit.

5.40 M-Logic

M-ogic functionality is included in the unit and is not an option-dependent function, however selecting addi-tional options, such as option M12 which offers additional digital inputs and outputs, can increase the func-tionality.

M-Logic is used to execute different commands at predefined conditions. M-Logic is not a PLC but substitutesone, if only very simple commands are needed.



M-Logic is a simple tool based on logic events. One or more input conditions are defined, and at the activa-tion of those inputs the defined output will occur. A great variety of inputs can be selected, such as digitalinputs, alarm conditions and running conditions. A variety of the outputs can also be selected, such as relayoutputs, change of genset modes and change of running modes.

The M-Logic is part of the PC utility software, and as such it can only be configured in the PCutility software and not via the display.

The main purpose of M-Logic is to give the operator/designer more flexible possibilities of operating the gen-erator control system.

Please refer to the "Help" function in the PC utility software for a full description of this config-uration tool.

5.41 GSM communication

The GSM modem communication is used to send a GSM message to up to five cellular telephones when analarm appears on the display.

System single-line diagram

Controller

GSM

Modem

External

antenna

DEIF recommends using a MOXA OnCell G2150I, Wavecom WMOD2 or Westermo GDW-11 ter-minal, as the application has been tested with these terminals.

Serial connectionThe serial connection to the GSM modem is done via the null-modem cable (option J3).

Basic parameter settings

Setting no. Name Function Set to

GSM GSM PIN code Set PIN code for GSM modem None

GSM 12345678901 Set phone no. for SMS to cellular phone 1 None





For calling a foreign number type "+" and country code instead of "00", for example dial +4599999999 for a Danish number.



The phone number can only be dialed using the PC utility software.

The SIM card used in the cellular telephone must support data transfer.

PIN code configurationAfter each auxiliary supply power up, the unit will send the required PIN code to the modem if this is necessa-ry. The PIN code is adjusted in the PC utility software.

5.42 USW communication

It is possible to communicate with the unit via the PC utility software. The purpose is to be able to remotemonitor and control the genset application.

It is possible to remote control the genset from the PC utility software if a modem is used. Takeprecautions that it is safe to remote operate the genset to avoid personal injury or death.

Serial connectionThe serial connection to the GSM modem is via the null-modem cable (option J3).

Because of the RS232 communication the GSM function is only available with option H9.2.

SetupThe Modbus protocol type can be changed from RTU to ASCII (9020 Service port). This menu can only bereached using the JUMP push-button. When set to 1, the ASCII protocol type is used, and the unit will allowfor the slower modem communication.

9020 Service port

No. Setting Min. setting Max. setting Factory setting

9021 Service port Setpoint 0 (normal USW) 1 (modem USW) 0 (normal USW)

If setting 9020 is set to 1, the PC utility software cannot communicate with the unit when it isconnected directly to the PC and a modem is not used.

Application settingsPlease refer to the PC utility software help file.

SafetyIf communication fails, the unit will operate according to the received data. If e.g. only half of the parameterfile has been downloaded when the communication is interrupted, the unit will use this actual data.

5.43 Nominal settings

The nominal settings can be changed to match different voltages and frequencies. The AGC has four sets ofnominal values for the generator, and they are adjusted in menus 6000 to 6030 (Nominal settings 1 to 4).There are also two sets of nominal settings for the busbar, they can be adjusted in menus 6050 to 6060.



If no busbar voltage transformer is present, the primary and secondary side values are set togenerator nominal value.

The possibility to switch between the four sets of nominal setpoints is typically used on rentalgensets, where switching between 50 and 60 Hz is required.

ActivationThe switching between the nominal setpoints can be done in three ways; digital input, AOP or menu 6006.

Digital inputM-logic is used when a digital input is needed for switching between the four sets of nominal settings. Selectthe required input among the input events, and select the nominal settings in the outputs.

Example:

Event A Event B Event C Output

Dig. input no. 115 or Not used or Not used Set nom. parameter settings 1

Not Dig. input no. 115 or Not used or Not used Set nom. parameter settings 2

See the "Help" file in the PC utility software for details.

AOPM-logic is used when the AOP is used for switching between the four sets of nominal settings. Select the re-quired AOP push-button among the input events, and select the nominal settings in the outputs.

Example:

Event A Event B Event C Output

Button07 or Not used or Not used Set nom. parameter settings 1

Button08 or Not used or Not used Set nom. parameter settings 2

See the "Help" file in the PC utility software for details.

Menu settingsIn menu 6006 the switching is made between settings 1 to 4 simply by choosing the desired nominal setting.

Four nominal settings of GOV/AVR offsetsIn menu 6006 the selection of nominal setting is made. The nominal setting of GOV/AVR offset will follow thesetting in 6006, meaning: nominal setting 1 (6001…6005) will follow GOV/AVR offset in 2550.



5.44 Step-up transformer

The AGC can be used in applications where the generator is followed by a step-up transformer. I.e. themeasurement of the generator voltage is on a different level than the measurement of the busbar voltage.The functions available in this application are:

1. Synchronising with or without phase compensation2. Voltage measurements displayed3. Generator protections (option-dependent)4. Busbar protections (option-dependent)

The maximum nominal voltage supported is 160 kV AC.

5.44.1 ApplicationsDifferent applications are supported by the AGC when a step-up transformer is placed after a generator.Measurement transformers can be installed on the generator side and the busbar side, or direct inputs be-tween 100V AC and 690V AC can be connected.

A typical setup includes a low-voltage generator, e.g. 400V AC, and a step-up transformer, e.g. 400/10000VAC. In this case, 400V AC would be connected to the generator inputs and 100 or 110V AC from the meas-urement transformer would be connected to the busbar inputs.

Measurement transformerThe AGC can be adjusted with different measurement transformer ratios. This is adjusted in the system setup(menus 6040/6050/6060). The advantage is i.e. that synchronising of a circuit breaker can be performed,even though the voltage measurement points are not placed on the same busbar.

Different measurement inputsIn the AGC, it is possible to have different measurement inputs on the generator measurements and the bus-bar measurements. Schematically, it looks e.g. like the diagram below where the generator inputs are 440volt and the busbar inputs are 100 volt.

Controller

G

Busbar 10 kV

Step up transformer

10/0.4 kV

Measurement

transfomer ratio:

10/0.1 kV

440 V AC

direct input

UNOMINAL = 440 V AC



The current measurement point must be placed on the generator side of the step-up transform-er.

Single-line exampleThe simple diagram below shows a step-up transformer with +/- 30 deg. phase shift. This of course dependsof the type of transformer. To be able to synchronise the generator circuit breaker, the AGC must compen-sate for the 30 deg. offset.

Controller

G

Busbar 13.8 kV

Step up transformer

13.8/3.3 kV

Measurement

transfomer ratio:

13.8/0.1 kV

UNOMINAL = 3.3 kV

±30 deg phase shift

Measurement

transfomer ratio:

3.3/0.1 kV

Measurement

transfomer ratio:

3.3/0.1 kV

When it is used for synchronising, the AGC uses the ratio of the nominal voltages of the generator and thebusbar when calculating the AVR setpoint and the voltage synchronising window (dUMAX).

Example:A 10000/400V AC step-up transformer is installed after a generator with the nominal voltage of 400V AC. Thenominal voltage of the busbar is 10000V AC. Now, the voltage of the busbar is 10500V AC. The generator isrunning 400V AC before the synchronising starts, but when attempting to synchronise, the AVR setpoint willbe changed to UBUS-MEASURED * UGEN-NOM/UBUS-NOM :10500*400/10000 = 420V AC.

The AGC has a phase angle compensation range inside +/- 179° (setting 9140).

5.45 Demand of peak currents

5.45.1 I thermal demandThis read-out is used to simulate a bimetallic system which is specifically suited for indication of thermal loadsin conjunction with cables, transformers, etc. The measuring principle is using sliding windows.



Example of sliding window based on FIFO register.

The measured peak currents are sampled once every second, and every 6 seconds an average peak value iscalculated. If the peak value is higher than the present MD, it will be saved in the register. The thermal period(Time C.) can be set from 0 to 20 minutes in menu 6841. The thermal demand period will provide an expo-nential thermal characteristic.

The display value can be reset in menu 6842. If the value is reset, it will be logged in the event log.

5.45.2 I max. demandRead-out is showing the Imax. peak value. When a new max. peak current is detected, the value is saved inthe display. The value can be reset in menu 6843. If the value is reset, it will be logged in the event log.

The two reset functions will also be available as commands through M-logic.

Display readout is updated with an interval of 6 seconds.

5.46 Fan logic

The AGC is able to control four different fans. This could e.g. be air supply fans for supplying air to a gensetin a closed enclosure, or radiator fans for switching on and off cooling fans for air coolers.

There are two features in the fan control of the AGC.

1. Priority rearranging depending on running hours of the fans2. Temperature-dependent start and stop



A priority routine ensures that the running hours of the available fans are evened out and the priority shiftsbetween them.

The functionality behind the temperature-dependent start/stop is that the AGC measures a temperature, e.g.cooling water temperature, and based on this temperature it switches on and off relays that must be used forengaging the fan(s) itself.

5.46.1 Fan parametersEach fan has a group of parameters that defines their scheme of operation. It is recommended to use the PCutility SW for the setup, because then it is possible to see all parameters. The setup of the fan control is donein the menus 6561-6620 and by using M-logic in the PC utility SW.

Parameters:

M-logic:

5.46.2 Input for fan controlThe fan control requires a temperature input in order to start and stop the fans based on a temperature meas-urement.

Fan temperature input is set up in parameter 6561, and this input can be selected between the multi-configu-rable inputs: Multi-input 102, 105, 108 or a value from the EIC (engine interface communication).



The multi-inputs can be configured to e.g. a Pt100 sensor that measures an engine- or ambient temperature.If EIC is selected, this is defined as the highest measured temperature of either cooling water or oil tempera-tures.

Based on the measurement of the selected input, the fan(s) is (are) started and stopped.

5.46.3 Fan start/stopThe start and stop settings of the fan(s) are set up in parameters 6563 to 6574. With the settings in the tablebelow, the illustrative curve can be observed.

A hysteresis (abbreviation: hyst.) ensures that there is a range between the start and stop.

The following start/stop curve will be generated if a bow setting is used:

5.46.4 Fan outputAt parameter 6581 to 6584, the output relays for fans A to D are selected. The purpose of these relays is toissue a signal to the fan starter cabinet. The relay must be energised for the fan to run.



5.46.5 Fan start delayIf two or more fans are requested to be started at the same time, it is possible to add a start delay betweeneach fan start. The reason for this is to limit the peak start current, so all fans will not contribute with a startcurrent at the same time. This delay is adjusted in the menu 6586.

5.46.6 Fan failureIt is possible to activate an alarm if the fan does not start. The fan failure alarm appears if the running feed-back from the fan does not appear. In parameters 6590 to 6620 the fan failure alarms are set up for fans A toD.



5.46.7 Fan priority (running hours)The priority of the fans A to D rotates automatically from 1st to 4th priority. This is done automatically, be-cause the running hours of the fans are detected and are used for the rearranging.

M-logic setup:If the fan unit is raising a signal that is led to a digital input on the AGC when it is running, then the followingM-logic must be programmed:

When it is not possible to get a running feedback from the fan unit, the internal relay of the AGC must beused to indicate that the fan is running. If e.g. R57 is the relay for FAN A, the following M-logic must be pro-grammed:

The running hour can be reset by entering parameter 6585 and then selecting the desired fan hours to bereset.

Only reset is possible. It is not possible to add an offset to the run hour counter.



5.46.8 Fan priority updateIn parameter 6562 the priority update rate (hours between priority rearrange) is selected:

If the fan priority update is set to 0 hours, the order of priority will be fixed at: Fan A, fan B, fan C and fan D.

5.47 Oil renewal function

The purpose of the oil renewal function is to give the possibility to exchange a small portion of the lubricatingoil of the engine with fresh or new oil. This means that the quality of the oil is kept at a satisfactory level with-out significant degrading of the oil (e.g. contamination and TBN value) in the entire period between the oilchanges.

The time interval between the oil changes is assumed to be 1000 hours of operation. The renewal functionwill read the engine hours from the engine interface communication (EIC). The running hours counter in theAGC is only used if the EIC counter is not available.

The function in the AGC is to activate a relay under defined conditions. Then the relay must be used for theoil renewal system (not part of the DEIF scope of supply) where lubricating oil is removed and added to theengine. Any freely configurable relay is available for this feature. When the running time information is be-tween 0 and 750 hours, the relay is activated in the AGC. Above 750 hours and up to 999 hours the relay isdeactivated.



5.48 Differential measurement

Up to three differential measurements between two sensors can be configured in menus 4600-4606. Thesensors can be selected from the input list below:

Two levels of alarms can be made of each differential measurement between sensor A and B.



Analogue settings for differential measurements.



6. Protections6.1 General

The protections are all of the definite time type, i.e. a setpoint and time is selected.

If the function is e.g. overvoltage, the timer will be activated if the setpoint is exceeded. If the voltage valuefalls below the setpoint value before the timer runs out, then the timer will be stopped and reset.

Set point

TimeTimer

start

Timer

reset

Timer

startAlarm

Timer setting

Measured

value

When the timer runs out, the output is activated. The total delay will be the delay setting + the reaction time.

Phase-neutral voltage tripIf the voltage alarms are to work based on phase-neutral measurements, please adjust menus 1200 and1340 accordingly. Depending on the selections, either phase-phase voltages or phase-neutral voltages will beused for the alarm monitoring.

Phase-neutral Phase-phase

UL3-L1 UL1-N UL1-L2

UL2-L3

UL2-NUL3-N

UL3-L1 UL1-N UL1-L2

UL2-L3

UL2-NUL3-N

As indicated in the vector diagram, there is a difference in voltage values at an error situation for the phase-neutral voltage and the phase-phase voltage.

The table shows the actual measurements at a 10% undervoltage situation in a 400/230 volt system.

Phase-neutral Phase-phase

Nominal voltage 400/230 400/230

Voltage, 10% error 380/207 360/185

The alarm will occur at two different voltage levels, even though the alarm setpoint is 10% in both cases.

AGC-4 manual, November 2011, UK Protections


ExampleThe below 400V AC system shows that the phase-neutral voltage must change 20%, when the phase-phasevoltage changes 40 volts (10%).

Example:UNOM = 400/230V AC

Error situation:UL1L2 = 360V ACUL3L1 = 360V AC

UL1-N = 185V AC

ΔUPH-N = 20%

UL3-L1

UL1-N

UL1-L2

UL2-L3

UL2-NUL3-N

20%

Phase-neutral or phase-phase: both the generator protections and the busbar/mains protec-tions use the selected voltage.

6.2 Voltage-dependent (restraint) overcurrent

This protection is used when the generator must be tripped due to a fault situation that creates a reducedgenerator voltage, e.g. a voltage collapse. During the voltage collapse, the generator can only produce part ofits usual rating. A short-circuit current during a voltage collapse can even be lower than the nominal currentrating.

The protection will be activated based on the overcurrent setpoint as a function of the measured voltage onthe generator voltage terminals.

The result can be expressed as a curve function where the voltage setpoints are fixed values and the currentsetpoints can be adjusted (menu 1100). This means that if the voltage drops, the overcurrent setpoint will al-so drop.



100

110

120

130

140

150

160

170

180

190

200

50 60 70 80 90 100

% Nominal Voltage

% N

om

ina

l C

urr

en

t

The voltage values for the six points on the curve are fixed; the current values can be adjustedin the range 50-200%.

Voltage and current % values refer to the nominal settings.

Timer value can be adjusted in the range 0.1- 60.0 sec.



7. PID controller7.1 Description of PID controller

The unit controller is a PID controller. It consists of a proportional regulator, an integral regulator and a differ-ential regulator. The PID controller is able to eliminate the regulation deviation and can easily be tuned in.

See "General Guidelines for Commissioning".

7.2 Controllers

There are three controllers for the governor control and, if option D1 is selected, also three controllers for theAVR control.

Controller GOV AVR Comment

Frequency X Controls the frequency

Power X Controls the power

P load sharing X Controls the active power load sharing

Voltage (option D1) X Controls the voltage

VAr (option D1) X Controls the power factor

Q load sharing (option D1) X X Controls the reactive power load sharing

The table below indicates when each of the controllers is active. This means that the controllers can be tunedin when the shown running situations are present.

Governor AVR (option-dependent) Schematic

Frequency Power P LS Voltage VAr Q LS

X XG

GB MB

X XG

GB MB

X XG

GB MB

X XG

G

GB

GB

AGC-4 manual, November 2011, UK PID controller


Load sharing mode is option-dependent (option G3/G5).

7.3 Principle drawing

The drawing below shows the basic principle of the PID controller.

P-part

(Kp)

I-part

(Ti)

D-part

(Td)

OutputSet point Σ Σ

-

++

+

As illustrated in the above drawing and equation, each regulator (P, I and D) gives an output which is sum-marised to the total controller output.

The adjustable settings for the PID controllers in the AGC unit are:

Kp: The gain for the proportional part.Ti: The integral action time for the integral part.Td: The differential action time for the differential part.

The function of each part is described in the following.

7.4 Proportional regulator

When the regulation deviation occurs, the proportional part will cause an immediate change of the output.The size of the change depends on the gain Kp.

The diagram shows how the output of the P regulator depends on the Kp setting. The change of the output ata given Kp setting will be doubled if the regulation deviation doubles.

P regulator

0

20

40

60

80

100

0 10 20 30 40 50 60

Kp

Ou

tpu

t (%

)

4 % 2 %

1 %

0,5 %



7.4.1 Speed rangeBecause of the characteristic above it is recommended to use the full range of the output to avoid an unstableregulation. If the output range used is too small, a small regulation deviation will cause a rather big outputchange. This is shown in the drawing below.

1% regulation

deviation

5 20

mA

kP

10 2515

kP

A 1% regulation deviation occurs. With the Kp setting adjusted, the deviation causes the output to change 5mA. The table shows that the output of the AGC changes relatively much if the maximum speed range is low.

Max. speed range Output change Output change in % of max. speed range

10 mA 5 mA 5/10*100% 50

20 mA 5 mA 5/20*100% 25

7.4.2 Dynamic regulation areaThe drawing below shows the dynamic regulation area at given values of Kp. The dynamic area gets smallerif the Kp is adjusted to a higher value.

Dynamic regulation band

-100

-75

-50

-25

0

25

50

75

100

44 45 46 47 48 49 50 51 52 53 54 55 56

Output [%]

Frequency

[Hz]

Kp=10

Kp=1

Kp=50



7.4.3 Integral regulatorThe main function of the integral regulator is to eliminate offset. The integral action time Ti is defined as thetime the integral regulator uses to replicate the momentary change of the output caused by the proportionalregulator.

In the drawing below the proportional regulator causes an immediate change of 2.5 mA. The integral actiontime is then measured when the output reaches 2 x 2.5 mA = 5 mA.

Integral action time, Ti

0

1

2

3

4

5

6

0 5 10 15 20 25 30 35

sec

mA

Ti = 10 s Ti = 20 s

As shown in the drawing, the output reaches 5 mA twice as fast at a Ti setting of 10 s than with a setting of 20s.

The integrating function of the I-regulator is increased if the integral action time is decreased. This means thata lower setting of the integral action time Ti results in a faster regulation.

If the Ti is adjusted to 0 s, the I-regulator is switched OFF.

The integral action time, Ti, must not be too low. This will make the regulation hunt similar to atoo high proportional action factor, Kp.

7.4.4 Differential regulatorThe main purpose of the differential regulator (D-regulator) is to stabilise the regulation, thus making it possi-ble to set a higher gain and a lower integral action time Ti. This will make the overall regulation eliminate devi-ations much faster.

In most cases, the differential regulator is not needed; however, in case of very precise regulation situations,e.g. static synchronisation, it can be very useful.

The output from the D-regulator can be explained with the equation:



D = Regulator outputKp = Gainde/dt = Slope of the deviation (how fast does the deviation occur)

This means that the D-regulator output depends on the slope of the deviation, the Kp and the Td setting.

Example:In the following example it is assumed that Kp = 1.

D-regulator

0

1

2

3

4

5

6

7

8

0 0,5 1 1,5 2 2,5

Time [s]

Ou

tpu

t/d

ev

iati

on

Deviation 2

D-output 2, Td=1s

Deviation 1

D-output 2, Td=0.5 s

D-output 1, Td=0.5 s

Deviation 1: A deviation with a slope of 1.Deviation 2: A deviation with a slope of 2.5 (2.5 times bigger than deviation 1).D-output 1, Td=0.5 s: Output from the D-regulator when Td=0.5 s and the deviation is according to De-

viation 1.D-output 2, Td=0.5 s: Output from the D-regulator when Td=0.5 s and the deviation is according to De-

viation 2.D-output 2, Td=1 s: Output from the D-regulator when Td=1 s and the deviation is according to Devi-

ation 2.

The example shows that the bigger deviation and the higher Td setting, the bigger output from the D-regula-tor. Since the D-regulator is responding to the slope of the deviation, it also means that when there is nochange the D-output will be zero.

When commissioning, please keep in mind that the Kp setting has influence on the D-regulatoroutput.

If the Td is adjusted to 0 s, the D-regulator is switched OFF.

The differential action time, Td, must not be too high. This will make the regulation hunt similarto a too high proportional action factor, Kp.



7.5 Load share controller

The load share controller is used in the AGC whenever load sharing mode is activated. The load share con-troller is a PID controller similar to the other controllers in the system and it takes care of frequency control aswell as power control.

Adjustment of the load share controller is done in menu 2540 (analogue control) or 2590 (relay control).

The primary purpose of the PID controller is always frequency control because frequency is variable in a loadsharing system as well as the power on the individual generator. Since the load sharing system requires pow-er regulation as well, the PID controller can be affected by the power regulator. For this purpose a so-calledweight factor is used (PWEIGHT).

The regulation deviation from the power regulator can therefore have great or less influence on the PID con-troller. An adjustment of 0% means that the power control is switched off. An adjustment of 100% means thatthe power regulation is not limited by the weight factor. Any adjustment in between is possible.

The difference between adjusting the weight value to a high or low value is the speed at which the powerregulation deviation is eliminated. So if a firm load sharing is needed, the weight factor must be adjusted to ahigher value than if an easy load sharing is required.

An expected disadvantage of a high weight factor is that when a frequency deviation and a power deviationexist, then hunting could be experienced. The solution to this is to decrease either the weight factor or theparameters of the frequency regulator.

7.6 Synchronising controller

The synchronising controller is used in the AGC whenever synchronising is activated. After a successful syn-chronisation the frequency controller is deactivated and the relevant controller is activated. This could e.g. bethe load sharing controller. The adjustments are made in the menu 2050.

Dynamic synchronisingWhen dynamic synchronising is used, the controller "2050 fSYNC controller" is used during the entire synchro-nising sequence. One of the advantages of dynamic synchronising is that it is relatively fast. In order to im-prove the speed of the synchronising further, the generator will be sped up between the points of synchroni-sation (12 o’clock to 12 o’clock) of the two systems. Normally a slip frequency of 0.1 Hz gives synchronismeach 10 seconds, but with this system on a steady engine the time between synchronism is reduced.

Static synchronisingWhen synchronising is started, the synchronising controller "2050 fSYNC controller" is activated and the gen-erator frequency is controlled towards the busbar/mains frequency. The phase controller takes over when thefrequency deviation is so small that the phase angle can be controlled. The phase controller is adjusted in themenu 2070 ("2070 phase controller").

7.7 Relay control

When the relay outputs are used for control purposes, the regulation works like this:



55Hz45Hz 50Hz

Regulator

output

Fix up signal Up pulse No reg. Fix down signalDown pulse

Hz

The regulation with relays can be split up into five steps.

# Range Description Comment

1 Static range Fix up sig-nal

The regulation is active, but the increase relay will be constantly activa-ted because of the size of the regulation deviation.

2 Dynamicrange

Up pulse The regulation is active, and the increase relay will be pulsing in order toeliminate the regulation deviation.

3 Dead bandarea

No reg. In this particular range no regulation takes place. The regulation acceptsa predefined dead band area in order to increase the lifetime of the re-lays.

4 Dynamicrange

Down pulse The regulation is active, and the decrease relay will be pulsing in orderto eliminate the regulation deviation.

5 Static range Fix downsignal

The regulation is active, but the decrease relay will be constantly activa-ted because of the size of the regulation deviation.

As the drawing indicates, the relays will be fixed ON if the regulation deviation is big, and they will be pulsingif it is closer to the setpoint. In the dynamic range the pulses get shorter and shorter when the regulation devi-ation gets smaller. Just before the dead band area the pulse is as short as it can get. This is the adjusted time"GOV ON time"/("AVR ON time"). The longest pulse will appear at the end of the dynamic range (45 Hz in theexample above).



7.7.1 Relay adjustmentsThe time settings for the regulation relays can be adjusted in the control setup. It is possible to adjust the"period" time and the "ON time". They are shown in the drawing below.

Adjustment Description Comment

Period time Maximum relay time The time between the beginnings of two subsequent relay pulses.

ON time Minimum relay time The minimum length of the relay pulse. The relays will never be acti-vated for a shorter time than the ON time.

As it is indicated in the drawing below, the length of the relay pulse will depend on the actual regulation devia-tion. If the deviation is big, then the pulses will be long (or a continued signal). If the deviation is small, thenthe pulses will be short.

PERIOD PERIOD PERIOD PERIOD PERIOD

t [sec]

Relay ON

HIGH <DEVIATION> LOW

ONONONONON

7.7.2 Signal lengthThe signal length is calculated compared to the adjusted period time. In the drawing below the effect of theproportional regulator is indicated.



P regulator

0

20

40

60

80

100

0 10 20 30 40 50 60

Kp

Ou

tpu

t (%

)

4 % 2 %

1 %

0,5 %

In this example we have a 2 percent regulation deviation and an adjusted value of the Kp = 20. The calcula-ted regulator value of the unit is 40%. Now the pulse length can be calculated with a period time = 2500 ms:

The length of the period time will never be shorter than the adjusted ON time.



8. Synchronisation8.1 Synchronisation principles

The unit can be used for synchronisation of generator and mains breaker (if installed). Two different synchro-nisation principles are available, namely static and dynamic synchronisation (dynamic is selected by default).This chapter describes the principles of the synchronisation functions and the adjustment of them.

In the following, the term "synchronisation" means "synchronising and closing of thesynchronised breaker".

8.2 Dynamic synchronisation

In dynamic synchronisation the synchronising genset is running at a different speed than the generator on thebusbar. This speed difference is called slip frequency. Typically, the synchronising genset is running with apositive slip frequency. This means that it is running with a higher speed than the generator on the busbar.The objective is to avoid a reverse power trip after the synchronisation.

The dynamic principle is illustrated below.

Synchronised

Synchronisation principle – dynamic synchronisation

Speed:

1503 RPM

50.1 Hertz

Speed:

1500 RPM

50.00 Hertz

LOAD

G

GB

G

GB

L1

L2L3

L1

L2L3

L1

L2L3

L1

L2L3

Generator on loadSynchronising generator

L1

L2L3

L1

L2

L3

L1

L2 L3

L1

L2

L3

2.5 s 7.5 s5.0 s0 s

∆t [s]

180°

90°

0°

Angle

L1gen/L1bus

[deg]

In the example above, the synchronising genset is running at 1503 RPM ~ 50.1 Hz. The generator on load isrunning at 1500 RPM ~ 50.0 Hz. This gives the synchronising genset a positive slip frequency of 0.1 Hz.

The intention of the synchronising is to decrease the phase angle difference between the two rotating sys-tems. These two systems are the three-phase system of the generator and the three-phase system of thebusbar. In the illustration above, phase L1 of the busbar is always pointing at 12 o’clock, whereas phase L1 ofthe synchronising genset is pointing in different directions due to the slip frequency.

AGC-4 manual, November 2011, UK Synchronisation


Of course both three-phase systems are rotating, but for illustrative purposes the vectors forthe generator on load are not shown to be rotating. This is because we are only interested inthe slip frequency for calculating when to release the synchronisation pulse.

When the generator is running with a positive slip frequency of 0.1 Hz compared to the busbar, then the twosystems will be synchronised every 10 seconds.

Please observe the chapter regarding PID controllers and the synchronising controllers.

In the illustration above, the difference in the phase angle between the synchronising set and the busbar getssmaller and will eventually be zero. Then the genset is synchronised to the busbar, and the breaker will beclosed.

8.2.1 Close signalThe unit always calculates when to close the breaker to get the most accurate synchronisation. This meansthat the close breaker signal is actually issued before being synchronised (read L1 phases exactly at 12o’clock).

The breaker close signal will be issued depending on the breaker closing time and the slip frequency (re-sponse time of the circuit breaker is 250 ms, and the slip frequency is 0.1 Hz):

The synchronisation pulse is always issued, so the closing of the breaker will occur at the 12o’clock position.

The length of the synchronisation pulse is the response time + 20 ms (2020 Synchronisation).

8.2.2 Load picture after synchronisingWhen the incoming genset has closed its breaker, it will take a portion of the load depending on the actualposition of the fuel rack. Illustration 1 below indicates that at a given positive slip frequency, the incominggenset will export power to the load. Illustration 2 below shows that at a given negative slip frequency, theincoming genset will receive power from the original genset. This phenomenon is called reverse power.

To avoid nuisance trips caused by reverse power, the synchronising settings can be set upwith a positive slip frequency.



LOAD

0% 100%

FUEL INDEX

0% 100%

FUEL INDEX

G1

G2

PGen1

PGen2

GB

GB

Illustration 1, POSITIVE slip frequency______________________________________________________________________________________

LOAD

0% 100%

FUEL INDEX

0% 100%

FUEL INDEX

G1

G2

PGen1

PGen2

Reverse power

GB

GB

Illustration 2, NEGATIVE slip frequency

8.2.3 AdjustmentsThe dynamic synchroniser is selected in 2000 Sync. type in the control setup and is adjusted in 2020 Syn-chronisation.


2021 fMAX Maximum slip frequency Adjust the maximum positive slip frequency where synchro-nising is allowed.

2022 fMIN Minimum slip frequency Adjust the maximum negative slip frequency where syn-chronising is allowed.

2023 UMAX Maximum voltage differrence(+/- value)

The maximum allowed voltage difference between the bus-bar/mains and the generator.

2024 tGB Generator breaker closing time Adjust the response time of the generator breaker.

2025 tMB Mains breaker closing time Adjust the response time of the mains breaker.

It is obvious that this type of synchronisation is able to synchronise relatively fast because of the adjustedminimum and maximum slip frequencies. This actually means that when the unit is aiming to control the fre-quency towards its setpoint, then synchronising can still occur as long as the frequency is within the limits ofthe slip frequency adjustments.

Dynamic synchronisation is recommended where fast synchronisation is required, and wherethe incoming gensets are able to take load just after the breaker has been closed.



Static and dynamic synchronisation can be switched by using M-logic.

8.3 Static synchronisation

In static synchronisation, the synchronising genset is running very close to the same speed as the generatoron the busbar. The aim is to let them run at exactly the same speed and with the phase angles between thethree-phase system of the generator and the three-phase system of the busbar matching exactly.

It is not recommended to use the static synchronisation principle when relay regulation out-puts are used. This is due to the slower nature of the regulation with relay outputs.

The static principle is illustrated below.

Synchronised

t [s]

20°

10°

0°

Angle

L1gen/L1bus

[deg]

Synchronisation principle – static synchronisation

Speed:

1503 RPM

50.1 Hertz

Speed:

1500 RPM

50.00 Hertz

LOAD

G

GB

G

GB

L1

L2L3

L1

L2L3

L1

L2L3

L1

L2L3

Generator on loadSynchronising generator

L1

L2L3

α

L3

L1

L2

α

L3

L1

L2

α

L3

L1

L2

30°

8.3.1 Phase controllerWhen the static synchronisation is used and the synchronising is activated, the frequency controller will bringthe genset frequency towards the busbar frequency. When the genset frequency is within 50 mHz of the bus-bar frequency, then the phase controller takes over. This controller uses the angle difference between thegenerator system and the busbar system as the controlling parameter.

This is illustrated in the example above where the phase controller brings the phase angle from 30 deg. to 0deg.



8.3.2 Close signalThe close signal will be issued when phase L1 of the synchronising generator is close to the 12 o’clock posi-tion compared to the busbar which is also in 12 o’clock position. It is not relevant to use the response time ofthe circuit breaker when using static synchronisation, because the slip frequency is either very small or non-existing.

To be able to get a faster synchronisation, a "close window" can be adjusted. The close signal can be issuedwhen the phase angle UGENL1-UBBL1 is within the adjusted setpoint. The range is +/-0.1-20.0 deg. This isillustrated in the drawing below.

± close window

Max. Du difference

Max. Du differenceUBB

UGEN

Direction of

rotation

The synchronisation pulse is sent dependent on the settings in menu 2030. It depends on whether it is theGB or the MB that is to be synchronised.

8.3.3 Load picture after synchronisationThe synchronised genset will not be exposed to an immediate load after the breaker closure if the maximumdf setting is adjusted to a low value. Since the fuel rack position almost exactly equals what is required to runat the busbar frequency, no load jump will occur.

If the maximum df setting is adjusted to a high value, then the observations in the section about "dynamicsynchronisation" must be observed.

After the synchronising, the unit will change the controller setpoint according to the requirements of the selec-ted genset mode.

Static synchronisation is recommended where a slip frequency is not accepted, for instance ifseveral gensets synchronise to a busbar with no load groups connected.

Static and dynamic synchronisation can be switched by using M-logic.

8.3.4 AdjustmentsThe following settings must be adjusted if the static synchroniser is selected in menu 2000:




2031Maximum df

The maximum allowed frequency difference be-tween the busbar/mains and the generator.

+/- value.

2032Maximum dU

The maximum allowed voltage difference be-tween the busbar/mains and the generator.

+/- value related to the nominal gener-ator voltage.

2033Closing window

The size of the window where the synchronisa-tion pulse can be released.

+/- value.

2034Static sync

Minimum time inside the phase window beforesending a close command.

2035Static type GB

"Breaker" or "Infinite sync" can be chosen. "Infinite sync" will close the MB to thebusbar and run the generator in syncwith the mains. The GB is not allowedto close.

2036Static type MB

"Breaker" or "Infinite sync" can be chosen. "Infinite sync" will close the GB to thebusbar and run the generator in syncwith the mains. The MB is not allowedto close.

2061Phase KP

Adjustment of the proportional factor of the PIphase controller.

Only used during analogue regulationoutput.

2062Phase KI

Adjustment of the integral factor of the PI phasecontroller.

2070Phase KP

Adjustment of the proportional factor of the PIphase controller.

Only used during relay regulation out-put.

8.4 GB closing before excitation

It is possible to adjust the AGC to start up the genset with the excitation switched off. When the gensets arestarted up, the breakers will be closed and the excitation started. It is also possible to close the breaker be-fore the engine is started. This function is called "close before excitation".

The purpose of the "close before excitation" is that the gensets are able to be ready for the load very quickly.All of the gensets will be connected to the busbar as soon as they are started, and as soon as the excitationis switched on, the gensets are ready for operation. This is faster than the normal synchronising, because inthat case the breakers will not be closed until the generator voltage is in the synchronised position, and ittakes some time to achieve that position.

The "close before start" function can also be used if the load requires a "soft" start. This can be the casewhen the gensets connect to a transformer.

As soon as the excitation is activated, the generators will equalise the voltage and frequency and will eventu-ally run in a synchronised system. When the excitation is activated, then the regulators of the AGC will beswitched on after an adjustable delay.

The function can be used in the single AGC but also the AGC with option G4 or G5.

The excitation must be increased slowly when this function is used.



This function can only be used when a magnetic pick-up is used.

This function is not available in units with option G3.

The principle is described in the flowcharts below.

Flowchart abbreviations

Delay 1 = Menu 2252Delay 2 = Menu 2262Delay 3 = Menu 2271

SP1 = Menu 2251SP2 = Menu 2263



8.4.1 Flowchart 1, GB handling

Delay 1 expired

on all DG(s)

Start

RPM > SP1

End

YesRPM > SP2

No

Delay 1 expired

Yes

Yes

No

Yes

Yes

Start DG(s)

Close GB

Start

excitation

Delay 1 expired

Trip GBStart

excitation

Delay 2 expired

Delay 3 expired

”Close before

excitation”

failure

Activate

regulators

UBUS OK

Delay 2 expired

Activate

regulators

Sync GB

Delay 3 expired

”Close before

excitation”

failure

UBUS OK

No

No

Yes

No

No

No

Yes

Yes

No

No

No

No

Yes

Yes

Yes



8.4.2 Flowchart 2, TB handling (option G5)

Start

Any GB closed

MB OFF

Close TB

End

No

No

Yes

TB Open

No

Yes

Yes

PAVAIL > PCAP

Yes

No

”GB + TB”

Sync TB

Yes

No



8.4.3 Genset start actionsThe start sequence of the AGC is changed in order to achieve the function "close before excitation". The fol-lowing parameters must be adjusted:

Menu Description Comment

2251 RPM setpointfor breakerclosing

The generator breaker will close at the adjusted level. The range is from 0-400RPM. If it is adjusted to 0, then the breaker will be closed when the start com-mand is given.In the example below the setting is adjusted to 400.

2252 RPM timer The genset must reach the setpoint (menu 2263) within the adjusted delay.When the delay expires and the RPM is above the setpoint, then the excitationwill be started. If the RPM is below the setpoint, then the GB will be tripped.

2253 Output A Select the relay output that must be used to start the excitation.Configure the relay to be a limit relay in the I/O setup.

2255 Enable Enable the function "close before excitation".

1500 RPM

1350 RPM

400 RPM

Engine RPM

time

Close GB Start excitation

RPMNOM

The diagram above shows that the GB will be closed at 400 RPM. When the engine RPM has reached thesetpoint (menu 2263) (1450 RPM), then the excitation is switched on.

8.4.4 Breaker sequenceThe "GB close before start" function can be used in three applications:

1. AGC single genset plant2. AGC power management plant - no tie breaker present3. AGC power management plant - tie breaker present

In one of the applications a tie breaker is present, and it must be adjusted in the menu 2261 whether only thegenerator breaker must be closed or both the generator breaker and also the tie breaker.

The breaker sequence adjustments are the following:



Menu Description Comment

2261 Breaker selection Select breakers to close: GB or GB + TB.

2262 Timer The timer defines the period from the excitation is started and until the regu-lation is activated. The alarms with inhibit set to "Not run status" will be acti-vated after this timer has expired.

2263 Excitation start level The setting defines at what level of RPM the excitation is started.

8.4.5 "Close before excitation" failureIf the starting of the genset does not succeed, then the alarm menu 2270 "Cl.bef.exc.fail" will occur, and theselected fail class will be executed.

8.5 Separate synchronising relay

When the AGC gives the synchronising command, then the relays on terminal 17/18/19 (generator breaker)and terminal 11/12/13 (mains breaker) will activate, and the breaker must close when this relay output is acti-vated.

This default function can be modified using a digital input and extra relay outputs depending on the requiredfunction. The relay selection is made in the menu 2240, and the input is selected in the input settings in theutility software.

The table below describes the possibilities.

In-put

Re-lay

Relay selectedTwo relays used

Relay not selectedOne relay used

Not used Synchronising:The breaker ON relay and the sync. relay activate at thesame time when synchronising is OK.Blackout closing:The breaker ON relay and the sync. relay activate at thesame time when the voltage and frequency are OK.

Synchronising:The breaker ON relay activateswhen synchronising is OK.Blackout closing:The breaker ON relay activateswhen the voltage and frequencyare OK.

DEFAULT selection

Low Synchronising:Not possible.Blackout closing:The breaker ON relay and the sync. relay activate at thesame time when the voltage and frequency are OK.

Synchronising:Not possible.Blackout closing:The breaker ON relay activateswhen the voltage and frequencyare OK.

High Synchronising:The relays will activate in two steps when the synchro-nising is selected:1. Breaker ON relay activates.2. When synchronised the sync. relay activates.

See note below!Blackout closing:The breaker ON relay and the sync. relay activate at thesame time when the voltage and frequency are OK.

Synchronising:Not possible.Blackout closing:The breaker ON relay activateswhen the voltage and frequencyare OK.



When two relays are used together with the separate sync. input, then please notice that thebreaker ON relay will be activated as soon as the GB ON/synchronising sequence is activated.

Care must be taken that the GB ON relay cannot close the breaker, before the sync. signal isissued by the sync. relay.

The selected relay for this function must have the "limit" function. This is adjusted in the I/Osetup.



9. Parameter list9.1 Related parameters

The Designer’s Reference Handbook relates to the parameters 1000-1980, 2000-2780, 3000-3490,4120-4990, 5000-5270, 6000-6900 and 7000-7120.

For further information, please see the separate parameter list, document number 4189340688.

AGC-4 manual, November 2011, UK Parameter list


10. Voltage/VAr/PF control10.1 Description of option, ANSI numbers

Function ANSI no.

Voltage synchronisation matching 25, 90

Constant voltage control for stand-alone generator 90

Constant reactive power control for paralleling generator 90

Constant power factor control for paralleling generator 90

Reactive power load sharing for paralleling with other generators 90

10.2 Description of option, Option D1

Option D1 is a combined software and hardware option. The specific hardware selection depends on the re-quired interfacing to the automatic voltage regulator (AVR).

10.3 Functional description, Running mode selection, AGC/PPM

The unit selects the actual setpoint in one of two ways:1. Automatic selection based on GB and MB feedback (MB for AGC only).2. Manual selection based on digital inputs selection.

10.3.1 Automatic selectionWhen the automatic running mode selection is used, the actual running mode is as indicated in the table:

AGC:

Generator break-er OFF

Generator breaker ON,Mains breaker OFF

Generator breaker ON,Mains breaker ON

Fixed voltage X X

Fixed power factor X

VAr sharing (requires OptionG3 or G5)

X

PPM:

Generatorbreaker OFF

Generator breaker ON, Shaftgenerator/Shore connection

breaker OFF

Generator breaker ON, Shaftgenerator/Shore connection

breaker ON

Fixed voltage X X

Fixed power factor X

VAr sharing X

VAr sharing mode is a mix of fixed voltage and VAr sharing. This means that the reactive loadwill be shared equally between the gensets, AND the voltage will be maintained at the nominalvalue.

AGC-4 manual, November 2011, UK Voltage/VAr/PF control


10.3.2 Manual selectionIf the manual running mode selection is used, the actual mode depends on the activated input. How to selectthe manual running mode is described in the Designer’s Reference Handbook.

The purpose of manual selection is to be able to use external setpoints, e.g. from an externalpotentiometer or a PLC.

The available running modes and their respective adjustment ranges:

Mode Comment Terminal "ext. U/Q setpoint"

Fixed voltage Stand-alone generator or GBopened

+/-10V DC input ~ nominal voltage +/-10%

Fixed VAr Fixed reactive power 0-10V DC input ~ 0-100% reactive power

Fixed PF Fixed power factor ÷10-0-10V DC input ~ 0.6 capacitive-1.0-0.6 inductive PF

0-100% relates to the nominal power of the generator.

10.3.3 Input selectionIn order to activate the input for the external setpoint, the digital input functions "Ext. U control", "Ext. PF con-trol" or "Ext. Q control" must be programmed in the PC utility software (USW) as illustrated below.

Only one of the functions needs to be programmed.

10.4 Functional description, Regulation mode selecetion, GPC/PPU

The regulation mode selection is done in the GPC/PPU using digital inputs, M-Logic or external communica-tion, e.g. Modbus.



The modes are used to change the control method of the AVR when the GB is closed. With the GB open, therunning mode is fixed voltage and frequency unless manual or SWBD mode is activated.

Available regulator modes with option D1:

Mode Comment

Fixed voltage E.g. stand-alone generator

Fixed Q Fixed reactive power

Fixed PF E.g. parallel with mains

Q load sharing Reactive load sharing

Voltage droop Voltage will drop with rising reactive power

10.4.1 Input selectionThe mode inputs must be programmed in the PC utility software (USW) as illustrated below (default settings).

Only one of the functions needs to be programmed.



10.4.2 Regulators

The working principle of the PID regulator is described in the Designer’s Reference Handbook.

The outputs for the AVR can be either analogue or digital. Please refer to the data sheet for further informa-tion about possible selections.

10.4.3 External setpointThe external setpoints can be used if the setpoint comes from another source, e.g. a PLC. In order to activatethe external setpoint, the mode input called "Ext. AVR setpoint" is used. When the input is high, the externalsetpoint is used and when it is low, the internal setpoint is used.

The inputs for the external setpoints are terminal 41 (common) and 42 (+) and the signal level is +/-10V DC.

The available running modes and their respective adjustment ranges are described in the table below:

Mode "Ext. AVR setpoint" = ON Comment

Fixed voltage +/-10V DC input ~ nominal voltage +/-10% Stand-alone generator or GB opened

Fixed Q 0…10V DC input ~ 0…100% reactive power Fixed reactive power

Fixed PF 0…10V DC input ~ 1…0.6 inductive PF Fixed power factor

Q load sharing +/-10V DC input ~ nominal voltage +/-10% Reactive power sharing

Voltage droop +/-10V DC input ~ nominal voltage +/-10%

0…100% relates to the nominal power [P] of the generator.

10.4.4 AVR mode undefined (menu 2750)After the breaker has been closed, it is required that 1 AVR regulation mode is selected. In case no mode isselected or more than one mode is selected, the following action will be performed regardless of the fail classselected for "AVR mode undef." in menu 2750:

1. No mode input active: the unit is changed to manual mode (regulator OFF) and an "AVR mode undef."alarm is raised after the delay has expired.

2. More than 1 mode input active: the unit is maintained in the first selected running mode and an "AVRmode undef." alarm is raised.

10.5 Functional description, Regulation mode selection, GPU

There is no regulation mode selection available for the GPU. It will always operate in fixed voltage controlwhen the GB is open, make voltage matching during synchronisation and after closing of the GB, the regula-tion is turned OFF.

To activate the regulation in a GPU, option G2 is required.



10.6 Functional description, AVR regulation failure

The AVR regulation failure in menu 2230 is part of option D1. The alarm occurs when the regulation is activa-ted but the setpoint cannot be reached.

The alarm will appear when the setpoint is reached. The deviation is calculated in per cent:

Example:UACTUAL = 400V ACUNOMINAL = 440V AC

Difference in per cent: (440-400)/440*100 = 9.1%

If the alarm setting is lower than 9.1% in this example, the alarm appears.

Adjust the alarm setting "Deadband" to 100% to deactivate the alarm.

10.7 Functional description, Manual AVR control

Regarding manual control of the AVR, please refer to the chapter "Manual governor and AVR control" in theDesigner’s Reference Handbook.

10.8 Functional description, Voltage-dependent PF/Q control (y2(x2) droop

Voltage-dependent power factor or reactive power control is a function that gives a dynamic power factor/re-active power control in an isolated system based on the grid voltage. The purpose is to support the grid volt-age locally behind a transformer by minimising the reactive current flow in the grid.

The selection between using power factor and reactive power regulation is made in setting7143.

The selection between relating to mains voltage or generator power is made in setting 7144.

(Unom-Uact)*100/Uacy [%]

MIN

PF

DBH

HYSH

0%1%2%3%4% 1% 2% 3% 4% 5%5%

Power Factor Set point

6%7%8%9%10% 6% 7% 8% 9% 10%

SH

0.6 C

DBL

HYSL

SL

0.6 l

MA



The above vector diagram is configured with the following parameter settings:


7052 0.9 Power factor Power factor setpoint 0.6-1

7053 Inductive Power factor Inductive/capacitive

7151 2.00 DBL[%] Deadband low in percentages of nominal X2.

7152 2.00 DBH[%] Deadband high in percentages of nominal X2.

7153 1.00 HYSL[%] Hysterese low in percentages of nominal X2. If HYSL is set above DBL,the hysteresis low is disabled.

7154 1.00 HYSH[%] Hysterese high in percentages of nominal X2. If HYSH is set aboveDBH, the hysteresis high is disabled.

7171 0.8 MI Minimum output of droop handling. This setting is related to the settingin 7172.

7172 Inductive I/C Minimum output of droop handling.

7173 1.00 MA Maximum output of droop handling. This setting is related to the settingin 7174

7174 Inductive I/C Maximum output of droop handling.

7175 -0.05 SL[PF/%] Slope low. The setting determines the increase/decrease of PF refer-ence per percentage the actual X2 drops below nominal X2.

7176 0.05 SH[PF/%] Slope high. The setting determines the increase/decrease of power ref-erence per percentage the actual frequency rises above nominal fre-quency.

7181 PF(X2) Y2(X2) Output type for curve 2. Selections currently available “Reactive Power”and “PF”

7182 U X2 Input type for curve 2. Selections currently available “Power” and “Volt-age”

7183 ON ENA Enable/Disable of curve2.

Example:With a nominal voltage of 400 V and an actual voltage of 412 V, there is a deviation of 12 V which is equal toa 3% deviation from the nominal setting. The genset will then droop to a power factor 0.95 inductive accord-ing to the above settings.

The Q control is programmed similarly to the frequency droop function. Please see the fre-quency droop function in the Designer’s Reference Handbook for reference.

This function is in many ways comparable to the droop functionality.

The system measures and reacts based on the mains voltage measurement. The function will make a dy-namic voltage-dependent PF/Q ramp that is used to support the mains voltage. The ramp has a configurabledeadband that can be used with reference to the nominal voltage of the mains to deactivate the ramp func-tionality. This is to have a normal operation band where a normal voltage fluctuation does not create disturb-ance on the mains. If the deadband is set to 0, the deadband is removed and the ramp will be active at anytime.



When the mains measurement is outside the deadband, the voltage deviation is taken into consideration anda new power factor/reactive power value is calculated. The power factor/reactive power regulator of the gen-erator will then adjust the power factor/reactive power and thereby change the VAr import/export of the plant.

The calculation is based on the fixed power factor/reactive power setpoint value.

The system is able to run the generator with a capacitive and an inductive power factor/reactive power lower-ing or raising the grid voltage.

The system is made with only one active regulator on the generator and a variable curve defining the setpointto the regulator. This ensures that there are no hunting problems with 2-3 regulators in cascade.

The ramp slope is set in % per unit [%/u] where the unit is in V AC, meaning that the nominal setting for slopelow, 10%/u means 10% increase of power factor/reactive power per volt AC deviation.

AGC: This function is only active when activated and when the generator is running parallel tomains grid.

PPU/GPC: This function is only active with "ixed PF"or "ixed Q"mode activated depending onthe selection in menu 7143.

PPM: This function is not supported.

10.9 Parameters, Further information

The option D1 relates to the parameters 2640-2690, 2730, 2750 and 2782; for voltage-dependent PF/Q con-trol parameter 7150/7180.

For further information, please see the separate parameter list for the Multi-line unit in question:

AGC-3 Document number 4189340705


PPM Document number 4189340672

GPC-3/GPU-3 Hydro Document number 4189340580

PPU-3/GPU-3 Document number 4189340581



11. Load sharing11.1 Description of option, ANSI numbers

Function ANSI no.

Load sharing between gensets 90

11.2 Description of option, Option G3

11.2.1 AGCOption G3 is a hardware option, and therefore a separate PCB is installed in slot #3 in addition to the stand-ard-installed hardware. If option M12 is already installed in the unit, option G3 is a software upgrade.

11.3 Description of option, Terminal description

Term. Function Technical data Description Comment

37 -5/+5V DC Analogue I/O Active load sharing line Requires option G3

38 Com. Common Common

39 -5/+5V DC Analogue I/O Reactive load sharing Requires option D1/G3

40 -10/+10V DC Analogue I/O f/P setpoint Requires option G3


42 -10/+10V DC Analogue I/O U/Q setpoint Requires option D1/G3

11.4 Functional description, Load sharing

Option G3 is an option that enables the unit to share the active load (and reactive load (option D1)) equally inpercentage of the nominal power. The load sharing is active when the genset is running in island mode andthe generator breaker is closed.

A voltage signal equal to the load produced by the genset is sent to the load sharing line. When the generatorload is 0%, 0V DC is sent to the load share line. When the load is 100%, the voltage will be 4V DC.

This is illustrated in the drawing below.

AGC-4 manual, November 2011, UK Load sharing


Load sharing line

4V DC

100% loadReverse power

V DC

100% load

-4V DC

Power

The active load sharing line is illustrated above, and the characteristics of the reactive load sharing line areequivalent to it.

11.4.1 Working principleThe controller unit will supply a voltage on the load sharing line equal to the actual load. This voltage comesfrom an internal power transducer. At the same time, the actual voltage on the load sharing line will be meas-ured.

If the measured voltage is higher than the voltage from the internal power transducer, the unit will in-crease its load in order to match the voltage on the load sharing line.If the measured voltage is lower than the voltage from the internal power transducer, the unit will de-crease its load in order to match the voltage on the load sharing line.

The voltage on the load sharing line will only be different from the voltage from the internal power transducer,if two or more controller units are connected to the load share line.

When the option G3 is activated, the load share line will be active at all times no matter if one generator isrunning in a single application, or a number of generators are actually sharing the load. In case a generator isrunning alone, it is recommended to disable the load share line to keep the frequency regulator active.

To disable the load share line, use the M-Logic category output/inhibits in the PC utility soft-ware.



To improve the handling of several generators in the same application, the option G3 is working as backupsystem for the power management AGC; option G5. This means that if both option G3 and power manage-ment are available in the same unit, the load sharing will be done by the CANbus communication as the pri-mary choice, but if a CANbus error occurs, the load sharing will continue on the analogue load sharing line.The generators will stay stable even though the power management is lost.

AGC only: please refer to the description of option G5 for further information about the powermanagement.

Example 1:Two generators are running in parallel. The loads of the generators are:

Generator Actual load Voltage on load sharing line

Generator 1 100% 4V DC

Generator 2 0% 0V DC

The voltage level on the load sharing line can be calculated to:

ULS: (4 + 0) / 2 = 2.0V DC

Now generator 1 will decrease the load in order to match the voltage on the load sharing line (in this example2.0V DC). Generator 2 will increase the load in order to match the 2.0V DC.

The new load share situation will be:

Generator Actual load Voltage on load sharing line

Generator 1 50% 2.0V DC

Generator 2 50% 2.0V DC

Example 2:If the size of the generators differs, the load sharing will still be carried out on the basis of a percentage of thenominal power.

Two generators supply the busbar. The total load is 550 kW.

Generator Nominal power Actual load Voltage on load sharing line

Generator 1 1000 kW 500 kW 2.0V DC

Generator 2 100 kW 50 kW 2.0V DC

Both generators are supplying 50% of their nominal power.



11.5 Functional description, Island ramp up with load steps

Po

we

r [k

Wh

]

Time [sec] GB closed

De

lay,

ste

p 1

Power ramp [%/s]

Analogue load share set point

Ra

mp

up

, re

ad

fro

m lo

ad

sh

are

line Sta

nd

ard

lo

ad

sh

arin

g

One step before the

load share setpoint is

reached the ramp up

function is switched off

De

lay,

ste

p 2

De

lay,

ste

p 3

De

lay,

ste

p 4

De

lay,

ste

p 5

When menu 2614 is enabled, the power setpoint continues to rise in ramp up steps, determined by menu2615, towards the load sharing setpoint. The delay time between each ramp up step will be determined bymenu 2613. The ramp up will continue until the load sharing setpoint is reached, and then the regulator willbe switched to standard load sharing mode.

If the delay point is set to 20% and the number of load steps is set to 3, the genset will ramp to 20%, wait theconfigured delay time, ramp to 40%, wait, ramp to 60%, wait and then ramp to the system setpoint. If thesetpoint is at 50%, the ramp will stop at 50%.

11.6 Functional description, Freeze power ramp

A way to define the ramp up steps is to use the freeze power ramp command in M-Logic.


1. The power ramp will stop at any point of the power ramp, and this setpoint will be maintained as long asthe function is active.

2. If the function is activated while ramping from one delay point to another, the ramp will be fixed until thefunction is deactivated again.




11.7 Functional description, External analogue setpoints

The genset can be controlled from internal as well as from external set points. The external set points areactivated with a digital input.

The inputs are only available, if option G3 is selected.

Five different inputs can be selected by using the ML-2 PC utility software (USW):

Input Ext. setpoint active condition Comment

Ext. frequency ctrl Stand-alone generator or GB opened

Ext. power ctrl Parallel to mains (AGC)

Ext. voltage ctrl Stand-alone generator or GB opened Requires option D1.

Ext. PF ctrl Parallel to mains (AGC)

Ext. VAr ctrl Parallel to mains (AGC)

The controller setpoints will be ignored if the running condition is not present. It is for instance not possible touse the frequency controller when paralleling to the mains.

The table below shows the possible setpoints.

Controller Input voltage Description Comment

Frequency +/-10V DC fNOM +/-10% AGC only: active when MB isOFF

Power +/-10V DC PNOM +/-100%

Voltage +/-10V DC UNOM +/-10% AGC only: active when GB isOFF

Reactive power +/-10V DC QNOM +/-100%

Power factor ÷10 V…0…10V DC 0.6 capacitive…1.0…0.6 inductive

The external setpoints can be used in all genset modes, when auto or semi-auto mode is selected.

Only a limited number of digital inputs are available in the standard unit. The unit should beinstalled with the sufficient number of options to get the desired digital inputs.

If the option H2 (Modbus RS 485 RTU) is available in the unit, the external setpoints can becontrolled from the control registers in the Modbus protocol. Please refer to the description ofoption H2 for further information.

11.8 Functional description, Load sharing type

The AGC can be adjusted to work with different types of load sharing modules and ranges of the load sharingsignal. This is controlled by two menus: menu 6380 (signal level) and 6390 (load sharing type). The signallevel is used to adjust the maximum output of the LS lines. The default range is 0-4V DC, and therefore 4VDC is the voltage applied to the load sharing line at 100% load. If the AGC is interfacing to another productwhere the max. range is different, then it can be changed in this menu.



To be able to adjust the max. range, it is necessary to adjust the menu 6391 to "adjustable". The AGC is ableto provide between 1.0 and 5.0V DC as 100% load. Load sharing interfacing to DEIF Uni-line LSU (load shar-ing unit) and Multi-line 2 version 1 and version 2 might require a 0-5V DC range, depending on configuration.If the load sharing is unequal, please check this.

Menu 6390 holds the following possibilities: Adjustable Selco T4800 Cummins PCC

When either "Selco T4800" or "Cummins PCC" is selected, then the adjustable range is ignored. The selec-tion causes the AGC to modify the signal level of the LS lines to adapt to the specific brand of controller/loadshare unit.

11.8.1 Load sharing modulesIf interfacing is performed to the load sharing modules of unspecified brands, it might be necessary to providegalvanic separation of the load sharing lines. The input impedance of such isolation amplifiers should be highimpedance for proper function.

11.8.2 Selco T4800 load sharerThe signal level is +/-1V DC, so the AGC adapts automatically to this level. The terminals of the T4800 are 12(com) and 13 (+). When interfacing to the Selco T4800, the frequency difference of the measured comparedto generator nominal is taken into account in order to prevent unequal load sharing (not user-configurable).T4800 is for kW sharing only and not kVAr sharing.

11.8.3 Cummins PCC 3100The signal level is 0.3-2.1V DC, so the AGC adapts automatically to this level. The terminals (TB3) of thePCC3100 are placed on connector 8, and the terminals are 51 (kW), 53 (kVAr), 52 and 54 (common). Termi-nal 55 is a dedicated terminal for the shield of the load sharing cable. (Notice that kVAr sharing is option-dependent in some DEIF products (option D1)).

Cummins PCC applicationsWhen the DEIF AGC-3, AGC-4 or AGC 200/IOM230 is being used, then it is possible to interface directly withthe PCC using the terminal numbers as mentioned above.



PCC interface to DEIF AGC

PCC Interface to AGC-200/IOM-230

PCC in DEIF power management systemNotice that if the AGC is part of a power management system, then it is possible to enable the analogue loadsharing lines. This is done in M-logic by activating the command "Use Ana LS instead of CAN". If the CANbuscommunication is used for load sharing, the analogue LS line of the AGC-3 and AGC-4 is still updated so theCummins PCC will be able to adjust the load level according to the load level of the AGCs. This is useful ifthe AGC is placed on all gensets only sending start and stop commands to the PCC. This means that theCummins ILSI unit is not necessary.




The option G3 relates to the parameters 2610 and 6380-6390.






12. Power management12.1 Description of options, ANSI numbers

Function ANSI no.

Power management -

12.2 Description of options, Options G4, G5 and G8

The options G4, G5 and G8 (power management) are software options and therefore not related to any hard-ware apart from the standard-installed hardware.

The options G4, G5 and G8 are alike in the basic functionality. In the below table the differences are shown:

Product AGC gen. AGC mains AGC bus tie

Option G4 X X

Option G5 X X X

Option G8 X

This means that all functionalities available in the G4 and G8 options will also be available in the G5 option,but all power management functionalities regarding the mains connections and the sequences handling themains are not available in the G4 option, and only generator fulctionality will be available in the G8 option.

As the basic power management functions are similar in the three options, it will be possible to mix controllersspecified with one of the three options in the same application.

A number of AGC units are being used in the power management application, i.e. one for each mains breakerand tie breaker (AGC mains unit), if installed, one for each bus tie breaker (AGC bus tie unit) and one foreach generator (AGC generator unit). All units communicate by means of an internal CANbus connection.

AGC-4 manual, November 2011, UK Power management


The AGC mains unit includes the power management option and can therefore only be used with option G5applications. The generator AGC unit must be specified with either option G4, G5 or G8, because this unitcan be used in single genset applications and in power management applications.



12.3 Description of options, Terminal description

The CANbus interface for the internal communication between AGC units in a G4/G5/G8 application is placedon the engine interface PCB in slot #7.

Term. Function Technical data Description

98 +12/24V DC 12/24V DC +/-30% DC power supply/common for 118

99 0V DC

100 MPU input 2-70V AC/10-10.000 Hz Magnetic pick-up

101 MPU GND

102 A 0(4)-20 mADigitalPt100Pt1000VDO0-40V DC

Multi-input 1

103 B

104 C

105 A Multi-input 2

106 B

107 C

108 A Multi-input 3

109 B

110 C

111 Com. Common Common for terminals 112-117

112 Digital input 112 Optocoupler Configurable



115 Digital input 115 Optocoupler Ext. engine failure/configurable

116 Digital input 116 Optocoupler Start enable/configurable

117 Digital input 117 Optocoupler Running feedback/configurable

118 Digital input 118 Optocoupler Emergency stop and common for 119 and 120

119 NO Relay24V DC/5 A Run coil

120 NO Relay24V DC/5 A Start prepare

121 Com. Relay250V AC/8 A Crank (starter)

122 NO

123 Com. Relay24V DC/5 A Stop coil w/wire failure detection

124 NO

A1 CAN-H CANbus interface A

A2 GND

A3 CAN-L

B1 CAN-H CANbus interface B

B2 GND

B3 CAN-L



In menus 7540 and 7550, you can choose which CANbus interface you wish to use for internal communica-tion. For CANbus redundancy it is possible to use both communication interfaces.

If the LED marked "CAN B" on the main unit is alive, then the CANbus port(s) is (are) switchedon.

12.4 Description of options, Breaker feedbacks

12.4.1 Generator breakerThe feedbacks of the generator breaker must always be connected (terminals 26 and 27).

12.4.2 Mains breaker (MB) feedback

MB present: The feedbacks of the mains breaker must always be connected (terminals 24 and 25).MB not present: Selected in the power plant constructor (USW).

When no MB is represented, the MB open and close relays together with the inputs for MBopen and close feedbacks (terminals 24 and 25) will be configurable.

12.4.3 Tie breaker (TB)

TB present: The feedbacks of the tie breaker must always be connected (terminals 26 and 27).TB not present: Selected in the power plant constructor (USW)

When no TB is represented, the TB open and close relays together with the inputs for TB openand close feedbacks (terminals 26 and 27) will be configurable.



12.5 Description of options, Wiring diagram

The following diagrams show examples with three AGC units connected, e.g. one AGC mains and two gener-ator AGC units.

Multi-line 2

CANbus interface 1

A1 A2 A3

H GND L

Multi-line 2

CANbus interface 1

A1 A2 A3

H GND L

Multi-line 2

CANbus interface 1

A1 A2 A3

H GND L

120 Ω 120 Ω

Multi-line 2

CANbus interface 2

B1 B2 B3

H GND L

Multi-line 2

CANbus interface 2

B1 B2 B3

H GND L

Multi-line 2

CANbus interface 2

B1 B2 B3

H GND L

120 Ω 120 Ω

Multi-line 2

CANbus interface 1

A1 A2 A3

H GND L

Multi-line 2

CANbus interface 2

B1 B2 B3

H GND L

Multi-line 2

CANbus interface 1

A1 A2 A3

H GND L

120 Ω 120 Ω

As you can see from the last example, it is possible to mix CANbus interface 1 and 2.

For distances above 300 metres we recommend to use a CAN to fibre converter.

Do not connect the cable shield to the GND terminal of the AGC units.

12.6 Functional description, Power management functions

In the following chapter the power management functions of the AGC are listed.

Plant modes: Island mode (no mains unit) Automatic Mains Failure (needs mains unit) Fixed power/base load (needs mains unit)



Peak shaving (needs mains unit) Load takeover (needs mains unit) Mains power export (needs mains unit)

Display: Mains unit display showing mains breaker and tie breaker Generator unit showing generator and generator breaker

Power management functions: Load-dependent start/stop Priority selection

Manual Running hours Fuel optimisation

Ground relay control ATS control Safety stop (fail class = trip and stop) Load management Multiple mains support Secured mode Quick setup/broadcast Base load Heavy consumer (HC) Asymmetric load sharing (LS) Common PF control CAN flags

Please refer to the Designer’s Reference Handbook for standard functions not relating to thepower management option.



12.7 Functional description, Terminal strip overview

12.7.1 AGC generator unit





12.7.2 AGC mains unit





12.7.3 AGC bus tie unit





12.8 Functional description, Applications

The G4 and G5 options can be used for the applications listed in the table below. The G8 option can only beused for an island application with DG units.

Application Drawing below Comment

Island operation Island mode plant Multiple gensets

Automatic Mains Failure Parallel with 1-16 mains No back synchronising

Automatic Mains Failure Parallel with 1-16 mains With back synchronising

Automatic Mains Failure ATS plant, multiple start Multiple start system

Automatic Mains Failure ATS plant, mains unit Mains unit installed

Fixed power Parallel Also called base load1-16 mains units

Mains power export Parallel 1-16 mains units

Load takeover Parallel 1-16 mains units

Peak shaving Parallel 1-16 mains units

Refer to the Designer’s Reference Handbook for description of the individual genset modes.

Regarding AC and DC connections for the individual applications, please refer to the Installa-tion Instructions.



12.8.1 Island operation plantIn an application where up to 16 gensets are installed, the AGC will automatically operate in an island modewith load-dependent starting and stopping.

G

Generator

breaker

(GB 1)


Busbar

G

Generator

breaker

(GB 2)


CANbus

Controller

Display 1

Controller

Display 2

If a mains unit is installed and connected (e.g. for preparing future requirements to the application), the islandmode operation is selected in the mains unit.



12.8.2 Parallel with mains plantAn application where a mains breaker is installed together with up to 16 gensets is shown below.

The application also supports a redundant mains unit.

The application is shown with a tie breaker, but it is also possible to use the application without a tie breaker.The tie breaker can only be placed as shown in the drawing below.

G

Generator

breaker

(GB 1)


Busbar

G

Generator

breaker

(GB 2)


CANbus

Tie

Breaker

(GB)

Mains

breaker

(MB)

Mains

Consumers

Controller

Display 1

Controller

Display 2

Controller

Display mains

This one-line diagram is also valid for AMF plants without back synchronising and load take-over plants without possibility of synchronising the genset to the mains.

If no CTs are installed on the AGC mains, a 4-20 mA power transducer TAS-331 can be usedinstead.

The CT measurements are used when the transducer setup is 4/20 mA = 0/0 kW. The transduc-er is used when the transducer setup is changed from 0/0 kW.



12.8.3 Dual mains plantAn application with two mains breakers installed together with up to 16 gensets is shown below.

The application also supports redundant AGC mains units.

The application is shown with a tie breaker, but it is also possible to use the application without a tie breaker.

G

Generator

breaker

(GB 1)


Busbar

G

Generator

breaker

(GB 2)


CANbus

Tie

Breaker

(GB)

Mains

breaker

(MB 1)

Mains 1

Consumers

Mains

breaker

(MB 2)

Mains 2

Optional Optional

Controller

Display 1

Controller

Display 2

Controller

Display mains 1B

Controller

Display mains 2A

Controller

Display mains 2B

Controller

Display mains 1A

The tie breaker can only be placed as shown in the drawing.

In this application it will not be possible to synchronise the tie breaker.



12.8.4 ATS plantApplications that use an ATS for switching between mains supply and generator supply are supported aswell. Two application examples which use an ATS are shown below.

12.8.5 ATS plant, multiple start



12.8.6 ATS plant, mains unitDisplay

Tie

Breaker

(TB)

Mains

Consumers

Controller

G


Controller

Display 3

G


Busbar

G


CANbus

Controller

Display 1

Controller

Display 2

ATSON/OFF

Mains okay

12.8.7 Multiple mainsAn example of a multiple mains plant is shown below. This is just an example; please refer to the chapter onmultiple mains for further information about the possible combinations.

G

Generator

breaker

(GB 1)


Busbar

G

Generator

breaker

(GB 2)


CANbus

Tie

breaker

(TB 17)

Mains

breaker

(MB 17)

Mains 17

Consumers

BTB 33

G

Generator

breaker

(GB 3)


BUSBAR

G

Generator

breaker

(GB 4)


CANBUS

Tie

breaker

TB 18)

Mains

breaker

(MB 18)

Mains 18

Consumers

Controller

Display 1

Controller

Display 2

Controller

Display 3

Controller

Display BTB 33

Controller

Display 4

Controller

Display mains 17

Controller

Display mains 18



12.9 Display units, DU for option G5

Three displays exist for the option G5.

See the Designer’s Reference Handbook or the Operator’s Manual for detailed informationabout push-button functions and LED indication.

12.10 Display units, Generator unit display


multi-line AGC

VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

MODE

JUMP

START

INFO

STOP

Alarm

Alarm

OnRun

G

Load

12.11 Display units, Mains unit display


VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

MODE

JUMP

START

INFO

STOP

Alarm

Alarm

multi-line AGC MAINS

On On

Load



12.12 Display units, BTB unit display


multi-line AGC BUS TIE

VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

On

INFO

JUMP

Alarm

Alarm

MODE

12.13 Power management setup, Initial power management setup

The AGC is set up using the display and the PC utility software.

12.13.1 Display setupEnter the menu 9100 using the JUMP push-button. Select one of the following AGC types:

1. Mains unit2. DG unit3. BTB unit

When this setting is adjusted, the device returns to factory settings! Therefore this must bechanged prior to other adjustments.

Enter the menu 9170 using the JUMP push-button. Select "CAN protocol 2" for a multi mains functionality.Select "CAN protocol 1" for dual mains or single applications.

An alarm appears if CAN protocol 2 is needed.

12.13.2 PC software setupThe communication ID must be adjusted in the utility software for each of the AGC units. In the screen shotbelow, the internal communication ID is set to 1.



The numbering of the communication IDs must always start from the lowest number, so an application alwaysincludes a DG with ID 1. The principle also applies to the AGC mains where the numbering starts from ID 17and to the BTB units where the numbering starts from ID 33.

12.13.3 Application designThe application is designed through the utility software. Please select configuration.

Select a new application and adjust the settings in this dialogue box.



Description Comments

Producttype

Select AGC. PPM is a power management system for marine use.

Planttype

Select between Single DG Standard Dual mains Genset group

plant Genset group

Use "single DG" if option G5 is not selected (or if single functionality isneeded for a G5 AGC).

Use "standard" if a power management application is needed.

Use "dual mains" if the power management application with two mainsunits known from version 3.0-3.2 are to be used.

Genset group plant and genset group are used for power plants con-sisting of 17-256 gensets in the same application. [email protected] for further information.

Config-urationselec-tion

The AGC is able to in-clude four applications.One of these can beactive.Write a proper name ofyour application.

Press "Yes" in the pop-up window to set the application to active whendownloading it to the AGC.

It is possible to see which application is active when the USW is con-nected to the AGC.

Bus tieoptions

Select "Wrap busbar"if the BTBs are con-nected in a ring.

CANline op-tions

CAN line A: ConnectA1-A3.CAN line B: ConnectB1-B3.

Now the application can be designed using the section control panel.



For each area it is defined whether a generator and a mains is present, and the number and type of breakers.

12.14 Power management setup, Remove unit from PM

If one or more units have to be taken out of the power management system, the following possibilities existdepending on the situation.

12.14.1 Auxiliary supply OFFThe auxiliary supply must be removed from the AGC. This means that a CANbus alarm occurs on the otherAGCs. These alarms appear in a 2 DG plant where ID 2 is powered down:

Alarms Functioning unit (ID 1)

System alarm Failed CAN tx line

System alarm CAN ID 2 MISSING

Menu 7533 Miss. all units

Menu 7535 Any DG missing

The alarms will be present at all times during the failure. A reconfiguration of the power plant is required toremove the alarms.



12.14.2 Quick setupNormally, the quick setup function is only used for simple rental applications. It only requires a few settings tobe running, and these settings can be made via the DU-2 display on the AGC, so no utility software is nee-ded.

For more details, please refer to the chapter "Quick setup" in this document.

The mode changes according to the setting in CAN failure mode (menu 7532).

When the AGC is reconnected, the ID will automatically be enabled again in the other units when the ID hasbeen recognised. If the AGC that is reconnected is a new unit with the factory settings set in the parameterfile, a "Duplicate CAN ID" error message will appear. When an ID is chosen for the new unit, and the ID chos-en is already active in another device, the error message "CAN ID not available" will appear, and the ID isreset to the start value.

12.14.3 Auxiliary supply ONIf a failure appears on the CANbus lines of an AGC, the following alarms appear in the example where a fail-ure appears at ID 2:

Alarms Defective unit Functioning unit

System alarm Failed CAN tx line Failed CAN tx line

System alarm CAN ID 1 MISSING CAN ID 2 MISSING

Menu 7533 Miss. all units Miss. all units

Menu 7535 Any DG missing Any DG missing

If the auxiliary supply of the unit where the CANbus is not functioning is connected, the AGC can be adjustedto another mode than AUTO. In that case the genset will not take part in the power management routines.

Semi-automatic start or automatic start is possible if the mode is changed to SEMI or AUTOmode. The only exception to this is when BLOCK mode is selected on a genset AGC. In thissituation the GB can be closed without allowance from the power management system.

12.15 Power management setup, CANbus failure handling

12.15.1 CAN failure modeIn case of a CAN failure on the internal CAN controlling the power management, the system can be set up indifferent ways. In menu 7530 it is decided how the power management system will react in case of a CANfailure.

1. If "MANUAL" is selected, all AGC units will change mode to manual mode, and this way the regula-tors will have no reaction, and it will not be possible to close any breakers.

Example 1:

A break on the CAN line is made between ID1 and ID2 shown below. Both gensets are running and all breakers are closed.



When the break occurs, the regulators will stop on both gensets, but they will stay online. As the gensetshave no valid information about the other unit, over time a blackout can occur as no load sharing is activebetween the units.

If for example six gensets are available in an island application, and the CAN failure happens between ID3and ID4, the load sharing will still be disabled between all units, as it is the manual mode which is activated.

If the CAN error happens when no gensets are running, it will block the whole system and it will not be possi-ble to start any gensets, before the CAN error has been fixed.

G

Generator

breaker

(GB 1)


Busbar

G

Generator

breaker

(GB 2)


CANbus

Controller

Display 1

Controller

Display 2

2. If "SEMI-AUTO" is selected, all AGC units will change mode to semi-auto mode, and this way theregulators will continue to regulate the load on the gensets which are still "visible" on the internalCAN communication. This means that in the example with six gensets, the load sharing will contin-ue between the units which are still connected (ID1-ID3 and ID4-ID6).

If the CAN error happens when no gensets are running, it will not block the whole system, and it will be possi-ble to start all the gensets in SEMI-AUTO mode, even though the CAN error has not been fixed.

A message will be shown in the status line "BLACKOUT ENABLE" on the display.

If the CANbus error is present and no generator breakers are closed, it will be possible toclose two breakers on the same busbar, which may result in fatal damage to the whole system.

It is recommended to use the analogue load sharing (option G3) and an interlock system toprevent this situation.

3. If "No mode change" is selected, all AGC units will stay in the mode they were in before the failureappeared.



This setting makes it possible to keep the system in Auto mode in case of a CAN failure, however, the faultyunit will not be a part of the power management, since it cannot send or receive status and commands on theCANbus.

If this selection is used, it is recommended to use the CANbus fail class settings to disconnect the faulty units(refer to the "CANbus fail class" in this chapter).

If the CANbus error is present and no generator breakers are closed, it will be possible toclose two breakers on the same busbar, which may result in fatal damage to the whole system.

It is recommended to use the analogue load sharing (option G3) and an interlock system toprevent this situation.

12.15.2 Redundant CANbus communicationIt is possible to use two CANbus communication lines; CAN I/F 1 (A1/A2/A3) and CAN I/F 2 (B1/B2/B3). Thisway, the communication will be redundant, and if one of the CANbus communication lines are damaged, theapplication will still continue in Auto mode with full functionality.

12.15.3 CANbus alarmsThe following alarms can be displayed on an AGC unit in case of CANbus communication failures:

CAN A ID X MISSINGThe AGC unit has lost CANbus communication to one or more CAN IDs on CANbus I/F A.

CAN A MAINS X MISSINGThe AGC unit has lost CANbus communication to the AGC mains unit on CANbus I/F A.

CAN A BTB X MISSINGThe AGC unit has lost CANbus communication to the AGC BTB unit on CANbus I/F A.

CAN B ID X MISSINGThe AGC unit has lost CANbus communication to one or more CAN IDs on CANbus I/F B.

CAN B MAINS X MISSINGThe AGC unit has lost CANbus communication to the AGC mains unit on CANbus I/F B.

CAN B BTB X MISSINGThe AGC unit has lost CANbus communication to the AGC BTB unit on CANbus I/F B.

MISSING ALL UNITSThe AGC unit has lost the CANbus communication to all the other units. The fail class set in menu 7533will be executed.

FATAL CAN ERRORThe AGC unit has lost CANbus communication to more than one CAN ID on the CANbus line. The failclass set in menu 7534 will be executed.

ANY DG MISSINGThe AGC unit has lost CANbus communication to one of the generator CAN IDs on the CANbus line. Thefail class set in menu 7535 will be executed.



ANY MAINS MISSINGThe AGC unit has lost CANbus communication to one of the mains CAN IDs on the CANbus line. The failclass set in menu 7536 will be executed.

ANY BTB MISSINGThe AGC unit has lost CANbus communication to one of the BTB CAN IDs on the CANbus line(s). Thefail class set in menu 7536 will be executed.

12.15.4 CANbus fail classIn menu 7530 it is possible to set a fail class of the following CANbus alarms:

Missing all units Fatal CAN error Any DG missing Any mains missing

By using these settings, it is possible to disconnect the faulty units and in this way keep the system running inAuto mode. (Depends on the setting 7532).

For a general description of "Fail class" please refer to the Designer’s Reference Handbook.

12.16 Power management setup, Quick setup

This function is made to provide an easy user interface for applications where it is vital for the end-user to beable to change the application quickly and easily.

It is often applications for the rental market that need this flexibility, and therefore there are some limitationsas to which applications that can be handled through the quick setup menu.

The following applications can be handled through the quick setup menu.

Island applications



Simple applications with connection to one mains

12.16.1 LimitationsIn most cases, the rental applications are very simple applications, and therefore there are some limitationsthat have to be considered when using the quick setup menu:

It will not be possible to have any AGC bus tie units in the application. It will not be possible to set up a "dual mains" application through the quick setup menu.

This function is made to facilitate change of a plant configuration without AGC BTB units. Entering the quicksetup menu 9180 via the DU-2 display makes it possible to add or remove a genset without the use of utilitysoftware. It is only possible to do the same basic setup as through the "application configuration" in the utilitysoftware.



The functions marked with clear text in the screen shots below can be accessed through the quick setupmenu.

12.17 Power management setup, 9180 Quick setup

9181 Mode

OFF: When the mode menu is set to "OFF", the existing application that is about to have this gensetincluded will not look for this new genset. This will give the operator time to connect all wiringand to do the basic setup of the genset.

SetupPlant:

When the mode menu is set to "Setup Plant", the new AGC will receive the application config-uration from the other units in the plant. The new AGC will then notify the rest of the applica-tion that a new ID is available on the line. If the ID of the new AGC already exists, the newAGC will – based on the ID numbers in the application configuration – have the highest ID + 1assigned. This new ID will then be included in the application configuration in all the otherAGCs. During this process, the existing application will be able to continue running and will notbe affected by the upgrade of the system.

The new AGC will automatically go to block mode to ensure that it is in a safe mode. When thesetup is done, the end-user must decide in which running mode the added genset is to run.

If there are already 16 gensets on the CAN line and a new AGC tries to connect to the plant, analarm text, "No IDs available", will appear.



SetupStand-alone:

When the mode menu is set to "Setup Stand-alone", the AGC will change the applicationconfiguration, so it will no longer be a part of the application. When the ID is removed fromthe application, the new application will be broadcasted to the other AGCs. The IDs of theexisting gensets in the application will maintain their ID, as a rearrangement could lead tounnecessary starting and stopping of the gensets.

If the genset that is to be removed is running, it will not be possible/allowed to continue theprocess until the genset has stopped. If it is attempted to disconnect, an info text, "Quick set-up error", will appear.

If "Setup Stand-alone" is activated when the genset is running, an info text, "Quick setup er-ror", will appear.

If an AGC BTB is detected in the application, an indicating alarm, "Appl. not possible", will ap-pear.

Change of setup from standard to single DG unit: When disconnecting a standard AGC unit ina system, it is important to change the menu 9181, plant setup. After disconnecting, the AGCunit will become a single DG.

12.17.1 9190 Application broadcastThis function makes it possible to broadcast an application over the CAN line from one AGC to all unitspresent in the application. It takes one operation to activate the broadcast function. It can be done in twoways:

1. By sending the application.2. By sending the application and activating it.

Menu 9191 Enable

OFF: When it is set to OFF, no broadcast will be made.

Broadcast: Broadcast of the selected application in menu 9192 will be sent to the units in theapplication.

Broadcast + Acti-vate

Broadcast is activated and the application in menu 9192 will be broadcasted andactivated in all units.



Menu 9192 ApplicationApplications 1-4 can be drawn in the utility software.

The following pop-up windows in the utility software will guide you through the broadcast.

12.18 Power management functions, Command unit

The power management system is a multi-master system. In a multi-master system, the available generatorunits automatically perform the power management control. This means that the system never depends ononly one master unit.

If for instance one unit ID is disabled, and this was the command unit, then the next available unit will takeover the command functions.

The above also applies to the AGC mains units – in that case the command unit is called Mains CommandUnit (MCU).

The command unit cannot be selected by the operator. It is automatically selected when a power manage-ment setting is accessed.

12.19 Power management functions, Load-dependent starting and stopping

The purpose of this function is to ensure that sufficient power is always available on the busbar. This meansthat the gensets will automatically be started and stopped in order to let only the sufficient number of gensetsrun. This optimises the fuel economy and the maintenance intervals.

The load-dependent start/stop function is active when the plant is in AUTO mode. The starting and stoppingof the gensets is automatically carried out according to the adjusted setpoints and priority selection.

The load-dependent start/stop function can be selected as:

Rated power setpoint (P) [kW] Apparent power setpoint (S) [kVA] Actual or load percentage value [%]

The load-dependent starting and stopping can be selected to base on either produced power calculation (%)or available power calculation (P or S).



The easiest way is to use produced power calculation; however, this method is not suited for systems withthree or more generators as regards fuel savings and saving running hours.

12.19.1 TerminologyThe table shows the abbreviations used.

Short Description Comment

PAVAILABLE Available power PTOTAL - PPRODUCED

PTOTAL Total power ΣPNOMINAL of running sets with GBs closed

PPRODUCED Produced power

PNOMINAL Nominal power

PNOMINAL-STOP Nominal power of the genset to stop Priority-dependent

Deactivate load-dependent stopThe load-dependent stop can be deactivated through M-logic, should this be preferred. This is necessary e.g.to allow operators to start the factory load after a blackout before the normal load-dependent operation canbe started.

In the example below, the function is activated with terminal 43. Now the operator can switch the load-de-pendent stop ON or OFF with a switch connected to terminal 44.

Produced power methodThis method is in effect if % power is selected in menu 8880 as basis for the start/stop calculation.

If the load % of a generator exceeds the "Start next" setpoint, the start sequence of the lowest priority genera-tor in stand-by will be initiated.

If the load % of a generator drops below the "Stop next" setpoint, the stop sequence of the running generatorwith the highest priority number will be initiated.

If the load of the plant decreases so much that the generator with the highest priority number can be stoppedand an available power of at least the stop setpoint in % is available, then the stop sequence of this generatorwill be initiated.



-200

-100

0

100

200

300

400

500

kW% load

Time

1 2 3

Load dep. start90

10Load dep. stop

1 Load increase

2 ”Load start delay” runs out; PMS start command

3 Stand by genset running and connecting to the busbar

Power produced% power

Available power methodThis method is in effect if P [kW] or S [kVA] is selected as basis for the start/stop calculation.

Independent of the selection (P [kW] or S [kVA]), the functionality is basically identical; therefore the exampleof the functionality below will be given for the load-dependent start function with selected rated power (P) val-ue.

The apparent power setpoint is typically selected if the connected load has an inductive character and thepower factor is below 0.7.

DescriptionThis drawing illustrates the terms used.

PNOM

1500 kW

PNOM

1000 kW

PNOM

1000 kW100%

70%

DG1 DG2 DG3

Σ = 2450 kW

Σ = 1050 kW (available power)

Σ = 3500 kW ~ 100%

Consumed power at the busbar

Nominal power



The nominal power is the rated power of the genset that can be read on the type plate of the generator.

Total powerThe total power is the summation of the rated nominal power of each individual genset. In the example abovethe plant consists of three DGs:

DG1 = 1500 kWDG2 = 1000 kWDG3 = 1000 kW

That is a total of 3500 kW

Produced powerThe produced power is defined as the existing load on the busbar. In the example above the produced poweris indicated as the hatched area, and the total of the three gensets = 2450 kW.

Available powerThe available power is the difference between the maximum possible power produced by the gensets and theactual produced power.

In the example above the plant consists of three gensets, in total 3500 kW. The load consumes 2450 kW intotal. Since the total load PTOTAL is 3500 kW, and the produced load PPRODUCED is 2450 kW, then the avail-able power PAVAILABLE is 1050 kW, meaning that the gensets can handle this load if it should be added tothe busbar.

12.19.2 Principle – available power methodOne genset is running and is supplying the load. The load increases which means that the available power/apparent power decreases. At a certain time the load has increased so much that only a little amount of pow-er/apparent power is available, and the next priority genset will be started in order to increase the amount ofavailable power/apparent power.

When the load drops, the available power/apparent power will increase. When the available power/apparentpower has increased above the stop level plus the nominal power of the last priority genset, then the last pri-ority genset will be stopped. Please note that the nominal power of the genset to be stopped is added to theadjusted stop level. The reason is that otherwise the available power/apparent power would immediately dropbelow the start level again.

Example:If the adjusted stop level is 200 kW (PSTOP = 200 kW), and the genset with the last priority is 1000kW, it is necessary that the available power reaches 1200 kW, because the available power will bereduced with 1000 kW immediately after the last priority genset is stopped.

12.19.3 Principle – percentage methodOne genset is running and is supplying the load. The load increases which means that the % load increases.At a certain time the load has increased so much that the load % start will start up the next priority genset inorder to take some of the load.

When the load drops, the produced power will decrease. When the produced power has decreased below thestop level plus the nominal power of the last priority genset, then the last priority genset will be stopped.Please note that the nominal power of the genset to be stopped is added to the adjusted stop level. The rea-son is that otherwise the produced power would immediately drop below the start level again.



Example:If the adjusted stop level is 10% (100 kW produced power), and the genset with the last priority is1000 kW, the last priority generator will produce 20% (200 W) after stop. It is necessary that the startlevel is above this value, otherwise an ongoing starting and stopping will take place.

12.19.4 Adjusting load-dependent startIn the example below the available power is 200 kW. When the load increases, the available power dropsbelow the start limit. The stand-by genset will start when the start timer runs out, and after the synchronisingthe available power increases (in this example to 500 kW).

-200

-100

0

100

200

300

400

500

P-Avail. on busbar

Time

1 2 3

Load start limit

1 Load increase

2 ”Load start delay” runs out; PMS start command

3 Stand by genset running and connecting to the busbar

Measured P-Avail.Predicted P-Avail.



12.19.5 Adjusting load-dependent stopIn the example below the available power is 500 kW. When the load decreases, the available power increa-ses to 750 kW. The AGC now calculates what happens if the last priority genset is stopped. In the examplebelow the last priority genset is 400 kW which means that it can be stopped, because the available power willstill be above the stop level.

Now the difference between the stop level and the available power is 50 kW. This means that only if the gen-set, which now has the last priority, is 50 kW, it can be stopped!

700

600

400

500

300

200

100

0

Load decreases

”Load stop delay” runs out; PM stop command

Last priority genset stopped

Load stop limit

1

1

2

3

2 3

If the order of priority is changed, the following must be observed:

If the priority does not seem to change as expected, it is because the load-dependent stopfunction is not able to stop the lowest priority after having started the new first priority. Thatwould cause two DGs to be running at low load instead of one DG.



12.19.6 Power windowThe difference between the programmed load-dependent start and stop limits forms the power hysteresis be-tween the start and stop. This is shown in the diagram below:

Available power

at the busbar

Load-depending start

Load-depending stop

Load stop

limit

Load start

limit

1. DG

Start

2. DG

Start

3. DG

Start

3. DG

Stop

2. DG

Stop

Power

window

PD

G1

PD

G2

PD

G3

PD

G3

PD

G2

12.20 Power management functions, Load management

The function is used to activate a relay when a specific amount of power is available. The purpose of thisfunction is to be able to connect load groups when the gensets of the emergency power plant are running.

In each of the gensets, five levels can be adjusted (menus 8220-8260):

Available power 1 Available power 2 Available power 3 Available power 4 Available power 5

These setpoints can activate a relay when the specific amount of available power is reached. The relay out-put can be used for connecting load groups when sufficient power is available. The relays will activate whenthe available power is higher than the setpoint, but be aware that when the load groups are being connected,the available power will decrease and the relay(s) deactivate again if the available power is below the set-point. So it is necessary to make an external holding circuit.

The number of available relays is option-dependent.

The function is not depending on the running modes. The relays will activate in all modes including block. Toavoid activation, e.g. when the genset is stopped, the inhibit function should be used.

Regarding the inhibit function, please refer to the Designer’s Reference Handbook.



It is possible to adjust different levels of available power in all gensets. This gives the possibility to use sever-al load groups if this is necessary.

Example:In the example below, generator #1 is started followed by generator #2. The simplified diagram shows the twogensets and two load groups that are being connected by the available power relays R1 and R2 on AGC1.

G


G


Load

Group 1

Trip load group 1

R1

K1

K1Load

Group 2

Trip load group 2

R2

K2

K2

R1 R2

Multi-line 2 Multi-line 2

12.20.1 Functionality description (refer to the diagram below)The generator #1 is started, and the timer t1 starts running when the GB1 closes. When the t1 is expired, theselected relay activates (R1), and in the example a 200 kW load group is connected. Now the available powerfalls to 300 kW. After some time the generator #2 is started and its generator breaker is synchronised. Whenthe GB2 closes, the timer t2 runs. When the timer t2 expires, the selected relay activates (R2), and the sec-ond load group of 200 kW is connected. Now the available power falls to 600 kW.



GB

1 O

N

t1

t2

R1 R2

200

1000

800

600

400

PAVAIL

kW

GB

2 O

N

To connect the load groups, individual relays can be selected on each AGC or on one of the AGC units only.

12.21 Power management functions, Load sharing

When the power management communication is running, the load sharing between the gensets is done byusing the CANbus communication between the AGC units.

If both CANbus ports are being used (A1-A3 and B1-B3), the communication automatically switches to theother port if e.g. A1-A3 is disconnected or faulty. (Please refer to the description of redundant CANbus).

If both CANbus lines are disconnected or faulty, the AGCs do not automatically switch over to analogue loadsharing. This has to be set up in M-logic: Use the command "Force analogue loadshare". Now the load shar-ing continues based on the signals from terminals 37/38/39. This means that the power management will belost, but the gensets already running will stay stable.

The option G3 has to be active to have the backup of the analogue load share line.



12.22 Power management functions, Island ramp up with load steps

Po

we

r [k

Wh

]

Time [sec] GB closed

De

lay,

ste

p 1

Power ramp [%/s]

CAN load share setpoint

Ra

mp

up

, re

ad

fro

m lo

ad

sh

are

line Sta

nd

ard

lo

ad

sh

arin

g

One step before the

load share setpoint is

reached the ramp up

function is switched off

De

lay,

ste

p 2

De

lay,

ste

p 3

De

lay,

ste

p 4

De

lay,

ste

p 5

12.23 Power management functions, Fixed power ramp up with load steps

Po

we

r [k

Wh

]

Time [sec]GB closed

De

lay, ste

p 1

Power ramp

[%/s]

Power Set point

Ra

mp

do

wn

Stop signal

Ra

mp

up

, re

ad

Fro

m lo

ad

sh

are

line

De

lay, ste

p 2

De

lay, ste

p 3

De

lay, ste

p 4

De

lay, ste

p 5



When menu 2614 is enabled, the power setpoint continues to rise in ramp up steps, determined by menu2615, towards the load sharing setpoint. The delay time between each ramp up step will be determined bymenu 2613. The ramp up will continue until the load sharing setpoint is reached and then switch the regulatorto standard load sharing mode.

If the delay point is set to 20% and the number of load steps is set to 3, the genset will ramp to 20%, wait theconfigured delay time, ramp to 40%, wait, ramp to 60%, wait and then ramp to the system setpoint. If thesetpoint is at 50%, the ramp will stop at 50%.

12.24 Power management functions, freeze power ramp

A way to define the ramp up steps is to use the freeze power ramp command in M-logic.


1. The power ramp will stop at any point of the ramp, and this setpoint will be kept as long as the function isactive.

2. If the function is activated while ramping from one delay point to the other, the ramp will be fixed until thefunction is deactivated again.


12.25 Power management functions, ATS applications

Two possibilities are available; the mains unit can either be installed or not.

12.25.1 AGC mains installed

See single line diagram for "Parallel with mains plant".

In an AMF application the AGC mains will normally operate the mains breaker and thereby make sure thatthe supply is coming from the mains if this is healthy.

This function allows the AGC to be used in an application where an automatic transfer switch is installed. Thisis known as an ATS.

In the applications shown as one-line diagrams in the chapter Functional description it can be seen that theATS will take care of the switching between the generator supply and the mains supply.

If ATS is selected, the AGC has no control over the ATS ("mains breaker").

DescriptionNormally the AGC detects a mains failure based on the voltage and frequency measurement on the mains.However, when ATS is selected in menu 7085 it is necessary to use a digital input together with the positionfeedbacks from the ATS. Thus, the mains failure is not detected by the AGC measurements but by the follow-ing two requirements:

1. Alternative start input ON2. ATS (MB) feedback OFF



To make the AGC detect a mains failure, the alternative start input has to be ON and the MB OFF feedbackhas to be active.

The input used as "Alternative start" function is configured in the PC utility software (USW).

The mains unit will not try to operate the ATS (mains breaker) at all. But it is still necessary that position feed-backs are wired up.

It is possible to have a tie breaker installed. This is useful if more gensets need to be started before supplyingthe load, because the tie breaker will not close until the required number of gensets is available.

12.25.2 ATS island mode

See single line diagram for "Island operating plant".

If this application is needed, the gensets can be started by activating the "auto start/stop" input. The gensetswill be started and stopped according to the power demand. That is, they will operate in load-dependent start/stop mode.

Be aware that since no tie breaker is installed, it is important that the first genset to close onthe busbar can carry the load. If the load is too high, the genset will be overloaded.

This application can be combined with the multi start function.

12.26 Power management functions, Fail class

The fail classes described in the Designer’s Reference Handbook are still valid when the power managementoption is selected. In addition to these fail classes the safety stop can be used in the AGC units with powermanagement.

This means that when a trip + stop alarm occurs, the faulty genset will stay on the busbar until the next priori-ty genset is started and synchronised to the bus. When the incoming genset has taken the load, the faultygenset will ramp down the power, followed by trip of the breaker, cooling down of the engine and finally stop.

If the faulty genset has the last priority, or no standby gensets are available, then it will stay on the busbarand will not trip.

If no genset can start in a safety stop situation, then the faulty genset will not be stopped.Therefore it is important that the safety stop is backed up, e.g. by a trip and stop alarm or ashutdown alarm.

12.27 Power management functions, Local/remote/timer operation

The plant can be adjusted to local, remote or timer operation (menu 8021). This selection is done in the com-mand unit, i.e. one of the generator units.



The setting defines how the plant is started while it is in AUTO mode.

The settings can be changed in M-logic and via display or PC utility software.

Display Utility SW(Parameter setup)

M-logic

Local X X X

Remote start X X X

Timer start X X -

The purpose of the selection is to decide whether the plant can be started from the display (local operator),from remote (e.g. PLC) or by an internal timer. Remote means that the control can be carried out by activat-ing the digital input or through Modbus/Profibus communication.

12.27.1 Local selectionAll operation is carried out on the display. In island operation any generator unit display can be used, and inload takeover, mains power export and fixed power the mains unit display must be used. The plant modemust be AUTO.

12.27.2 Remote selectionThe plant is started using the digital input "auto start/stop" when "remote" is selected.

Island modeIn island mode the "auto start/stop" input on any of the generator AGCs can be used for starting the plant.However, DEIF recommends to wire up the "auto start/stop" input to all of the AGCs to be sure that the auto-matic operation is able to continue even though one of the DGs is taken out for service (power supply discon-nected to the AGC).

In island mode any running mode (MAN, AUTO, SEMI, BLOCK) can be selected on the generator units, andthe remote start signal is still working for the remaining AGC which is still in AUTO mode.

Parallel to mains modeIn load takeover, mains power export and fixed power mode the "auto start/stop" input on the mains unit mustbe used for starting the plant.

12.27.3 Plant operationThe table shows how the plant is started:

Plant mode Selection Local Remote

Island mode Display on generator units Auto start/stop on gen. units

Fixed power mode Display on mains unit Auto start/stop on mains unit

Mains power export Display on mains unit Auto start/stop on mains unit

Load takeover Display on mains unit Auto start/stop on mains unit

In peak shaving and AMF the automatic operation starts automatically depending on the impor-ted power (peak shaving) or mains failures (AMF).



12.27.4 Timer selectionThe operation of the plant is controlled by up to eight internal command timers which are programmed usingthe PC utility software (USW).

The function can be used in load takeover, mains power export and fixed power, and the mains unit has to bein auto.

12.27.5 Principle

Start

LocalNo

RemoteNo

Press stop

button

Plant runningPress start

button

Yes

No

Yes

Yes

Local mode

Stop plant

No

No

Yes

Start plantAuto

start/stop

ON

Plant running

Auto

start/stop

ON

Yes

Yes

No

Yes

Remote mode

Start plant

No

Yes

No

Stop plant

Timer ON

Plant running Timer ONYes

No

Yes

Timer mode

Start plant

No

Yes

No

Stop plant

Yes



12.28 Power management functions, Multi-starting gensets

The multi-start function can be used to determine the number of gensets to start. This means that when thestart sequence is initiated through push-button, digital input or automatic start, then the adjusted numbers ofgensets will start.

This function is typically used e.g. together with applications where a certain number of gensets is required tosupply the load.

Example:In an AMF application with a tie breaker, the tie breaker must not close before the maximum power isavailable (power capacity setpoint).

The multi-start function is adjusted in menu 8922-8926.

12.28.1 Multi-start configurationThe multi-start function can be adjusted to operate with two different settings. These settings consist of set-points for how many gensets to start and the minimum number of running gensets.

It is possible to switch between the settings using M-Logic or menu 8924.

Setpoint 1 Setpoint 2

Multi-start (numbers to start) 8922 8925

Min no. running 8923 8926

Default setting

Start condition Setpoint 1 Setpoint 2 Default setting of DGs to start

Emergency operation Mains failure - X Start all DGs

Normal operation No mains failure X - Auto calculate

The default setting of the selection between setpoint 1 and setpoint 2 is made so the setpoint 1 is adjusted to"Auto calculation" and is used in all modes except for AMF. Setpoint 2 will automatically be selected in case amains failure occurs (this is adjusted in M-logic). Setpoint 2 is adjusted to 16 gensets which means that allavailable gensets will start when the mains failure occurs.



The default setting can be changed, if convenient.

12.28.2 Numbers to startThe numbers to start (menu 8922/8925) can be selected depending on the number of DGs available. Theload-depending start and stop function will be active as soon as the generator breakers are closed or, if a tiebreaker is installed, as soon as the tie breaker is closed. It is possible to adjust the number of gensets, or anauto calculation can be selected.

If it is needed to delay the load-dependent start and stop function, it can be done through theM-logic function.

Auto calculationWhen auto calculation is selected, the sufficient number of gensets will be started as soon as the start com-mand is given. This is not depending on the plant mode.

Example:In a four DG plant each generator is rated with 1000 kW. The setpoint for load-dependent start (menu8001) is adjusted to 100 kW.

If a start command is given in fixed power mode and the setpoint is 2000 kW, then three gensets willbe started immediately and the fourth genset will remain stopped. Three gensets will be started be-cause two gensets are requested to supply the load (2*1000 = 2000 kW) and the load-dependent startfunction requests the third genset.

12.28.3 Minimum numbers runningThe multi starting function can be combined with the setting of a minimum number of running gensets (menu8923/8926). This means that the load-dependent stop function is disregarded when only the specific numberof gensets is running. This is also the situation even though the load would justify a load-dependent stop.

"Numbers to start" (menu 8922/8925) and "Minimum numbers running" (menu 8923/8926) areavailable for all modes.



12.29 Power management functions, Priority selection

It is possible to use one of five types of priority selection.

The parameter for each of the five priority selections will only be enabled (visible) when one ofthe five options is selected via the USW channel 8031, or by using the display parameter 8030Priority select.

12.29.1 ManualThe manual selection gives a possibility to adjust the order of priority between the adjusted numbers of avail-able DGs. This means that each genset always has a specific priority setting.

The adjustment is made in the menus 8080 (P1-P5), 8090 (P6-P11) and 8100 (P12-P16). In this example theorder of priority is DG3, DG1, DG2, DG4.

Priority/Genset DG1 DG2 DG3 DG4

Menu 8081 P1 X

Menu 8082 P2 X

Menu 8083 P3 X

Menu 8084 P4 X

These settings are only adjusted in the generator units. After the adjustment the order of priori-ty must be transmitted manually to the other gensets using the transmit function in menu 8086.

Manual abs. (absolute)Scenario:The four gensets in the drawing below are set up to have the same priority and ID (genset 1 has priority 1,etc.).

When sections are separated with a BTB and the gensets are in AUTO, the “Manual abs” setup will at alltimes keep the priority adjusted for each controller. If the BTB is open the four gensets can start and stop astwo independent applications. E.g. if a genset is running on each side of the BTB, genset 1 and genset 3 willbe running as the first priority gensets. If the BTB is synchronised and closed the genset 2 will start and takeover the load from genset 3. When this is done, genset 3 is stopped and the application is now considered asone common application with four gensets.



Manual rel. (relative)Scenario:The four gensets in the drawing below are set up to have the same priority and ID (genset 1 has priority 1,etc.). “Manual relative” makes sense if there is a mains connection on each side of the BTB as shown in thepicture below.

When sections are separated with a BTB and the gensets are in AUTO, the “Manual rel” setup will auto-change the priority depending on the position of the BTB and depending on which mains ID has the “ID torun” function activated.

If the BTB is open the four gensets can start and stop as two independent applications. E.g. if the gensets 3and 4 are running on the right side of the BTB and the BTB is synchronised and closed, the gensets 1 and 2will not start and take over the load from gensets 3 and 4 as they are seen as new gensets being available inan already running application, and gensets 1 and 2 will now become priority 3 and 4.



12.29.2 Running hoursThe purpose of the priority selection based on running hours is to let all the gensets have the same or nearlythe same amount of running hours.

Every time the adjusted period in menu 8111 is reached, a new order of priority is determined, and the gen-sets with first priorities will be started (if not already running), and the gensets with the last priorities will stop.

There are two possibilities for operating the priority routine based on the running hours: Absolute or relative.The selection between the absolute and relative routine defines whether the offset adjustment of the runninghours is taken into consideration in the priority calculation. The offset adjustment is used e.g. when the AGCis installed on an old genset which already has many running hours, or if an AGC is replaced.

Running hours abs. (absolute)All gensets participate in the priority routine based on the principle shown in the table below. This means thatthe gensets with the lowest number of running hours will be running. This can be a disadvantage for instanceif the application consists of old gensets together with new gensets. In that situation the new gensets will bethe first priorities, until they have reached the same number of running hours as the old gensets. To avoidthis, the priority routine called relative running hours can be used instead.

The actual number of running hours is adjusted in each genset AGC in menus 6101 and 6102, typically at thecommissioning. The purpose of the menu is to have the correct number of running hours displayed.

Running hours rel. (relative)When "relative" is selected, all gensets will participate in the priority routine independently of the number ofrunning hours adjusted in menus 6101 and 6102. This means that all gensets in AUTO mode participate inthe priority routine. The relative selection gives a possibility to reset the priority routine. When the reset is acti-vated in menu 8113, the relative running hour counters in the AGC units will be reset to 0 hours, and at thenext priority selection the calculation is based on the reset values.

Principle for priority routineThe principle for the priority routine is described in the following table where the running hours (menu 8111)are adjusted to 24 hours. In this example only one genset is required by the load.



DG1(int. ID3)

DG2(int. ID2)

DG3(int. ID4)

DG4(int. ID1)

Comment

Monday 0 1051 h 1031 h 1031 h 1079 h DG2 will start due to the lowest internalID number

Tuesday 24 1051 h 1055 h 1031 h 1079 h DG3 will be started, and DG2 will bestopped

Wednesday 48 1051 h 1055 h 1055 h 1079 h DG1 will be started, and DG3 will bestopped

Thursday 72 1075 h 1055 h 1055 h 1079 h DG2 will be started due to the lowest in-ternal ID number, and DG1 will be stop-ped

Friday 96 1075 h 1079 h 1055 h 1079 h DG3 will be started, and DG 2 will bestopped

Saturday 120 1075 h 1079 h 1079 h 1079 h DG1 will be started, and DG3 will bestopped

Sunday 144 1099 h 1079 h 1079 h 1079 h DG4 will be started due to the lowest in-ternal ID number… and so on

The time adjusted in menu 8111 is the time between each priority calculation.

12.29.3 Fuel optimisationThe purpose of the fuel optimisation routine is to always let the gensets run in the best combination at anygiven load based on their actual nominal powers.

The settings are adjusted in the command unit.

The multi start function cannot be used together with the fuel optimising routine.



DescriptionThe function is set up in the following menus:

Menunumber

Menu text Description Comment

8171 Setpoint Load with best fueleconomy (% ofPNOM)

The units will optimise around this genset load

8172 Swap set-point

Initiate optimising The improvement in nominal power must be betterthan this setpoint to initiate fuel optimising

8173 Delay Time delay Optimal combination must be present during this peri-od, before optimising is initiated

8174 Hour Running hours Maximum allowed difference in running hours

8175 Enable Activate runninghours

Activates the dependency of the running hours

The function is best described with an example. Below an example with three DGs is shown.

DG1 = 1000 kW DG2 = 1000 kW DG3 = 500 kW

Settings used in the fuel optimising function in this example:

8011 Load-dependent stop = 220 kW (extended with 10% in this function) 8171 Setpoint = 100% 8172 Swap percentage = 200 kW

Situation 1:The two 1000 kW gensets must operate. The load is too big for one 1000 kW and one 500 kW genset.

Situation 2:Since the load has decreased to 1400 kW, it would be enough with one 1000 kW and one 500 kW genset.The improvement is 500 kW which is better than 200 kW (menu 8172). The problem is that only 100 kWwould be available. The load-dependent stop requires 220 kW available, so no swapping can take place.

Situation 3:Now the load has decreased to 1300 kW. It would be enough with one 1000 kW and one 500 kW genset. Theimprovement is 500 kW which is better than 200 kW (menu 8172). The problem is that only 200 kW would beavailable. The load-dependent stop requires 220 kW available, so no swapping can take place.

Situation 4:Now the load has decreased to 1200 kW. It would be enough with one 1000 kW and one 500 kW genset. Theimprovement is 500 kW which is better than 200 kW (menu 8172). This means that 300 kW would be availa-ble, so the load-dependent stop does not interfere with the fuel optimising.

Fuel optimising is initiated!

Situation 5:Now DG3 has been started and is running with 400 kW. This is the best combination at this time, and noswapping takes place with this load.



The setpoint (menu 8171) in percent is typically set to 80-85% for optimum fuel economy.

Running hoursIt is possible to combine the fuel optimising with the running hours. This is enabled in menu 8175. If this set-ting is OFF the fuel optimising will be active, but the running hours will not be included in the calculation.

If the function "running hours" is enabled, the principle is the following: If one genset reaches the adjustedamount of running hours, it will be given quarantine. This means that it will just rest until it has the lowestnumber of running hours. The only exception to this is if there is no alternative combination. Then it will beused but will still be in quarantine.



12.30 Power management functions, Conditional connection of heavy consumers

Each diesel generator unit is able to handle two heavy consumers (HC). When a heavy consumer is reques-ted, the function for conditional connection of heavy consumers reserves the programmed HC requested val-ue (parameter 8201/8211) on the busbar and blocks for engagement of the heavy consumer, until sufficientpredicted available power is present at the busbar.

Time

1 Request HC

2 Connect DG2

3 Acknowledge HC

-200

-100

0

100

200

300

400

500

kW

-250

-125

0

125

250

375

500

625

kVA

1

DG2 start

delayHC running

2 3 4 5

HC ackn

delay

DG2 stop

delay

700 kwAvailable power on busbar

Disable request HC

Disconnect DG2

4

5

HC request value: 375 kVA

HC nominal load: 150 kW

DG nominal power: 500 kW

Cos phi: 0.8

Load-dep. start value 90%

Load-dep. stop value 70%

HC request

value

Consumed power

Available power

When the available power is above the requested HC power, the heavy consumer is subsequently blockeduntil the programmed HC acknowledge delay runs out (fixed delay of 4 sec.).

The "DELAY ACK. HC" may be necessary in order to allow the recently started generator set to take load andthus actually increase the available power at the busbar before engagement of the HC.

The heavy consumers (HC) are connected according to their priority. This means that if two or more heavyconsumers request start acknowledgement at the same time, the HC with the highest priority is handled first,and subsequently HCs with lower priority, etc.

HC 1.1 (1st HC in DG unit with CAN ID no. 1) is designated the highest priority. This means that HC 1.1 ishandled before HC 1.2, and HC 2.1 is handled before HC 2.2 if they are requested for start at the same time.If there are any preferential HCs, they must be connected to the hardware interface for the 1st HC in order toensure first priority handling.



The power management system carries out the following systematic sequence when a heavy consumer isrequested for start:

a) The programmed "HC n REQ. VALUE" is reserved at the busbar (parameter 8201/8211).b) A PMS start command is transmitted to the next stand-by generator set if the predicted available pow-

er is below the programmed "LOAD START LIMIT".c) When sufficient available power is present at the busbar, the timer "DELAY ACK. HC n" starts running

(fixed delay time of 4 sec.).d) The start acknowledge signal is transmitted to the HC in question when the timer "DELAY ACK. HC n"

runs out and sufficient available power is still measured at the busbar.e) The nominal HC power value (parameter 8202/8212) is used for load-dependent start/stop calculation

after the acknowledge signal is given.

12.30.1 Power feedback from the heavy consumerThe AGC is able to handle two types of power feedback:

Binary feedback Analogue feedback

The two types of power feedback signals are handled the same way by the conditional connection of heavyconsumers function.

Changing the power feedback type is done by a parameter (8203/8213) in each generator unit.

Activating the corresponding start request binary input activates the HC engagement sequence. The AGCsystem transmits a start acknowledge signal when sufficient predicted available power is present at the bus-bar.

HC with binary power feedback signal:

188 kVA

150 kW

P-avail. OK

Time

0 kVA

Nom. power HC 1

300 kW

Power reservation

at the busbar

"Delay ACK. HC1"

Start acknowledge HC1

HC 1 fixed load

375 kVAStart request HC 1



12.30.2 Engagement sequence for HCs with fixed loadThe power reservation by means of the feedback "HCx fixed load" input is enabled as long as the start re-quest signal is active. An OFF status (indicates that the HC is not operating) of the power feedback signalresults in a 100% power reservation at the busbar. An ON status (indicates that the HC is operating) at thepower feedback signal results in a 0% power reservation at the busbar.

HC with analogue power feedback signal:

P-avail.OK

Time

0 kVA

Nom. power HC 1

Request value 300 kW

Power reservation

at the busbar

25%

Start acknowledge HC1

HC 1 fixed load

4..20 mA

Start request HC 1

50%75%

100%

25%50%75%

100%

Nom.

power HC 1

The analogue power feedback for the heavy consumer is intended for a power transducer with a 4-20 mAoutput corresponding to 0-100% load. If the heavy consumer is of 400 kW, the power transducer has to becalibrated to 0-400 kW = 4-20 mA, and the setting has to be set for 400 kW.

12.31 Power management functions, Ground relay

The purpose of this function is to always let the star point of only one genset be connected to ground duringisland mode operation. The reason for this is to avoid circulating currents between the generators. The func-tion is adjusted in menu 8120.

The AGC which has the lowest CAN ID and where the generator breaker is closed will close its ground relay.Should this genset stop, it will open its ground relay when the generator breaker opens, and the ground relayof the generator which now has the lowest CAN ID closes its ground relay instead.

The number of available configurable relays is option-dependent. The relay for this function isselected in each AGC unit.



12.32 Power management functions, Stop of non-connected gensets

If peak shaving is selected and the imported power increases above the start setpoint, the genset(s) will start.If the load now drops below the start setpoint, it will remain disconnected from the busbar but will not stop,because the imported power is higher than the stop setpoint.

The function "stop of non-connected DGs" (menu 8140) will make sure that the gensets stop after the adjus-ted time.

In other modes, the generator will also be stopped if it is in automatic without the GB closed.

12.33 Power management functions, Secured mode

Secured mode adds an extra generator to the power management system. This means that one genset morethan calculated in load-dependent start will be running.

It is only possible to activate secured mode if the genset is in auto mode.

Secured mode can be activated/deactivated by means of digital inputs or via M-logic.

The extra generator running in secured mode will be selected, so it is possible to replace thelargest running generator if this should fail.

12.34 Power management functions, Base load

One genset unit in a power management system can be selected as running with base load (2952). This canbe done from the display unit, via M-logic or via a binary input. If the unit is selected to run with base load, thestatus message "FIXED POWER" will be indicated. The fixed power value can be adjusted with parameter2951.

If a generator runs in base load and the total load decreases to a point below the base load setpoint, the sys-tem will lower the fixed power setpoint. This is to prevent frequency control problems, as the generator run-ning in base load does not participate in the frequency control.

When the generator breaker is closed, the generator power will be increased to the fixed power setpoint.



If AVR control (option D1) is selected, the setpoint will be the adjusted power factor.

The unit selected for base load operation will automatically be set in SEMI-AUTO. Only onegenerator per independent busbar can run with base load.

The busbar has to be active with one or more DG units running, before the unit with the lowestID can activate base load.

Only one AGC unit at a time can run in base load. The unit with the lowest ID will be allowed torun in base load.

12.35 Power management functions, Asymmetric load sharing (LS)

When asymmetric LS is enabled in menu 8282, the "normal" G5 load sharing is deactivated in all AGC unitsin the system. The AGC units will then load share according to the asymmetric LS setpoint in menu 8281.

Example: Four DGs able to produce 2800 kW each as nominal power. Asymmetric LS setpoint = 90%. Loadon the busbar is 3030 kW.

The generator with priority 01 will start up first, taking 90% of the load = 2727 kW. The generator with priority02 will take the rest of the load = 303 kW.

DG 1 DG 2 DG 3 DG 4

303

90 %

2727

10 %

Total load on busbar = 3030 kW

kW

Loadshare

setpoint P01

Remaining

load P02

If the asymmetric LS setpoint in menu 8281 "kW value" is higher than the nominal power of thegenerators, the whole system will switch back to symmetric.

12.36 Power management functions, Tie breaker configuration

Some of the possible applications of the AGC with option G5 can be used with a tie breaker, i.e. a breakerconnected between the gensets and the load bus.

12.36.1 Tie breaker selectionIn menu 8191, the tie breaker can be selected ON (present) or OFF (not present).



12.36.2 Tie breaker controlIt can be selected whether the tie breaker should be open or closed when the generators are stopped. Thisdepends on the application and the auxiliaries. If auxiliary load is connected to the generator bus, the tiebreaker must be closed, but if no load is connected to the generator bus, then the tie breaker is often prefer-red to be open when the generators are stopped.

The tie breaker will open or close depending on the setting in the menu 8191 ("Tie breaker enable").

The tie breaker only opens or closes depending on the selection in menu 8191 and it is not de-pending on the selected mode whether it should open or close.

12.36.3 Tie breaker open pointIf the gensets are running parallel to mains and the mains breaker trips, e.g. due to a mains failure, it can benecessary to trip the tie breaker as well.

This depends on the total nominal power of the running gensets. If the gensets cannot supply the amount ofload which is adjusted in the "tie breaker open point" menu 8192, then the tie breaker will open. It will closeagain when the power capacity setpoint menu 8193 is reached.

This delay time can be used to trip non-essential load groups.

ExampleIn the example illustrated below it can be seen that the tie breaker will trip if DG1 or DG2 is connected to theload, because they are smaller than 510 kW. If DG1 and DG2 are running together, the tie breaker will alsotrip, because the total nominal power is still below 510 kW. If, however, DG3 is running alone or together withone of the two smaller DGs, then the tie breaker will not trip, because the total nominal power will be higherthan 510 kW.

DG 3 = 600 kW

DG 2 = 250 kW

DG 1 = 250 kW

Tie breaker open point = 510 kW

Trip No trip

The powers mentioned above are nominal powers of the gensets in the application.

12.36.4 Power capacityThe power capacity setting in menu 8193 is used in AMF applications to determine how much power must beavailable, before the tie breaker can close. When the gensets are started the generator breakers will close,and when sufficient power is available, then the tie breaker will be closed.



Power capacity overrule:In case some of the generators fail starting and the power capacity setpoint is not reached, the tie breaker willnever be closed. Because of this, it is possible to overrule the power capacity setpoint after a period of timeset in menu 8194. The function "power capacity overrule" is enabled in menu 8195.

12.37 Power management functions, Island application with TB

G


Controller

Display 3

G


Busbar

G


CANbus

Controller

Display 1

Controller

Display 2

Area 1

TB 17

Load

A tie breaker in the mains unit can be operated in an island application. It is controlled in the same way as inthe AMF situation described above. The power capacity setpoint menu 8193 is used to ensure that the gener-ators produce enough power to take the load. This is done to protect the generators from going into overload.



12.38 Power management functions, Multiple mains

The AGC can be used in an application with multiple mains incomers. This is an example of the multiplemains application:

CANbus

G


Controller

Display 1

TB 17

Load

MB 17

G


Busbar

Controller

Display 2

TB 18

Load

MB 18

G


Busbar

Controller

Display 5

TB 19

Load

MB 19

G


Controller

Display 3

Area 3

BTB 33

G


Controller

Display 4

BTB 34

Each application can handle:

0-16 mains feeders in the same application 0-16 gensets in the same application 8 bus tie breakers

The multiple mains functionality covers a great variety of different applications. Please contactDEIF support ([email protected]) for questions concerning the functionality.



12.38.1 DefinitionsA multiple mains application consists of feeders and generators + a number of GBs, TBs, BTBs and MBs.

SectionsThe application consists of static and dynamic sections if one or more BTBs are installed. The definition of asection is mentioned in the table below.

Section Definition

Static section Part of the total application which is separated by one or two open BTBs. There will be noclosed BTBs within this section.

A static section can also be a dynamic section, but not vice versa.

Dynamic sec-tion

Part of the total application which is separated by one or two open BTBs. There may beone or more closed BTBs within this section.



If no BTBs are installed, the application consists of a static section only.

Only use remote start signal in island application with BTB units.

CANbus

G


Busbar

Controller

Display 1

TB 17

Load

MB 17

G


Busbar

Controller

Display 3

TB 18

Load

MB 18

G


Controller

Display 2

Area 1

BTB 33 BTB 34

Static section:The BTB 33 is in open posi-tion. Therefore the indicatedsection is a static section.

Dynamic section:The section is separated by anopen BTB, so this is a dynamicsection.

CANbus

G


Busbar

Controller

Display 1

TB 17

Load

MB 17

G


Busbar

Controller

Display 3

TB 18

Load

MB 18

G


Controller

Display 2

BTB 33 BTB 34

Area 1 Dynamic section:The BTB 34 is in closed posi-tion. Therefore the indicatedsection is a dynamic section.



12.38.2 ConfigurationPlease select "Standard" in the plant configuration tool to configure this application.

Now the application can be configured using the section control panel.



12.38.3 Plant mode handlingBasically, six menus are available for setting up the functionality of the application.

No. Setting Min. setting Max. setting Factory setting

8181 MB failure start Enable OFF ON OFF

8182 Parallel Enable OFF ON OFF

8183 No break transfer Enable OFF ON OFF

8184 Auto switch Enable OFF Static Dynamic All OFF

8185 Run type Run one/all mains Run all mains Run one mains Run one mains

8186 Run type ID to run 17 32 17

MB close failure start:This setting determines whether a start of the DGs should be executed if an MB close failure occurs.

If "MB close failure start" is activated, the mode shift functionality will automatically be ena-bled.

In peak shaving, fixed power, mains power export and load takeover, the function is only activewhen menu 7081 Mode shift is set to ON.

MB parallel:This setting determines whether the mains connections (MBs) should be able to run in parallel or not.

The setting of "MB parallel" affects the function of the "Auto switch" setting.

No break transfer:This setting determines whether switching between the mains connections (MBs) should be executed as ablack coupling or a synchronised coupling.

If the TBs in a section are adjusted to normally closed and "MB parallel" is switched OFF, then only one of theTBs can be closed at the time.

The system will try to keep the ID selected in menu 8186 ("My ID to Run") to keep its TB closed. If, however,the selected ID does not have a TB configured as a normally closed breaker, or if it fails to close it, it will bethe mains unit holding the lowest ID without TB failures present that will close.

If "My ID to Run" is changed during operation, then the MB parallel setting will decide whether a black or asynchronised change-over will take place.

If "MB parallel" is activated, the "No break transfer" will automatically be enabled.

Auto switch:This setting determines whether a mains unit detecting a mains failure will try to get the connected load sup-plied by another mains or by the available DGs.



Description Section de-scription

OFF The auto switch functionality is switched OFF.

Static section The back-up power is recovered within its own static section. Page 69

Dynamic sec-tion

The back-up power is recovered within its own dynamic section.The application will never try to synchronise/close a BTB to get help in anAMF situation.

Page 69

All sections The back-up power is recovered within all available sections.

Sections are divided by bus tie breakers. If no BTBs are installed, then the settings static/dy-namic/all have the same auto switch function.

If dynamic is selected, then please be aware that one mains unit will be requested to carry allload from the dynamic section without any help from the DGs.

Therefore the remaining mains feeders must be able to carry the load from the entire section.

Run type:This setting determines how the system in a dynamic section reacts in all the plant modes except island andAMF.

Description Comment

Run onemains

Only one mains breaker is al-lowed to be closed at thetime.

"My ID to Run" (menu 8186) determines which mains feederis allowed to operate parallel to the mains.

If other TBs are closed, they will be tripped in order to onlyhave the TB of "My ID to Run" closed.

If no TB is available in the section, the MB will be tripped(causing a blackout).

Run allmains

All mains breakers are al-lowed to be closed at thetime.

This setting can be handled from M-logic.

12.39 Power management functions, Dual mains

If the AGCs are configured with two mains units, the settings for the dual mains application must be adjusted.



12.39.1 ConfigurationPlease select "Dual mains" in the plant configurator tool to configure this application.



12.39.2 Plant mode handlingThis is an illustration of the dual mains application.

Four additional settings have been specified to determine the behaviour of the system. The settings are to beset in one of the AGC mains units and are then communicated via the CANbus to the other mains unit. Thefour additional settings in menu 8180 are:



Description Dual mains relevance

8181 MB close failure start X

8182 MB parallel X

8183 No break transfer X

8184 Auto switch X

8185 Run one/all mains Not relevant

8186 ID to run Not relevant

The menus 8185 and 8186 are ignored in the dual mains application.

MB close failure start:This setting determines whether a start of the DGs should be executed if an MB close failure occurs.

If "MB close failure start" is activated, the mode shift functionality will automatically be ena-bled.

In peak shaving, fixed power, mains power export and load takeover, the function is only activewhen menu 7081 Mode shift is set to ON.

MB parallel:This setting determines whether the two mains connections (MBs) should be able to run in parallel or not.

The setting of "MB parallel" affects the function of the "Auto switch" setting.

No break transfer:This setting determines whether a priority switch between the two mains connections (MBs) should be execu-ted as a black coupling or a synchronised coupling.

If "MB parallel" is activated, the "No break transfer" will automatically be enabled.

1st priority mains:The configurable input "1st priority mains" determines which of the mains connections to consider the first pri-ority. The binary input must be configured via the PC utility software (USW). The priority of the mains connec-tions can then be altered by switching the input status on the AGC mains units.



The "1st priority" input has to be active on one of the mains units at all times.

Auto switch:

MB parallel OFF:- If "Auto switch" is ON, an attempt will be made to switch to the 2nd priority mains if a mains failure

occurs on the 1st priority mains before the generators are started.- If "Auto switch" is OFF, no attempt will be made to switch to the 2nd priority in case of a mains

failure.

MB parallel ON:- If "Auto switch" is OFF, the two mains will act as one meaning that both mains breakers have to be

closed at all times, since one mains connection is not enough to supply the load. A mains failureon either of the mains will cause a trip of both mains breakers and subsequently start of the gen-sets.

- If "Auto switch" is ON, both mains breakers will be closed in case both mains are OK. If a mainsfailure occurs on one of the mains, the mains breaker in question will be tripped, but an AMF startof the gensets will only happen when a mains failure is present on both mains.

If "Auto switch" is enabled (ON), mode shift (menu 7081) must also be enabled (ON).

12.39.3 Internal CAN IDThe internal CAN ID for the AGC mains units can be set between 17 and 32 when multiple mains has beenselected (otherwise the system only expects one mains and the ID is set to 17 as default). The selection ofthe CAN ID cannot be made randomly but must be made with caution. The reason for this is that the systemexpects ID 17 and ID 18 as a couple controlling the mains breaker for one mains connection, i.e. the ID 18unit acts as a redundant unit to ID 17. In the same manner, the system expects ID 19 and ID 20 as a couplecontrolling the mains breaker for one mains connection, i.e. the ID 20 unit acts as a redundant unit to ID 19.This means that when no redundant mains units are present, the ID selected for the two AGC mains unitsmust be ID 17 and 19.

Setting of the CAN ID in multiple mains applications:

AGC mains unit ID no. Comment

1A 17 Required

1B 18 Not required, redundant to 1A

2A 19 Required

2B 20 Not required, redundant to 2A

Please refer to the drawing above for the location of the AGC mains units.

12.39.4 AGC mains unit redundancyIt is possible to install a redundant AGC mains unit for each mains connection. If this is done, the redundantAGC mains unit will automatically take control if:



a mains breaker failure occurs on the primary control unit the primary control unit is suddenly missing on the CAN line due to a CAN error the primary control unit is put into semi-auto

When the alarm situation on the primary control unit has been reset, the control is switched back to this AGCmains unit.

The primary control units are ID 17 and ID 19.

Be aware that if "ID to run" is active, the mains unit to run must have higher nominal powerthan the load on the busbar to prevent overload.

The redundant controller is selected in the configuration window (section control).

12.39.5 Tie breaker configurationIn applications with two mains connections, the tie breaker is handled by the AGC mains unit fulfilling the fol-lowing conditions:

Holding the lowest CAN ID No tie breaker error Not in semi-auto

If the AGC mains unit controlling the tie breaker is not able to open the tie breaker, the tie breaker handling ismoved to the next AGC mains unit fulfilling the conditions above. This will continue until the tie breaker isopened or all the AGC mains units have tried to open the tie breaker.

Because of the AC wiring it is not possible to synchronise the tie breaker in applications sup-porting two mains connections.



12.40 Power management functions, Configurable CAN IDs

Can IDs can be configured as desired, as a mix of DG, mains and BTB units:

16 gensets IDs 1-1616 mains IDs 17-328 bus tie breakers IDs 33-40

This makes a total of 40 CAN IDs.

12.41 Power management functions, CAN flags

16 CAN flags can be accessed in M-logic. They can be used in the same way as digital inputs. CAN flags canbe set active when a CAN command is sent from one unit to another. The benefit is that no wire is needed, asthe CAN flags are activated via the G5 CANbus.



Example: CAN cmd 01 will be active when DG 5 is running. All units in the power management system willreceive "CAN input 01 active" and then be able to act on this information.

Only use of constant signals from digital inputs or AOP buttons can activate the CAN inputs.AOP buttons are pulse inputs, so a latch function must be made to make similar functionalityas constant signals.

12.42 Power management functions, Common PF control

A common PF value can be set in menu 7052, and menu 7053 can be set to either "Inductive" or "Capaci-tive". To activate the common PF control, menu 7054 must be enabled. These setpoints can only be handledfrom the AGC mains unit and then sent through the power management CANbus to all the DG units in thesystem. The DG units will then adjust their individual PF control according to the received setpoint.

Inductive/capacitive setpoints can be set up from M-logic.



12.43 Parameter lists, Common settings

The options G4 and G5 relate to the parameters 2250, 2260, 2270, 2761, 2950, 6071, 6400, 7011-7014,7041-7044, 7051-7054, 7061-7084, 7531-7536, 7871-7873, 8000-8120, 8170-8175, 8181-8195, 8201-8213,8220-8225, 8230-8272, 8280-8282, 8880-8882, 9160, 9170, 9180-9186, 9190-9192.

For further information, please see the separate parameter list:





13. Plant management13.1 Description of option, Option G7

The option G7, Plant Management, is a combined software and hardware option. It is a HW option becauseone of the used controller types communicates with the plant control system as well as with the belonginggenerators and then it uses an additional CAN port.

Plant management is only used in the AGC-4 product line.

13.2 Functional description, Plant management

What is DEIF plant management?DEIF plant management is an option in the AGC-4 controller that gives a number of possibilities for increasedand optimised performance, typically of large-scale power plants but also for power plants (critical power orpower producing) in a smaller scale.

The number of supported generators in the system is from 1 to 256 DGs per plant. If more generators areneeded, please contact your DEIF office for the solution. DEIF plant management is typically used on rentalor stationary power plants with the purpose of exporting power to the mains. The plant will operate base-loa-ded, alternatively supplying the mains in islanded mode of operation. The main control of the plant is per-formed from the central AGC control unit. The start and stop of the plant is controlled from this unit, and acti-vation and control of voltage and frequency support as well as MW and PF control setpoints are adjustedhere.

The generators can be controlled from the central point of control, or, depending on system architecture, theycan be controlled in groups from 1 to 16 DGs. DEIF plant management offers the possibility to control an ex-tra level of breakers compared to traditional DEIF power management systems. This will be explained furtherin this manual.

All breakers in the system can be synchronised. The system can also be configured with a reduced numberof breakers according to applicational demands.

AGC-4 manual, November 2011, UK Plant management


13.2.1 Unit definitionsThe AGCs used in the plant management system are shown in the table below.

AGC type Layout Required options

DGAutomatic Gen-set Controller

multi-line AGC

VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

MODE

JUMP

START

INFO

STOP

Alarm

Alarm

OnRun

G

Load

Y1

G7

Group(AGC Mains) Automatic Gen-set Controller


VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

On

INFO

JUMP

Alarm

Alarm

MODE

Y5

G7

Plant(AGC Mains) Automatic Gen-set Controller

VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

MODE

JUMP

START

INFO

STOP

Alarm

Alarm

multi-line AGC MAINS

On On

Load

Y4

G7

BTBAutomatic Gen-set Controller


VIEW

LOG

Auto

Alarm Inh.

Self check ok

Power

SEL

BACK

On

INFO

JUMP

Alarm

Alarm

MODE

Y5

G7

All other options can be selected by choice and availability.

Notice that the term "group" refers to a group of generators. The generators are referred to as generators orDGs.

Unit plant roleHere you will find a short description of the role the individual controller plays in the power plant.

DG: the DG unit controls a generator and the associated generator breaker. It will start the generator andsynchronise the generator breaker. When the breaker closes, it will control the set according to the load levelwhen load sharing with other gensets (island mode) or according to the kW reference from the plant unit. Thepower factor can be controlled individually from the group unit or from the plant unit.

The kW setpoint cannot be controlled individually on each genset when working as a part ofthe plant management system. However, it is possible to remove the individual AGC DG fromthe plant management and then operate it in a single fixed power mode. This would be e.g. forservice purposes.



Group unit: the group handler has two main purposes. One purpose is that it is the plant management linkbetween the plant unit and the genset controllers, i.e. it is connected to two CAN networks, "genset group"and "genset group plant". The other main purpose is that it controls the tie breaker of the group handler ifsuch is installed.

Plant unit: this is the main control device of the plant; setpoints, start/stop commands and plant modes areselected from here.

BTB unit: the bus tie breaker unit can be placed on the generators busses like in the traditional power man-agement system, or it can be placed between the mains feeders.

13.2.2 ApplicationsThe plant management functionality of the AGC makes it possible to build applications with many DGs. Themaximum number of AGC units in one plant is mentioned in this table:

Unit type Available number (total)

DG 1-256

Group 1-16

Plant 0-16

BTB (plant level) 0-8

BTB (group level) (0-16)*8

BreakersEach unit in the plant is able to synchronise and control one breaker. The DG and BTB units are always as-signed to one breaker (it is not possible to install an AGC DG or an AGC BTB without a breaker beingpresent). Notice that the AGC BTB can be drawn in the single line diagram, but that it can be externally con-trolled. In this case it is not necessary to install AGC BTBs, but the configuration of the application ("applica-tion configuration") has to be correct and include the externally controlled bus tie breaker.



Example of an application with three group units and one mains feeder. The mains feeder does not have abreaker to be controlled in this application.

Plant management levels

Genset group plantThe plant management application is split up in two levels, i.e. plant level and genset level.

The plant level (known as "Genset group plant" in the PC utility software) consists of mains feeders, mainsbreaker and tie breakers. Plant level bus tie breakers can also be installed.

The table shows which unit controls which part of the application:

Part of application Controlled by Available numbers

Mains feeder Plant 16

Mains breaker control Plant 16

Group feeder Group 16

Tie breaker control Group 16

Plant level BTB BTB 8



Overview plant level:A typical application (on "Genset group plant" level) could for instance look like this:

On genset group PLANT level, the following controllers are needed for this application:1 AGC Mains, plant unit4 AGC Mains, group units

Genset groupThe genset level (known as "Genset group" in the PC utility software) consists of one tie feeder and tie break-er and the number of DGs available in the group. Genset level bus tie breakers are also available.

The table shows which unit controls which part of the application:

Part of application Controlled by Available numbers

Tie feeder Group 1

Tie breaker Group 1

Diesel generator DG AGC 16

Generator breaker DG AGC 16

Genset level BTB BTB 8



Overview genset group level:A typical application (on "genset group" level) could for instance look like this:

On GENSET group level, the following controllers are needed for this application:1 AGC Mains, group unit10 AGC DG controllers

Plant overviewKnowing the possibilities with the number of controllers available for the system, the complete system can beput together (example 8 DGs, 2 groups and 2 mains feeders):



CANbus IDsEach AGC unit in the system has a dedicated ID number. However, it must be noted that the group handlershave an ID number for the genset group PLANT level and one for the genset group level.

ID number assignment:

CANbus network AGC unit type ID number Menu number

Genset network DG 1-16 7531

BTB 33-40 7531

GROUP 17-32 7531

Plant network GROUP 1-16 7540

PLANT 17-32 7531

BTB 33-40 7531

Notice that the group unit exists on both CANbus networks, i.e. the plant network and the genset network.

13.3 Functional description, Plant mode descriptions

Plant mode descriptionsThe plant management system supports the following plant modes:

Island mode (Island)Power plant with synchronising generators or a stand-alone generator. Can also be used in critical powerplants.

Automatic mains failure (AMF)Critical power/emergency standby plants, black start generator.

Peak shaving (Peak shaving)Power plant where generator supplies peak load demand paralleled to the mains.

Fixed power (FP)Power plant with fixed kW setpoint (including building load).

Mains power export (MPE)Power plant with fixed kW setpoint (excluding building load).

Load takeover (LTO)Plant mode where the load is moved from mains to generator, e.g. peak demand periods or periods withrisk of power outages.

A plant mode defines the method of operation of the plant, and it is adjusted in the plant unit (menu 6071) ifsuch is present. In island mode the plant unit is not needed - only in all other modes.

Using the supported modes, the plant will run with the gensets paralleled to the mains or islanded if they per-form their intended scheme of operation in full AUTO mode. This is shown in the table:

Parallel to mains Islanded

FP Island mode

Peak shaving AMF

MPE LTO



The functionality of the plant modes is described in the "Designer's Refence Handbook" (in which it is referredto as "genset mode")

Group interactionThere is no interaction between the groups, except that they start and stop at the "start/stop" limit adjusted inthe group units. The start and stop limit is using the setpoint of asymmetrical LS (menu 8281). This meansthat functions such as CAN flags, heavy consumers and ground relay are working inside the individual group,and they do not cross groups.

See separate chapter about the use of CAN flags.

Starting and stopping of the plantThe starting and stopping of the plant is driven either automatically or by a start/stop signal:

AMF and peak shaving are the only two modes that start/stop automatically. The start/stop is system-depend-ent, meaning that a loss of mains or mains failure will initiate the AMF operation, and an increase/decrease inimported load will initiate starting and stopping in peak shaving.

The modes Island, MPE, LTO and FP all require a start signal. This can be given from the display unit, digitalinput or communication, i.e. Modbus or Profibus. The start signal is called "AUTO Start/Stop". This signal hasto be given on the plant unit. If the plant management system is without plant units (island mode plant), thenthe "AUTO Start/Stop" has to be given on the group units.

Example of setting up AUTO start/stop in the plant unit using digital input terminal 23. The plant mode isMPE.

When the plant is started using the display unit, the setting of menu 8021 has to be "LOCAL".When the plant is started from the digital inputs or SCADA, the setting of menu 8021 has to be"REMOTE". This is adjusted in the plant unit, or, if the plant unit is not installed (island modeplant management applications only), in the group units. The setting of LOCAL/REMOTE is ashared setpoint between the group units.

Island mode, plant managementIn island mode the plant is running with the feature of load-dependent start/stop active. This means that thegroups will be started and stopped based on the load demand. (LD start/stop is also active inside the individu-al groups).



When the plant is started, one group with the first priority (P01) will start and connect its tie breaker. The num-ber of gensets that will start in the group depends on the power capacity setpoint (the menu number is 8192)in the group unit and the multi-start setpoints of the DG units (the menu number is 8920).

If the power capacity of the group units varies, make sure that the first priority group (P01) is able to carry theload.

Mains parallel, plant managementDuring mains parallel, the plant is running with the feature of load-dependent start and stop. The setpoint iscoming from the plant unit which is always there in //-mains applications, so depending on the kW/MW set-point, the right number of groups is requested.

The load-dependent starting and stopping of other groups is using the asymmetrical LS setpoint (see descrip-tion of asymmetrical load sharing).

When operating paralleled to the mains, the cos phi setpoint can be adjusted on the plant unit, the individualgroup unit, the individual DG controllers or a combination of those. See description of cos phi control.

PLANT mode remarksSome plant modes vary from the traditional plant modes, or some useful remarks are mentioned in this chap-ter.

Fixed power remarks.It is observed that the fixed power mode can be used with BTBs in the genset group levels. Normally, this isnot possible in an AGC power management system where the AGC Mains in an FP mode cannot requestDGs in another dynamic section than its own.

Due to the design of the plant management system, the BTBs can be requested even though they are part ofanother dynamic section than the group controller. (A dynamic section is separated by opened BTBs. In thediagram below there are three dynamic sections when the two BTBs are opened, two dynamic sections whenone BTB closes and one dynamic section when both BTBs are closed).



Example of FP application where the plant controllers are able to request the DGs.

Mains power export remarksMPE mode maintains the MW setpoint measured at the plant controller. This means that if auxiliaries insidethe plant consume variable power, the power setpoint is still maintained. This could be cooling fans, pumps -any load connected inside the plant. Notice that the difference between FP and MPE is that in FP mode, thepower setpoint is maintained at the generator side instead of at the plant controller side as in MPE. So with a30 MW setpoint/1 MW auxiliaries, the generators would produce 31 MW in MPE mode in order to dispatch 30MW, and in FP mode they would produce 30 MW and 29 MW would be dispatched to the grid.

The same observation can be made about the cos phi setpoint. The generators will adjust their setpoint sothe total cos phi is maintained at the plant controller side. This must be enabled in the menu 7054 (selectsuperior setpoint) in all controllers, including DG and group controller. See description of cos phi control.

Notice that MPE mode requires the use of CTs or a mains power transducer on the plant controller. The CTsmust be connected, so the sign of the power is negative when exporting to the grid and positive when import-ing from the grid (e.g. peak shaving applications). It is not required on the group controllers, but it is possible.

Knowing that the displayed value of the exported power is negative, it is necessary to point out that the set-point (menu 7001/7002 (day setting/night setting)) can be adjusted negative or positive; the negative value isimported and the positive is exported. So it is the contrary of the displayed.

Peak shaving remarks.Notice that peak shaving mode requires the use of CTs or a mains power transducer on the plant controller.The CTs must be connected, so the sign of the power is negative when exporting to the grid (e.g. MPE appli-cations) and positive when importing from the grid. It is not required on the group controllers, but it is possi-ble.



13.4 Functional description, Plant management functions

13.4.1 Group controller start and stopGroup start and stopThe genset group PLANT consists of individual genset groups. In the individual genset group, traditional pow-er management is operating - i.a. load-dependent start/stop of the gensets based on percentage or availablepower (selected in menu 8882). If the load in a group increases, the group controller will be able to requestanother group (other groups). A group controller can request groups but not generators in another group. Thismeans that the priority settings in the specific groups are respected.

Next group startThe next available group will start when the setting of asymmetrical LS on the group controller level isreached on the groups that are running. This menu is adjusted in one of the group controllers in menu 8281.It is a shared setpoint so it is only necessary to adjust it in one (any) group controller. The factory setting is80%.

If the PLANT is in operation and the group with first priority (P01) is in operation, the group with second priori-ty (P02) will start when the first priority group reaches the asymmetrical LS setpoint. (Factory set = 80%).There is a timer that must expire before the next group starts. This timer is adjusted in the group controller inthe menu number 8001 (shared setting, so it can be adjusted in any of the group controllers). If the asymmet-rical LS setpoint is lower than the LD start setpoint of the generators, then DG(s) in the next group will startbefore all generators in the first group are running. To avoid this, the asymmetrical LS setpoint on group levelmust be higher than the LD start setpoint of the generators.

This setpoint of asymmetrical LS has two functions; one is to be the actual asymmetrical LSsetpoint if this is enabled on group controller level, and the other is to act as a setting of whento start/stop the groups. The latter is what is described in this chapter.

Example:

Two groups of 10 DGs exist in a plant. Each DG is 1000 kW LD start setpoint is 90% All 20 DGs are ready and in full AUTO Asymmetrical LS setpoint = 80%

If one group is running with nine generators and the load has increased to 80% (0.8*10*1000 = 8000 kW),then the next group (group 2) is requested and one or several sets will start. If e.g. the load is 8100 kW (90%load on all nine generators), then group 1 will run with nine DGs and group 2 will run with one DG. The loadon each DG will be 8100/10 = 810 kW.

The value of the scale (setting 8006 – DG) must be equal in all groups because it is used for thenext group start routine.

It is preferred to adjust the timer of the LD start of the group higher than the LD start timer in the generatorgroup.



Next group stopThe groups will be stopped according to the load demand. The setting of asymmetrical LS is used to decidewhen to stop a group. So the asymmetrical LS setpoint is used to request groups (described in previouschapter) and to shut down groups. There is a timer used for the group load-dependent stop function. This isadjusted in a group controller in menu 8011 (shared setpoint so it can be adjusted in any of the group control-lers).

Example:

Two groups of 10 DGs exist in a plant. Each DG is 1000 kW 11 DGs are running and they are sharing 8100 kW Asymmetrical LS setpoint = 80%

This is the present situation: if the second group was stopped, the first group would have to carry this load(8100 kW). This is above the start setpoint (see description of next group start), so the second group contin-ues to be in operation.

If the load decreases below 8000 kW (e.g. to 7900 kW), the group load-dependent stop timer starts countingand the second group is stopped. The reason is that the group load of the first group ends below the groupstart setpoint: 7900*100/(10*1000) = 79%. The second group stops the generator that it has in operation.

It is preferred to adjust the timer of the LD stop of the group higher than the LD stop timer in the generatorgroup.

13.4.2 Power reference scalingThe AGC-4 uses scaling of some of the settings. The purpose of this is to make it possible or easier to adjustsome of the setpoints.

If e.g. a scaling of 1:100 is used and the kW/MW reference is 400 kW, the actual kW setpoint is [400 x 100 =40000 kW/40 MW].

Scaling is used in the following parameters:

Mode Menu Power reference Instruction

FP 7055 plant unit 7051

TEST mode (load test) 7055 plant unit 7041

Peak shaving 7005 plant unit 7001/7002

MPE 7005 plant unit 7001/7002

LD start and stop 8006 DG controller 8001/8011 This must be equal in all DGs

13.4.3 Cos phi-controlled exportThe AGC is capable of controlling the cos phi at the mains breaker side with a common setpoint. This is use-ful for power plants with requirements of importing or exporting power at a certain cos phi, e.g. in mains pow-er export mode (MPE). The function can be used in all parallel to mains modes, though.

If the reactive load of the power plant is variable, the cos phi at the mains side would become variable too ifthe generators operate at a fixed cos phi setting. In order to prevent the varying cos phi, the fixed cos phisetpoint can be enabled in the mains unit.

Three settings exist, and their function is shown in this table:



AGC Mains se-lection

Used cos phi Comment

OFF Individual DG setpoint isused

Fixed for DGs All DGs Fixed PF setpoint regardless of the load.

Fixed for import/export

All DGs receive the set-point from the mains

This set is aiming to maintain the PF imported or exportedto/from the mains, taking the reactive load of the plant intoconsideration.

Superior Uses setpoint from a con-troller on a higher level

If the plant unit has a setting of "fixed for imp/exp" and thegroup and DG units have the setting of superior, the DGswill respond to the setpoint sent from the AGC plant unit.

In multi-mains systems with mains feeders paralleled, it is the AGC plant unit with "My ID toRun" that contains the setpoint.

Sign of cos phiAn important difference between “Fixed for DG” and “Fixed for import/export” is the sign of the cos phi. This isdifferent because when power is exported to the mains, the power is shown as a negative reading in the dis-play unit. If the power is imported, the power is shown as a positive reading. When the power reading is neg-ative, the mains unit will display a capacitive reading when the generators are running with an inductive cosphi, and the setpoint in the mains unit must be a capacitive setpoint.

A table describes the difference between inductive and capacitive setting:

Exporting power to the mains

Inductive setpoint Capacitive setpoint

Fixed for DGs The generators operate with inductive PF The generators operate with capacitive PF

Fixed for import/export

The generators operate with capacitivePF

The generators operate with inductive PF

The settings minimum and maximum cos phi are not cancelled! Factory settings are 0.8/induc-tive...1.0/inductive. So with the factory settings the DGs are never brought to operate underex-cited.

M-logicNotice that the reference can be switched using the M-logic commands between inductive and capacitive ref-erence.



Plant management considerations:In plant management systems, the common cos phi control is a cooperation between the plant controller andthe group controller. Three levels of cos phi settings are available:

1. On plant level2. On group level3. On DG level

The cos phi setpoint of the DGs can be overridden by the group unit and the plant unit. The cos phi setpointof the group unit can be overridden by the plant unit.

The table below presents an overview of the cos phi reference unit type and menu:

DG unit Group unit Plant unit DG unit Group unit Plant unit

OFF OFF OFF X (7051)

Superior Fixed for DG OFF X (7052)

Superior Fixed for imp/exp OFF X (7052)

OFF OFF Fixed for DG X (7051)

OFF OFF Fixed for imp/exp X (7051)

Superior Superior Fixed for DG X (7052)

Superior Superior Fixed for imp/exp X (7052)

Notice the difference between fixed for DG and fixed for import/export in the begining of this chapter.

Display viewNotice that it is possible to select the cos phi reference in the display lines of the AGC. This is useful to verifythe setpoint of the generators with a given reference adjusted in the AGC Mains (group or plant unit).



Notice that the measured cos phi of the generators and the mains are different due to the reactive load of theplant.

13.4.4 Voltage supportDEIF plant management has the voltage support function also referred to as “Voltage-dependent PF/Q con-trol (y2(x2) droop)”. The function changes the cos phi or the kVAr setpoint of the generators if the mains volt-age changes beyond certain values in order to suport the mains voltage. The idea is that if the mains voltagedrops, the generators increase their excitation and support the mains voltage. If the mains voltage increases,the excitation of the DGs decreases in order to produce a smaller amount of VAr.

This function is used when the generators are paralleling to the mains. It cannot be used in island mode appli-cations.

Functional descriptionThe diagram below shows the principle. The dotted line illustrates the x-axis (voltage deviation), and the verti-cal line (PF) is the y-axis. The cos phi setpoint is 0.90 in this example, but the voltage support works aroundany setpoint that is adjusted.



(Unom-Uact)*100/Uact [%]

MIN

COS PHI

DBH

0%1%2%3%4% 1% 2% 3% 4% 5%5%

Power Factor Set point

6%7%8%9%10% 6% 7% 8% 9% 10%

SH

0.6 C

DBL

SL

0.6 l

MAX

0.9 I

The diagram illustrates the following areas:

Zone Voltage Cos phi Menu

Minimum cos phi

Limit

90-96% Min. limit 7171

Decreasing slope

Low

96-98% Sloping 7175

Dead band 98-102% 0.90 7151-7152

Increasing slope

High

102-104% Sloping 7176

Maximum cos phiLimit

104-110% Max. limit 7173



ParametersThe above diagram is configured with the following parameter settings:


7052 0.9 Power factor Power factor setpoint 0.6-1.

7053 Inductive Power factor Inductive/capacitive.

7151 2.00 DBL [%] Dead band low in percentage of nominal X2.

7152 2.00 DBH [%] Dead band high in percentage of nominal X2.

7153 1.00 HYSL [%] Hysteresis low in percentage of nominal X2. If HYSL is set above DBL,the hysteresis low is disabled. (Not shown in the diagram).

7154 1.00 HYSH [%] Hysteresis high in percentage of nominal X2. If HYSH is set above DBH,the hysteresis high is disabled. (Not shown in the diagram).

7171 0.8 MI Minimum output of droop handling. This setting is related to the settingin 7172.

7172 Inductive I/C Minimum output of droop handling.

7173 1.00 MA Maximum output of droop handling. This setting is related to the settingin 7174

7174 Inductive I/C Maximum output of droop handling.

7175 -0.05 SL [PF/%] Slope low. The setting determines the increase/decrease of PF refer-ence per percent the actual X2 drops below nominal X2.

7176 0.05 SH [PF/%] Slope high. The setting determines the increase/decrease of power ref-erence per percent the actual frequency rises above nominal frequency.

7181 PF(X2) Y2(X2) Output type for curve 2. Selections currently available “Reactive Power”and “PF”.

7182 U X2 Input type for curve 2. Selections currently available “Power” and “Volt-age”.

7183 ON ENA Enable/disable of curve 2.

HysteresisIn addition to the mentioned settings, a hysteresis can also be used. The function of the hysteresis is that thecos phi setpoint stays at the drooped value if the voltage returns towards nominal until the adjusted hysteresisis reached.

If e.g. the voltage drops, the cos phi setpoint follows the slope to e.g. 0.82. If the voltage now recovers, thecos phi setpoint stays at the mentioned 0.82 (in our example) until the voltage reaches 99%, and then itmoves back to our setpoint of 0.90. (1% is the setpoint of the hysteresis).

If the hysteresis is adjusted at a higher value than the dead band, it is not in effect. Therefore, if the hystere-sis is not used, please adjust it higher than the DB.

SlopeTwo settings for the slope are available, namely the "Slope Low" (SL) and the "Slope High" (SH). The nameof the settings refer to the voltage being lower or higher than the nominal voltage (100%). The slope is adjus-ted with a sign (positive or negative). The positive sign is the leading (capacitive) range, and the negative signis the lagging (inductive) range.

In order to explain when to adjust positive or negative sign, the following coordinate system is used.



When the requirement of the voltage support is known, it can be decided whether the slope is positive or neg-ative. This is best illustrated with an example:

If the voltage drops compared to the nominal voltage, the generator is requested to increase the excitationand thereby the produced kVArs (in order to support the grid). If the setpoint (SP) is 1.00 and a dead bandsetting is 1%, the cos phi setpoint will decrease from 1.00 to 0.90 (SL setting is -0.05).

SPNEW 388 VAC = 1.00 - ((396-388)/400*100) x 0.05 = 0.90 (simplified)

Capacitive rangeEven though the function is normally used to support a low mains voltage, it is possible to adjust the functionto decrease the excitation if the voltage increases (leading power factor).

To avoid pole slip and damage of the generators, make sure that the capability curve of thegenerators is respected and that the generators are not running underexcited or without excita-tion.



13.4.5 Priority routine, load profileThe purpose of the load-profiled priority routine is to make sure that the engines with the lowest recorded loadprofile are given highest priorities. The goals are several, but all focused on engine handling in order to in-crease the maintenance intervals and the lifetime of the engines. This priority routine gives a method of al-ways dedicating the highest priority status to the engines with the lowest recorded load profile. This is an al-ternative to the running hour-based priority routines; if the routine is changed only on an hourly basis, the ac-cumulated load scheme is not taken into account, only the running hours.

Different load profiles exist, and they are known as e.g. stand-by power, prime power, emergency stand-byand continuous power. Only three of those will be mentioned in this chapter. The engine is specified for aspecific use, and this must be respected. Some, but not all, load profiles can substitute each other accordingto engine manufacturer instructions. The AGC uses PNOMINAL setting 1 for calculations of the mentionedpriority routine.

This is a suggested setup if more or different nominal setpoints are being used:

Menu Suggested name Menu for configuration Comment

Pnominal SETTING 1 Stand-by power 6002 Load profile routine uses thisvalue

Pnominal SETTING 2 Prime power 6012

Pnominal SETTING 3 Continuous power 6022

Pnominal SETTING 4 Pnominal SETTING 4 6032

Be careful when changing the Pnominal SETTING 1 (menu 6002). If the value is changed, theload profile calculations are based on a wrong Pnom setpoint.

Pnominal SETTING 1 can be protected with master password (to be configured).

For a given engine (if supported by the same engine), the continuous power rating is smaller than the primepower rating, and the stand-by power rating would be larger than the prime power rating - see the examplebelow:

Rating Power Notes

Stand by rating 1600 kW Limitations in running conditions

Prime power rating 1400 kW Limitations in running conditions

Continuous power rating 1300 kW 24:7 operation is possible

Always follow the instructions of the engine builder!

If a job site involves two methods of operation, e.g. continuous power and prime power, then switching be-tween nominal setting 2 and 3 is used when operating in the requested selection. This is a way of keeping theload of the engine within the acceptable levels.

One example is to run the set in fixed power mode (continuous power) at 1300 kW and in island mode (primepower) at 1400 kW. This would then be achieved by switching between nominal setting 2 and 3.

Regardless of the operation, the calculation of the priority routine is always based on nominal setting 1.



CountersThe load profile counter can be read from the display unit using the configurable view function.

Load profile accumulationThis section explains how the load profile is being accumulated during islanded mode of operation. The priori-ty routine can be used in all plant modes, though.

If a power plant consists of two or several gensets and they operate as prime power machines in islandedoperation (ISLAND MODE), the sets operate according to the load demand in load sharing mode. The loadprofile will be logged and accumulated by the AGC. The priority routine is then switching the order of priorityof the engines depending on this logged load profile.

This simplified diagram shows that the running sets accumulate a load profile, but the stand-by set does not.This is indicated by the second arrow on the right hand side.



This means that since DG2 does not accumulate on its load profile during the entire period of operation, it willbe shifted to a higher priority at the next rearrange.

Priority rearrangeThe command to make a rearranging of the priority order is given automatically or manually. This is shown inthe table below:

Command Comment

MANUAL Activate the transmit function of the menu8086 in the DG unit.

Same command as used for MANUAL pri-ority routines.

AUTOMATIC Rearranges according to fixed time intervals. Also used for "RUN hour total" and "RUNhour trip" routines.

Plant management considerationsThe group units read the average load profile of the genset groups. This means that in the group handlers,the group priority can be controlled similar to the priority on the genset level, i.e. automatically based on "RunHours" (total/trip/load-profiled running hours) or manually based on user-programmed order of priority.

The following types of priority methods exist in the group units:

Running hours abs:The running hours (total, trip or load-profiled) of the DGs are used to rearrange the order of group priority ofthe group units (not the DGs). An average value of the group (depending on number of gensets) is used forthis rearranging, so the number of DGs in the group does not matter. This means that the order of group pri-ority is changed at hourly-based intervals (run hour setpoint) and no user intervention is required. The intervalis adjusted in hours in the menu 8111.

If a manual rearranging is necessary, this can be forced in the menu 8086 by selecting “manualupdate” even though "running hours" has been selected as the type of priority routine in menu8031.

Manual abs:If the required priority update is manual, the new order of priority is adjusted in the menus 8080-8090-8100,followed by the transmit order in menu 8086: "Manual update". If the manual priority routine is desired, but theorder of priority should be determined on the basis of the running hours (total, trip or load-profiled), this ispossible by selecting "Running hour update" in menu 8086 instead of "Manual update".



Operator-controlled rearrangingThe table below presents an overview of the different possibilities of making manual priority rearranging:

Type of priority routine Type of priority routine

Manual orderto rearrange

Manual Running hour

Manual update New routine is adjusted in menu8080/8090/8100.

This can be used to "override" the automatical-ly selected order of priority.

Run hour up-date

The average running hours from thegroup is used for the new order of pri-ority.

The average running hours from the group isused for the new order of priority. This can beused to advance the planned rotation of the or-der of priority.

Display viewsIn the group unit, the views related to prioritising can be selected:

13.4.6 Offset of setpointsPower offsetIn the AGC-4 it is possible to make a fixed setting of power and cos phi offsets. This means that the setpointscan be manipulated e.g. by the digital inputs, Modbus or other events.

The settings are adjusted in the menu group 7220 (7221-7226) for kW/MW reference and the menu group7240 (7241-7246) for cos phi reference.

A typical example of when the offsets could be used is when more mains feeders, tie breakers or consumersare connected. This table shows an example where the fixed power setpoint depends on the breakers A, Band C.



Fixed powersetpoint

Offset value ΣFixed powersetpoint

Comment

Breaker A connected 5 MW - 5 MW No offset activated

Breaker A and B connected 5 MW 5 MW 10 MW P offset 1 activated

Breaker A, B and C connected 5 MW 10 MW 15 MW P offset 2 activated

The offsets can be used one at a time or as a combination. This means that in the example above, the totalfixed power setpoint if Poffset 1 and 2 were both activated would be 5+5+10=20 MW. Notice that the setpointis the same, and it is independent of the use of offsets.

Used power setpoint = power setpoint + Σoffset(1:2:3)Used power setpoint = 7051 + (7221+7223+7225)

Cos phi offsetThree menus exist for offsetting the cos phi setpoint. This is an example where the offsets are controlled withdigital inputs:

Cos phi setpoint Offset value ΣCos phi setpoint Comment

No digital input 0.80 - 0.80 No offset activated

Digital input 112 0.80 0.10 0.90 Cos phi offset 1 activated



It is shown that the setpoint is the same when the offsets are activated. So the real cos phi setting will be:

Used cos phi setpoint = cos phi setpoint + Σoffset(1:2:3)Used cos phi setpoint = 7052 + (7241+7243+7245)

M-logicThe offsets can be activated and deactivated through M-logic. This way they can be activated depending onsystem conditions, SCADA commands or inputs. The screendump below is just one example.



13.4.7 Asymmetrical load sharingThe function of asymmetrical load sharing (asymmetrical LS) has the purpose of topping up the load of therunning engines to a certain percentage when the load is lower than the asymmetrical LS setpoint but not solow that the last priority genset will be stopped by the load-dependent stop function. If asymmetrical LS is notused, the load setpoint will be shared equally between the generators. If asymmetrical LS is used, the majori-ty of the generators will run at the asymmetrical LS setpoint, and the minority will run at a lower load.

The function is useful because the generators can be brought to operate at their optimal setpoint. Asymmetri-cal load sharing can be used on two levels; power management (inside the genset group) and plant manage-ment (genset group PLANT level).

Asymmetrical LS, genset groupThe asymmetrical LS function is best described with an example.

10 DGs available, each 1000 kW LD stop level is 70% LD start level is 90% Asymmetrical LS setpoint is 80%

If the load is 6400 kW, eight generators will be running at 80%. If the load increases to 7208 kW, the genera-tors run at 90.1%, meaning that another generator starts. Now nine DGs operate at [7208/9 = 801 kW], andsince the load factor is higher than the asymmetrical LS setpoint, the load will be shared equally.

With asymmetrical LS switched ON, the load will be shared asymmetrically between the LD stop setting andthe asymmetrical LS setpoint. In this example with nine sets running and the LD stop setting at 70%, theasymmetrical LS will happen between [LD STOP limit] and [ASYMM SP]: [(9-1) * 1000 * 0.7 = 5600 kW] and[9 * 1000 * 0.8 = 7200 kW].



Priority 7200 kW 6700 kW 6401 kW 6200 kW 5602 kW

DG1 P01 800 kW 800 kW 800 kW 800 kW 800 kW

DG2 P02 800 kW 800 kW 800 kW 800 kW 800 kW

DG3 P03 800 kW 800 kW 800 kW 800 kW 800 kW

DG4 P04 800 kW 800 kW 800 kW 800 kW 800 kW

DG5 P05 800 kW 800 kW 800 kW 800 kW 800 kW

DG6 P06 800 kW 800 kW 800 kW 800 kW 800 kW

DG7 P07 800 kW 800 kW 800 kW 800 kW 800 kW

DG8 P08 800 kW 800 kW 800 kW 300 kW 1 kW*

DG9 P09 800 kW 300 kW 1 kW* 300 kW 1 kW*

DG10 P10 0 kW (not run-ning)

0 kW (not run-ning)

0 kW (not run-ning)

0 kW (not run-ning)

0 kW (not run-ning)

*Actually the sets will run at the defined minimum load (adjusted in menu 8005).

It is shown in the table that one or more generators can be running asymmetrically, depending on the rangebetween LD stop and the asymmetrical setpoint.

It is affecting the fuel consumption if this function is used. Therefore the fuel consumptioncurves of the generators must be studied before using the function

The actual setpoint is a shared setpoint, so all generators will be using the same setpoint.

Asymmetrical LS, genset group PLANTThe asymmetrical load sharing can be used to bring the groups to run at a predefined load level. If the func-tion is enabled, the groups will be running at the asymmetrical LS setpoint. The last group will produce theremaining load, similar to the asymmetrical LS within the genset group.

13.5 Functional description, Plant management toolbox

13.5.1 CAN flags16 internal flags (binary states) can be raised and communicated throughout the plant. These can be used foruser-defined functions, e.g. common mode switching or change of nominal settings. Since the plant manage-ment consists of a genset group plant network and genset group networks, two levels of CAN flags exist inthe group handler.

The use of CAN flags is best illustrated with an example:

Change nominal setpoint from nominal setting 2 to nominal setting 3 (this could be the case when switchingfrom prime power to continuous power).

A switch is connected to the AGC Mains (terminals 112, 113 (com=111)), but it is not wired to the AGC DGcontrollers. The link from the AGC Mains to the AGC DG controllers will be CAN flags, and this will be pro-grammed in M-logic.



AGC Mains M-logic:

AGC DG M-logic (all DG controllers):

So with this setting in all of the DG units, they will all follow the command from the switch connected to theAGC Mains.

Plant management considerationsThe CAN flags exist on two levels in a plant management system. The group controllers are linking the plantmanagement system with the genset power management system.

Therefore it is necessary to bridge the CAN flags from the plant management level to the power managementlevel in the group controllers.

This is best illustrated with an example:

Change nominal setpoint from nominal setting 2 to nominal setting 3 (this could be the case when switchingfrom prime power to continuous power).

A switch is connected to the AGC PLANT unit (terminals 112, 113 (com=111)), but it is not wired to the AGCGROUP units or the AGC DG controllers. The link from the AGC Mains to the AGC DG controllers will beCAN flags through the group controllers.



AGC PLANT unit M-logic:

AGC GROUP unit M-logic:

AGC DG M-logic (all DG units):

So with these settings in all of the respective AGC units, they will all follow the command from the switch con-nected to the plant unit.



In an overview table it looks like this:

Plant manage-ment level

Power manage-ment level

Plantunit in-

put

Plant unit out-put

Group unit in-put

Group unitoutput

DG unit input DG unit output

112 CAN command 1 GG CAN input 1 CAN command1

CAN input 1 Nominal setting2

113 CAN command 2 GG CAN input 2 CAN command2

CAN input 2 Nominal setting3

Multiple use of CAN flagsIt is possible to use the same CAN flags in different controllers. It can be raised by several controllers, but if itis raised in one controller, it cannot be lowered by another controller.

AGC ID Not in AUTO State Status CAN flag

DG 1 CAN flag 1 AUTO

DG 2 CAN flag 1 SEMI-AUTO CAN 1 HIGH



In this table it is shown that all DGs are able to raise CAN flag 1, and that DG2 presently raises it. The CANflag will be raised until DG2 + the DGs 1, 3 and 4 are all in AUTO mode.



13.5.2 Common settingsSome settings in the power and plant management system are shared settings. This chapter will show theseparameters.

Parameter Menu number DG unit Mains unit Group unit Plant unit

CBE setpoint 2251 X

CBE delay 2252 X

CBE output 2253 X

CBE enable 2254 X

CBE breaker sequence 2261 X

CBE regulation delay 2262 X

CBE RPM excite 2263 X

CBE failure 2270 X

Master clock start 6401 X

Master clock stop 6402 X

Master clock diff 6403 X

Master clock comp 6404 X

CAN failure mode 7532 X

CAN failure mode, plant 7542 X

LD start P 8001 X

LD start S 8002 X

LD start pct 8003 X

LD start delay 8004 X X

LD start/stop scale 8006 X X

LD stop P 8011 X

LD stop S 8012 X

LD stop pct 8013 X

LD stop delay 8014 X X

LD stop Blocked ON (HC) 8015 X

Remote/local start 8021 X X X X

Priority type 8031 X X

Run hours 8111 X

Run hour type 8112 X

Ground relay 8121 X

Fuel optimise setpoint 8171 X

Fuel optimise swap setpoint 8172 X

Fuel optimise delay 8173 X

Fuel optimise quarantine 8174 X

Asymmetrical LS 8280 X X



Parameter Menu number DG unit Mains unit Group unit Plant unit

LD start/stop basis 8881 X

LD start/stop method 8882 X

Multi-start method 1 8922 X

Multi-start Min number to run 8923 X

Multi-start selection 8924 X

Multi-start method 2 8925 X

Multi-start Min number to run 8926 X

Secured mode 8921 X

Plant mode 6070 X X X

MB failure start 8181 X X X

Parallel 8182 X X X

Autoswitch 8183 X X X

No break transfer 8184 X X X

Run type 8185 X X X

ID to run 8186 X X X



13.5.3 Modbus addressesThe most common Modbus addresses from the parameter list that are normally used in the plant manage-ment SCADA are shown in this table. For all other addresses, please check the manual of option H2, ModbusRTU.

Description Menunumber

Offsetaddress

Addressarea

Functioncode

Comment

base 0 base 1

Plant unit kW setpoint 7051 541 542 +4000 16

kW setpoint 7001 527 528 +4000 16

kW setpoint 7002 528 529 +4000 16

kW scale 7005 1508 1509 +4000 16 value 0,1,2,3equals 1:1,1:10, 1:100,1:1000

Test kW 7041 538 539 +4000 16

Cos phi commonsetpoint

7052 542 543 +4000 16

Ind/cap 7053 1236 1237 +4000 16 0=ind, 1=cap

Enable 7054 1299 1300 +2000 15 0,1,2

Scale 7055 1300 1301 +4000 16 value 0,1,2,3equals 1:1,1:10, 1:100,1:1000

Enable frequencysupport

7143 1306 1307 +2000 15

Enable voltagesupport

7183 1311 1212 +2000 15

Nominal voltage 6004 410 411 +4000 16

Power offset 1 7222 1476 1477 +2000 15

Power offset 2 7224 1477 1478 +2000 15

Power offset 3 7226 1478 1479 +2000 15

Cos phi offset 1 7242 1479 1480 +2000 15

Cos phi offset 2 7244 1480 1481 +2000 15

Cos phi offset 3 7246 1481 1482 +2000 15

Groupunit

Cos phi commonsetpoint

7052 542 543 +4000 16

Ind/cap 7053 1236 1237 +4000 16 0=ind, 1=cap

Enable 7054 1299 1300 +2000 15 0,1,2

Assym LS 8281 1294 1295 +4000 16 value in per-cent

Enable 8282 1294 1295 +2000 15



Description Menunumber

Offsetaddress

Addressarea

Functioncode

Comment

Prty update 8086 656 657 +4000 16 0,1,2

DG units Assym LS 8281 1294 1295 +4000 16 value in per-cent

Enable 8282 1294 1295 +2000 15

Cos phi individualsetpoint

7051 542 543 +4000 16 15

Ind/cap 7052 1236 1237 +4000 16

Enable 7053 1299 1300 +4000 16 0=OFF, 3=su-perior

Prty update 8086 656 657 +4000 16 0,1,2

Run hour trip reset 8113 659 660 +2000 15

Nominal setting 6006 412 413 +4000 16 0,1,2,3

13.5.4 AOP designThe plant management system can easily be controlled by the additional operator's panel, AOP. This panel issupplied (option X3 and X4) either as AOP-1 or AOP-2. The front layouts are different, because the AOP-2has a lamp test push-button.



AOP-1 or AOP-2The difference between the AOP-1 and the AOP-2 is the number of selectable panels and the distance fromthe AGC display to the AOP. Since it is possible to install the AOP-2 at a distance, there is a lamp test buttonon the device.

Distance from the AGC display:

AOP-1 0.5 m AOP-2 200 m

Number of selectable AOPs:

AOP-1 1 pce AOP-2 5 pcs

Other differences:

AOP-1 RJ45 straight patch cable for connection AOP-2 CANbus communication AOP-2 lamp test button

Examples:Vast possibilities exist when using the AOP-1 or AOP-2. These two examples are just to give an impressionof how to use the AOPs.

This is an example of an AOP design on an AGC Mains, but the LEDs and buttons can be configured so theymatch the individual plant functionality.

In this example, four LEDs have been used to indicate failure of groups. This would typically be made with theuse of CAN flags.

This is an example where the group consists of 10 DGs and their fault status (typically with the use of CANflags) is shown on the 10 first LEDs.




The option G7 relates to a wide range of parameters. The description of those can be found in the parameterlist of the AGC-4. In this document, a Modbus table is included, in which the most common parameters rela-ted to plant management are mentioned.

13.7 Appendix, Operating settings

The appendix includes some basic information about how the plant is operated, i.e. how the plant is startedand stopped, where the power or frequency setpoints are adjusted and how to remove the genset for servicewithout affecting plant operation.

There is one section for each plant mode, depending on the operation: AMF, fixed power, load takeover, is-land, peak shaving or mains power export. Notice which section applies to your plant.

13.7.1 Fixed power operationOperating the plant - fixed power modeThis chapter is a description of the basics of operating the plant, i.e. where are the commands and setpointscoming from.

All operation of the plant should be carried out or supervised by responsible personnel according to the in-structions from the owner of the site.

Start the plant (AUTO start)



Type: Instruction Comment Your se-lection

Local start/stop(menu 8021)

Plant controller display unit:Press the (green) start button

Remote start stop(menu 8021)

SCADA:See SCADA screen design

Modbus/Profibus


AOP-1 or AOP-2:Press the dedicated button

Programmed in M-logic(Auto start/stop)


Selector switch:Turn the selector switch to the start position

Digital input (Auto start/stop)

Menu 8021 is checked in the plant unit. (The group units must also be adjusted to remote).

Stop the plant (AUTO stop)



Plant controller display unit:Press the (red) stop button

Remote start/stop(menu 8021)


Modbus/Profibus





Selector switch:Turn the selector switch to the stop position



Servicing the plantIf a DG unit has to be taken offline for service, AUTO mode should be deselected on the unit in question. Thiscan be done by selecting SEMI, BLOCK or MAN depending on the service job that needs to be made. IfSEMI mode is selected, the setting of menu 8022 (mode update) should be checked. If it is adjusted to "up-date all", all units in the genset group with the same setting move to SEMI mode. If they are running, they donot stop but they do not react to AUTO start/stop commands such as AUTO start.

Setting Setting of menu 8022 Applicable Your selection

SEMI mode Local update Yes always

SEMI mode Update all Not always(Selecting SEMI switches all AGCs to SEMI)

BLOCK mode Don't care Yes always

MANUAL mode Don't care Yes always

Setpoints of the plant



When the plant is operating in the plant management mode, the MW and cos phi setpoints of the plant arenormally adjusted in the plant controller. It is also possible to control the cos phi setpoint from the individualgenset controller; please see description of cos phi control.

Type Instruction Your selection

Display unit MW menu 7051Cos phi menu 7052

SCADA See SCADA screen design

Hz and V supportVoltage and frequency support can be activated in the plant unit.

Function Menu Your selection

Frequency support 7143

Voltage support 7183

The control (enable and setpoints) of the frequency and voltage support can also be accessed through SCA-DA.

Notice that other settings might be required for specific plants.

13.7.2 AMF operationThis chapter is a description of the basics of operating the plant, i.e. where are the commands and setpointscoming from.


Start the plant (AUTO start)The gensets of the plant start when there is a mains failure.

Stop the plant (AUTO stop)The gensets of the plant stop when the mains is restored.

Servicing the plantIf a DG unit has to be taken offline for service, AUTO mode should be deselected on the unit in question. Thiscan be done by selecting SEMI, BLOCK or MAN depending on the service job that needs to be made. IfSEMI mode is selected, the setting of menu 8022 (mode update) should be checked. If it is adjusted to "up-date all", all units in the genset group with the same setting move to SEMI mode. If they are running, they donot stop but they do not react to AUTO start stop commands such as AUTO start.








Setpoints of the plantIn automatic mains failure operation the generators are controlled according to frequency and voltage set-points, and they are at the same time performing load and VAr sharing. The Hz and voltage setpoints of theplant are those of the nominal settings of the generator AGCs. If switching of voltage and frequency setpointsis needed, it must therefore be adjusted on all the generators, although normally on most applications thesesetpoints are not changed.

If the change of setpoint is done individually, it should be done while the plant is stopped to avoid differentfrequency and voltage setpoints on generators (to avoid breaker tripping). Alternatively, the switching can bedone by switching between the four sets of nominal values that are available.

The kW and kVAr setpoints depend on the load of the plant, and the generators perform load sharing be-tween them.

Setting Menus Your selection

Nominal settings - individual Hz adjust48-62 Hz

6001, 6011, 6021, 6031

Nominal settings - individual V adjust0.100-160 kV

6004, 6014, 6024, 6034

Nominal setting - setpoint group 1-4 6006

CAN flags can be used to select between the nominal settings 1-4 (menu 6006) by adjustmentin M-logic and carried out from e.g. SCADA or AOP-1. This can typically be performed on theplant unit, and the CAN flags are transmitted to the genset controllers effecting the change innominal setting.

Other settings might be required for specific plants.

13.7.3 Island mode operation with plant unitThis chapter is a description of the basics of operating the plant, i.e. where are the commands and setpointscoming from.










Modbus/Profibus














Modbus/Profibus














Setpoints of the plant



In island mode the generators are controlled according to frequency and voltage setpoints and they are at thesame time performing load sharing. The Hz and voltage setpoints of the plant are those of the nominal set-tings of the generator AGCs. If switching of voltage and frequency setpoints is needed, it must therefore beadjusted on all the generators, although normally on most applications these setpoints are not changed.

If the change of setpoint is done individually, it should be done while the plant is stopped to avoid differentfrequency and voltage setpoints on generators (risk of breaker tripping). Alternatively, the switching can bedone by switching between the four sets of nominal values that are available.




6001, 6011, 6021, 6031


6004, 6014, 6024, 6034


CAN flags can be used to select between the nominal settings 1-4 (menu 6006) by adjustmentin M-logic and carried out from e.g. SCADA or AOP-1. This can typically be performed on theplant unit, and the CAN flags are transmitted to the genset controllers effecting the change innominal setting.


13.7.4 Island mode operation without plant unitThis chapter is a description of the basics of operating the plant, i.e. where are the commands and setpointscoming from.





Group unit display unit:Press the (green) start button

Any group unit



Modbus/Profibus





Selector switch:Turn the selector switch to the start posi-tion




Menu 8021 is checked and adjusted in the group units.







Modbus/Profibus







Menu 8021 is checked and adjusted in the group units.







Setpoints of the plantIn island mode the generators are controlled according to frequency and voltage setpoints and they are at thesame time performing load sharing. The Hz and voltage setpoints of the plant are those of the nominal set-tings of the generator AGCs. If switching of voltage and frequency setpoints is needed, it must therefore beadjusted on all the generators although normally on most applications these setpoints are not changed.

If the change of setpoint is done individually, it should be done while the plant is stopped to avoid differentfrequency and voltage setpoints on generators (risk of breaker tripping). Alternatively, the switching can bedone by switching between the four sets of nominal values that are available.






6001, 6011, 6021, 6031


6004, 6014, 6024, 6034


CAN flags can be used to select between the nominal settings 1-4 (menu 6006) by adjustmentin M-logic and carried out from e.g. SCADA or AOP-1. This can be performed on one of thegroup controllers, and the CAN flags are transmitted to the genset controllers effecting thechange in nominal setting.


13.7.5 Load takeover modeThis chapter is a description of the basics of operating the plant, i.e. where are the commands and setpointscoming from.








Modbus/Profibus
















Modbus/Profibus














Setpoints of the plantNo setpoint can be adjusted in the LTO mode. The number of generators that is sufficient for supplying theload will start, and the MB will open when no load is flowing across the mains breaker.


13.7.6 Mains power export modeThis chapter is a description of the basics of operating the plant, i.e. where are the commands and setpointscoming from.










Modbus/Profibus














Modbus/Profibus
















Setpoints of the plantThe MW and cos phi setpoints of the plant are adjusted in the plant unit. It is also possible to control the cosphi setpoint from the individual genset controller; please see separate chapter.


Display unit MW day menu 7001MW night menu 7002Cos phi menu 7052


Hz and V supportVoltage and frequency support can be activated in the plant unit.

Function Menu Your selection

Frequency support 7143

Voltage support 7183


13.7.7 Peak shaving modeThis chapter is a description of the basics of operating the plant, i.e. where are the commands and setpointscoming from.


Start the plant (AUTO start)The plant starts according to the adjusted import setpoints and the load-dependent start setpoint (default#8001). This is best illustrated with an example:

Day and night setting = 10000 kW; LD start setting = 200 kW; LD stop setting = 400 kW Generators are stopped and the mains feeds the load When the imported load increases to [10000-200 = 9800 kW], the generators are started (according to

the multi-start settings Any load above 10000 (day/night setting) will be supplied by the generator. The mains supply is main-

tained at 10000 kW When the load (sum of load of mains+DGs) drops to [10000-400 = 9600 kW], the generators are stopped The 9600 kW are supplied by the mains

Stop the plant (AUTO stop)The plant stops according to the adjusted import stop setpoint and the load-dependent stop setpoint (default#8011). See example above.









Setpoints of the plantThe MW and cos phi setpoints of the plant are adjusted in the plant unit. It is also possible to control the cosphi setpoint from the individual genset controller; please see separate chapter.


Display unit MW day menu 7001MW night menu 7002Cos phi menu 7052




14. Analogue controller and transducer outputs14.1 Description of option, ANSI numbers

Function ANSI no.

Selectable +/-25 mA or relay output for speed control (governor) 77

Selectable +/-25 mA or relay output for voltage control (AVR) 77

PWM speed control output for CAT® engines 77

1 x 0(4)-20 mA outputs 77

2 x 0(4)-20 mA outputs 77

14.2 Description of option, Option EF6

Option EF6 is a hardware option, and a separate PCB is installed in slot #4. The PCB will replace the stand-ard-installed relay PCB in slot #4. The PWM (Pulse Width Modulated) speed output is intended for Caterpil-lar® electronic engine control systems ADEM and PEEC.

14.2.1 Terminal description

Term. Function Description

65 Not used

66 Not used

67 0 Speed governor, AVR or transducer output 68

68 +/-25 mA

69 PWM - PWM speed governor signal

70 PWM +


72 +/-25 mA

Connect PWM - to the engine battery negative and PWM + to the engine control system S-SPD(speed) input (called RATED SPEED on the ADEM controller and PRIMARY THROTTLE on thePEEC controller).

AVR control requires the D1 option.

14.3 Functional description, Analogue outputs

The analogue outputs are active and galvanically separated. No external supply can be connected.

The current outputs can be converted to any voltage in the range inside +/-10V DC by mounting a resistoracross the terminals.

Example: A 200 Ω resistor across the terminals of the +/-25 mA output will supply a range of +/-5V DC.

AGC-4 manual, November 2011, UK Analogue controller and transducer outputs


The choice of resistor depends on the specific governor. Please refer to the DEIF documents"Interfacing DEIF Equipment with Governors and AVRs" and "General Guidelines for Commis-sioning" for detailed information.

Place the resistor at the governor/AVR end to avoid the signal being disturbed by noise.

The outputs from the controller unit are active outputs, and no external supply can be connec-ted.

14.4 Functional description, Duty cycle

The PWM signal has a frequency of 500 Hz +/- 50 Hz. The resolution of the duty cycle is 12 bits, which givesoutput 4095 different levels. The output is an open collector output with a 1 k-ohm pull-up resistor.

The low level of the signal is between 0 and 0.05 volt, whereas the high level is between 5.7 and 6 volt.

Time

Voltage

0…0.5V

5.7…6V

0…100% duty cycle

14.4.1 Principle of duty cyclesThe drawing below shows an example of a 10% duty cycle:

Duty cycle = 10%



The drawing below shows an example of a 90% duty cycle:

Duty cycle = 90%

When used as transducer outputs, the signal can be connected directly to 4-20 mA instruments as shownbelow.

Out

0-

+

Transducer output 4-20mA instrument or similar

It is recommended to use instruments from the DQ series of DEIF instruments. Please refer towww.deif.com for more information.

14.5 Functional description, Analogue controller offset

In addition to the controller parameters, this additional setting can be used. The purpose of this setting is togive the analogue output an offset value when powering up the unit. Furthermore, a digital input can be usedto reset the output to the offset value. The offset value must be adjusted so the genset will start up at thecorrect speed and voltage.

The following drawing is for the E1 option with the output limits set to +/-25 mA.



Controller offset

100%

0%

25mA

-25mA

The offset always refers to the analogue output limits.

When the engine is stopped the controller outputs are reset to the analogue offset value.

Typically the initial speed/voltage adjustment is made on the speed governor/AVR itself.

14.6 Functional description, Output limits

If the full range of the analogue output is not needed it is possible to limit the maximum and minimum outputvalues.

This can especially be useful when using the analogue output for governor control, since some governors on-ly accept a specific voltage range.

In the following example, analogue output 66 with a standard output of +/- 25 mA (option E1) is limited to anoutput of 0-20 mA to be used for governor control.



0%

20%

40%

60%

80%

100%

0 mA

20 mA

Regulator output

0%

20%

40%

60%

80%

100%

-25 mA

25 mA

Regulator output

The menus used for setting up the output limits are 5780 to 5810. The menus available are op-tion-dependent.

14.7 Parameters, further information

The options E and F relate to the parameters 5780-5990.









15. Configurable I/O extension cards, four 4-20 mA inputs15.1 Description of option, Option M15.x

Option M15.x is a hardware option and therefore a separate PCB is installed in addition to the standard-in-stalled hardware.

15.1.1 Terminal description, M15.6


90 Analogue input 91 Common 4-20 mA input, configurable

91 Analogue input 91 4-20 mA in







15.1.2 Terminal description, M15.8










Please refer to the Installation Instructions for the wiring of active and passive transducers.

AGC-3/PPM: The option M15 can only be installed one time for each unit, so it is not possibleto have M15.6 and M15.8 at the same time.

15.2 Functional description, Analogue input configuration

The analogue input can be used for protection and display of values. The configuration can be done with theML-2 utility software or by using the display.

In the display, the readings of the 4-20 mA input can be read. The readings are found in the second line ofthe setup menu or, if configured, in the view menu system.

AGC-4 manual, November 2011, UK Configurable I/O extension cards, four 4-20mA inputs


Refer to the Designer’s Reference Handbook regarding the menu system and configuration ofuser views.

The ML-2 utility software enables you to change the text, scale and unit of the measurement. The text andunits can be changed in the "Translations" section of the utility software. The menus used for configuring thescale are 11010-11110. The menus available are option-dependent and can only be accessed from the ML-2utility software.

If the text of the input is changed, you will see the changed text. This could e.g. be "Oil press. ##bar" insteadof "4-20mA 91.1 ##mA"

15.3 Functional description, Inverse proportional

In situations where the signal of the input is reversed, the "Inverse proportional" selection can be made. Theselection ensures that the display reading is correct when an "inversed" signal is made.



The diagram shows the characteristics of the "normal" proportional sensor and of the inversed proportionalsensor.

4mA 20mA

100%

0%

Alarm

ProportionalInverse

proportional

Low alarm

area

High alarm

area

Value [%]

Current [mA]

9mA 15mA

This function can only be activated by using the ML-2 utility software.

15.4 Functional description, PC utility software

The PC utility software is a Windows® based software, which can be downloaded from our website www.de-if.com. To adjust the inputs via the PC utility software, a computer must be connected to the controller unit.Furthermore, the unit parameters must be uploaded to the computer.

15.5 Functional description, Wire failure detection

If it is necessary to supervise the sensors/wires connected to the analogue inputs, it is possible to activate thewire failure detection on each individual input.

If the measured value on the input is outside the normal dynamic area of the input, it will be detected as if thewire has made a short circuit or a break, and an alarm with a configurable fail class will be activated.

15.5.1 PrincipleThe illustration below shows that when the wire of the input breaks, the measured value will drop to zero.Then the alarm will occur.

Wire failure

Wire failure

Wire break

Lower failure

limit

Upper failure

limit

Input signal

(mA, °C,b, %)

t




The option M15 relates to the parameters 4000-4110 (M15.6) and 4800-4910 (M15.8).









16. Configurable I/O extension cards, 13 binary inputs, 4relay outputs16.1 Description of option, Option M12

Option M12 is a hardware option, and therefore an extra PCB is placed in slot #3 in addition to the standard-installed hardware.

16.2 Description of option, ANSI numbers

Function ANSI no.

13 x binary inputs for control and/or alarms 77

4 x digital outputs 74

AGC: if option G3 is already installed, option M12 is a software upgrade.

AGC-4 manual, November 2011, UK Configurable I/O extension cards, 13 binaryinputs, 4 relay outputs


16.3 Description of option, Terminal descriptions

16.3.1 Terminal description, AGC


37 Used for the option G3

38

39

40 -10…0…10V DC Analogue I/O f/P setpoint


42 -10…0…10V DC Analogue I/O U/Q setpoint














56 Com. Common Common for terminals 43 to 55

57 NE/ND Relay 57 Configurable

58 Com. 250V AC/5 A


60 Com. 250V AC/5 A


62 Com. 250V AC/5A


64 Com. 250V AC/5 A

Please refer to the Installation Instructions for detailed description of the wiring of digital in-puts.



16.3.2 Terminal description, GPU/GPU Hydro


37 Not used

38

39

40

41

42
















58 Com. 250V AC/5 A


60 Com. 250V AC/5 A


62 Com. 250V AC/5 A


64 Com. 250V AC/5 A

Please refer to the Installation Instructions for detailed description of the wiring of digital in-puts.

16.4 Functional description, Digital inputs

The digital inputs available in this option can be used for two purposes:1. Protection (alarm) inputs2. Function inputs



16.5 Functional description, Protection/alarm inputs

The delay settings are all of the definite time type, i.e. a set time is selected. The delay will be activated if theinput goes ON (or OFF if selected to be N/C). If the input is reset before the delay runs out, the delay will bereset.

TimeTimer

start

Timer

reset

Timer

startAlarm

Timer setting

Input

ONInput

OFF

Input

ON

When the delay runs out, the output will be activated.

16.5.1 Function inputThe function inputs can be set up via the PC utility software.

The PC utility software is a Windows®-based software, which can be downloaded from our website www.de-if.com. To adjust the inputs via the PC utility software, a computer must be connected to the controller unit.Furthermore, the unit parameters must be uploaded to the computer.

Please refer to the Designer’s Reference Handbook for a complete list of the available inputfunctions.



16.6 Functional description, Relay setup

Each relay has a function and an OFF delay setting as described below.

Function Description

Alarm relay NE When the relay is activated, an alarm is displayed. The relay will remain activated foras long as the alarm is present and unacknowledged.

Alarm relay ND(GPU/GPU Hydroonly)

When the relay is activated, an alarm is displayed. The relay will remain activated foras long as the alarm is present and unacknowledged.

Alarm/reset(GPU/GPU Hydroonly)

The functionality is similar to "Alarm", but with a short-time reset if the relay is ON andanother alarm tries to activate the same relay.

Limit relay When the relay is activated, no alarm message is displayed. After the condition activat-ing the relay has returned to normal, the relay will deactivate when the "OFF delay"has expired.

Horn relay When the relay is activated, an alarm message is displayed. The relay will be activateduntil the time set in menu 6130 "Alarm horn" has expired or the alarm activating therelay has been acknowledged.

Siren relay (GPU/GPU Hydro only)

The output activates on all alarms, like “Horn output”. If the relay is ON and anotheralarm is active, a short-time reset = 1 s will be activated.

OFF delay The "OFF delay" is used when limit relay is selected. It is the time between the disap-pearance of the event that caused the relay to activate and the actual deactivation ofthe relay.

It is possible to configure the relay outputs to be used for speed and/or voltage regulation.Please refer to the Designer’s Reference Handbook.

The relays can also be used together with M-logic. Please refer to the help function in the PCutility software.

16.7 Functional description, External analogue setpoints

16.7.1 AGCThe genset can be controlled from internal as well as from external setpoints. The external setpoints are acti-vated with a digital signal.

Five inputs can be selected, and their function depends on the mains breaker position.

Input Frequency Power Voltage Reactive power Power factor

Island mode, stand-alone X X

Island mode, load sharing X X

Parallel to the mains X X X

The controller setpoints will be ignored if the running condition is not present. For instance, it is not possibleto use the frequency controller when paralleling to the mains.



The table below shows the setpoints.

Controller Input voltage Description Comment

Frequency +/-10V DC fNOM +/-5 Hz Active when MB is OFF

Power +/-10V DC +/-100% *PNOM

Voltage +/-10V DC UNOM +/-10% Active when GB is OFF

Reactive power +/-10V DC +/-100% *QNOM

Power factor ÷10 V…0…10V DC 0.6 capacitive…1.0…0.6 inductive

The external setpoints can be used in all genset modes when auto or semi-auto mode is selected.

Only a limited number of digital inputs are available in the standard unit. The unit should beinstalled with the sufficient number of options to get the desired digital inputs.

If the option H2 is available in the unit, the external setpoints can be controlled from the controlregisters in the Modbus protocol. Please refer to the description of option H2 for further infor-mation.


The option M12 relates to the parameters 3130-3250 and 5110-5140.








17. Ethernet hardware17.1 Description of option, Hardware

The option N is an Ethernet hardware option offering a number of features; hereafter called the option N. Thehardware needed for the option N replaces the default interface board placed under the service port (See fig-ure below).

The option N board has four connectors:1. Display port (9-pole SUB-D)2. Service port (USB A-B)3. USB Memory (currently not used)4. Ethernet (RJ-45 for CAT 5 cable)

There are currently two different option N hardware cards. They are almost identical in features, but the twoversions are different in hardware. You can tell which card you have from the version of the software embed-ded in the option N. This information can be retrieved from the menu 9000 on the display unit. Either it isversion 1.xx.x, or it is the more recent version 2.xx.x. This document focuses on the most recent version, butit also describes the differences compared to a setup using the older option N hardware.

Ethernet

787776757473 96 979594929190 9389888785 8683 8482818079

727169 70686765 6662 6359 60 615856 575553 54 645251504947464443 45 4841403837 39 42

Service port Display

Ethernet

PMS CANEngine CAN

Power

Self check okAlarm inhibit

USB

USB Memory

Multi-line 2 device mounted with the option N interface board.

17.2 Description of option, Option N configuration software

The features that the option N offers can only be configured using the free PC tool:

AGC-4 manual, November 2011, UK Ethernet hardware


DEIF Multi-line 2 Utility Software v.3.x (USW).

The USW-3 can be downloaded from: www.deif.com.

Please see the application note "Download guide" for information about how to download andinstall this software and which operating systems are compatible with this software.

When the DEIF Multi-line 2 Utility Software v.3.x (USW) is running, click the "Option N" icon to run the optionN configuration software.

17.3 Network configuration of the option N board, Network settings

The Ethernet port of the Multi-line 2 option N board is delivered pre-configured with these network settings:

Factory setting

IP address 192.168.2.21

Subnet mask 255.255.255.0

To be able to configure and use the option N, it must be connected directly to a PC.

Please note that the option N network parameters cannot be programmed by using the Multi-line 2 unit dis-play. The PC must be configured to use the same network as specified above. Using Microsoft Windows XP,this can be done by changing the TCP/IP settings to the following (see the below figure):

Factory setting

IP address 192.168.2.22

Subnet mask 255.255.255.0



TCP/IP settings window from Microsoft Windows XP.

17.4 Network configuration of the option N board, Option N board setup

When your PC has been set up as described on the previous pages, and the PC is directly connected to theEthernet socket of the option N board, you must check if you have access by means of the "Ping" menu ofthe option N configuration software.



Enter the right IP address and press the "Ping" button (see example below).

Then press the "Stop" button and close this window.

17.4.1 Modifying the network configuration from the option N configuration softwareWhen the option N configuration software is running, it is also possible to modify the option N network param-eters (IP address, subnet mask, etc.) This can be done using the menus "Settings" and "Network parame-ters", see below.

Please note that the "Network parameters" menu point is only available after the "Get" function in the "Con-nection" menu has been used. The default user name and password are both "admin" (see the below screendump).

The below parameters are read, and they can be modified here:



DHCP is a new feature in version 2.xx.x of the option N card. When the DHCP function is enabled, the net-work parameters will be retrieved automatically if a DHCP server is available in the local network. If no DHCPserver is available, the network parameters will fall back to factory settings.

Press the "OK" button to write the new configuration to the Multi-line 2 unit.

After pressing "OK", the option N reboots automatically. It will take two minutes before the unit is fully opera-tional again.

Access control setupUsing a web interface, the user names and passwords of the option N card can be set. This function is toallow access for selected users only. To programme this access control, you must start your internet browsersoftware, enter the IP address in the internet address field and press the "Enter" key.



Click the bottom link, "Access control", to change the access control parameters of the option N card (username = admin, password = admin).

"Passwords" Is used to modify the passwords of each web page type (admin, application or FTP)."WWW IPFiltering"

Is used to select one or several IP addresses that will be allowed to access the option Ncard for each option N applicaton type.If these fields are left blank, no IP address filter is applied, and the option N card is accessi-ble by all IP addresses without any restriction.

17.5 TCP/IP Modbus communication, Further information

TCP/IP Modbus is identical with the classical serial Modbus communication, except for the fact that the mediaused for this communication is a TCP/IP communication. So the basic Modbus functionalities will not be ex-plained here, but more information can be found in the Multi-line 2 option H2 (Modbus option) documentation,which can be downloaded free of charge from the DEIF web page www.deif.com.



The useful parameters required from the software you use for communicating with the option N card bymeans of a TCP/IP Modbus communication are:

The IP address of the option N card to talk to The port number to be used

The previous chapters explain the way to set up the IP address parameter of the option N card. The portnumber to be used is: 502.

17.6 SMS or e-mail alarms transfer

When the option N card has access to the Internet, it can be configured to send SMS and e-mail alarm mes-sages. These functions require third party service providers (often a priced service).

The SMS function has been designed and tested to work with the Clickatell service provider, www.clicka-tel.com.

The e-mail function requires an available e-mail server that supports SMTP. Most popular e-mail servers sup-port SMTP. Contact your system administrator for details.

This alarm application supervises a number of Modbus flags. Should one or more of these alarm flags getset, the configured SMS and/or e-mail messages will be sent.

Each of the supervised alarm flags holds the state of a "fail class", which is one of the following:

AGC PPM GPC/GPU/PPU

Block Block Block

Warning Warning Warning

Trip GB (generator breaker) Trip GB (generator breaker)/SGB/SCB/BTB Trip GB (generator breaker)

Trip MB (mains Breaker) Trip SGB (shaft generator breaker)

Trip SCB (shore connection breaker)

Trip BTB Trip BTB (bus tie breaker)

Trip + Stop Trip + Stop Trip + Stop

Shutdown Shutdown Shutdown

Trip TB (mains breaker unit) Trip TB (tie breaker, emergency generatorunit)

Trip TB (mains breakerunit)

Safe stop Safe stop Safe stop

5 e-mail receivers and 5 SMS receivers can be defined. For each recipient, the fail classes to receive notifica-tions about can be defined. For e-mails, it can furthermore be specified if the user should receive the mails asa "To" receiver or a "Cc" receiver.

The alarm flags are scanned every second and for each unit (from lowest to highest CAN ID number), eachfail class (from highest to lowest priority) is evaluated, and e-mail/SMS messages are sent accordingly.

There is one special case, where an alarm is suppressed: when a warning alarm is detected at the same timeas some higher priority alarm, the warning alarm will not be sent.



17.7 SMS or e-mail alarms transfer, SMS or e-mail alarms configuration

You must use the "Get" function ( ) before you will be able to access this alarm function. Then go to the

"Settings" menu and select the "Email and SMS" menu or click the "Email and SMS settings" icon ( ).

>>> Write the above configuration to the option N card.

>>> Read the configuration present in the option N card.

EMail generalThis field gathers all the useful parameters for exporting the alarms by means of e-mail messages. This sec-tion is then connected to the e-mail section containing the "Recipients e-mail" (right upper section of this win-dow). If you do not require exporting the alarms by means of e-mail messages, do not fill in these fields.

Address of SMTP serverMust contain the IP address of the SMTP server you want to use for exporting alarms by means of e-mailmessages.

Sender addressMust contain the sender’s e-mail address.

User name for mail serverIf required by the used SMTP server, you can type a user name here.



Password for mail serverIf required by the used SMTP server, you can type a password here.

User text in emailThe text you enter here will be placed in the subject line of the sent e-mail messages.

SMS generalThis field gathers all the useful parameters for exporting the alarms by means of SMS messages. This sec-tion is then connected to the section containing the ‘Recipients tlf’ (right lower section of this window).

SMS gatewayTwo different services can be used for exporting alarms by means of SMS messages when using the ser-vices from an SMS gateway provider (for example: Clickatell www.clickatell.com):

http to SMS (see the Clickatell http post specification document _SMS Gateway). mail to SMS (see the Clickatell SMTP post specification document _SMS Gateway).

Visit their website to get all the details concerning these two different services.

The first field is for selection of the service type for alarms by means of SMS messages. Select "http" or"mail". The contents of the next field (to the right) depend on the SMS gateway type ("http" or "email"):

http: The heading of the http command line (ex: http://api.clickatell.com). email: The e-mail address given by your SMS gateway provider (Example from Clickatell: sms@mes-

saging.clickatell.com).

User name for SMS gatewayType the user name ID given by your SMS gateway provider.

Password for SMS gatewayType the password ID given by your SMS gateway provider.

SMS gateway ID (optional)Type the application ID given by your SMS gateway provider if this is necessary to use your provider serv-ices.

Pattern for mail subject lineYou must fill in this field, if "mail" is selected in the SMS gateway field (see above). In this case, the text lineyou enter here will be the subject line of the e-mails that will be sent for exporting alarms by means of SMSmessages.



Pattern for mail bodyYou must fill in this field, if you select "mail" in the SMS gateway field (see above). In this case, the text lineyou enter here will be the body text of the e-mails that will be sent for exporting alarms by means of SMSmessages.

Pattern for http GET requestYou must fill in this field if you select "http" in the SMS gateway field (see above). In this case, the text lineyou enter here will be the http line of the http message that will be used for exporting alarms by means ofSMS messages.

The below symbols must be used to incorporate all the useful data from the other fields into this http GETrequest. The line to enter here can then be as follows:

/http/sendmsg?api_id=%I&user=%U&password=%P&to=%N&text=%M

In these patterns, the substitution parameters to use in the above http command line are:

%U is replaced by the "User name for SMS gateway" field content.%P is replaced by the "Password for SMS gateway" field content.%I is replaced by the "SMS gateway ID" field content.%N is replaced by the "Recipients tlf" field content.%M is replaced by the "User text in SMS" field content.

The final http command line that will be sent to the SMS gateway provider will then be:

‘content of the field situated at the right side of the SMS gateway field’/http/sendmsg?api_id=’SMS gateway ID’ field content.‘&user=’user name for SMS gateway field content’&password=’password for SMS gatewayfield content’&to=’Recipients tlf field content’&text=’user text in SMS field content’.

Http proxyMust contain the proxy server IP address (and the port number) that is required to reach the WEB (WorldWide Web) from the Multi-line 2 unit option N card TCP/IP port. For example 192.168.1.1:8080. A semicolonmust be used as separator between the proxy server IP address (192.168.1.1) and the port number (8080).

User text in SMSThe text line you enter here will be used as SMS text when exporting alarms by means of SMS messages.

The above table has to be filled in if you want to export the alarms by means of e-mail messages.

Recipients EmailMust contain the e-mail addresses of the persons to contact by e-mail messages when an alarm is detectedfrom the Multi-line 2 unit.



Alarm listThis field informs about which fail class alarm is interesting for the corresponding e-mail address (from the leftside). Min. value: a, max. value: h, in steps of one letter. Example: a,b,d,f - in this case, the Multi-line 2 unitwill only export its alarms with a fail class type a, b, d or f.

The above table has to be filled in, if you want to export the alarms by means of SMS messages.

Recipients tlfMust contain the GSM phone number of the persons to contact by SMS messages when an alarm is detectedfrom the Multi-line 2 unit.

Alarm listThis field informs which fail class alarm is interesting for the corresponding GSM phone number (from the leftside). Min. value: a, max. value: f, in steps of one letter. Example; a,b,d,f. In this case, the Multi-line 2 unit willonly export its alarms with a fail class type a, b, d or f.

Fail class

Alarmlist

GPU/PPU/GPC

AGC(singlegen.)

AGC DG(optionG5)

AGCMains

AGC/PPMBTB

PPMDG

PPMSG

PPMSC

PPMEDG

a Block Block Block Block Block Block Block Block Block

b Warning Warning Warning Warning Warning Warning Warning Warning Warning

c Trip GB Trip GB Trip GB Trip MB TripBTB

Trip GB TripSGB

TripSCB

TripEGB

d Trip+stop

Trip+stop

Trip+stop

Trip TB N/A Trip +stop

N/A N/A Trip +stop

e Shut-down

Shut-down

Shut-down

N/A N/A Shut-down

N/A N/A Shut-down

f N/A Trip MB Safetystop

N/A N/A Safetystop

N/A N/A Trip TB



Examples for the SMS or e-mail alarms configurationExample 1: Exporting the Multi-line 2 alarms by e-mails.

By adding "To" or "Cc" at the end of each alarm list item, the concerned IP address will be used as "To" or"Cc" field in the e-mail that will send the alarm.



Example 2: Exporting the Multi-line 2 alarms by SMS (SMS gateway service type: http).

Pattern for http GET request:http/sendmsg?api_id=%I&user=%U&password=%P&to=%N&text=%M.

%I: Will insert what is already typed inside the "‘SMS gateway ID" field (api_id).%U: Will insert what is already typed inside the "User name for SMS gateway" field (user name).%P: Will insert what is already typed inside the "Password for SMS gateway" field (password).%N: Will insert what is already typed inside the "Recipients tlf" field (mobile phone numbers).%M: Will insert what is already typed inside the "User text in SMS" field (user-selectable text).



Example 3: Exporting the Multi-line 2 alarms by SMS (SMS gateway service type: mail).

Pattern for mail body: api_id:%I&user:%U&password:%P&to:%N&text:%M.

%I: Will insert what is already typed inside the "SMS gateway ID" field (api_id).%U: Will insert what is already typed inside the "User name for SMS gateway" field (user name).%P: Will insert what is already typed inside the "Password for SMS gateway" field (password).%N: Will insert what is already typed inside the "Recipients tlf" field (mobile phone numbers).%M: Will insert what is already typed inside the "User text in SMS" field (user-selectable text).

17.8 SMS or e-mail alarms transfer, Received message format

The content of the message sent is defined as:

"MsgNo._n1_IDNo._n2_t1_t2_t3"

The variables in the message are as follows:

n1: Unique number of the alarm, incremented at each new alarm detection.

n2: CAN ID of the unit giving the alarm:



CAN ID Comment CAN ID Description

0 Single mains unit 9 Genset/multiple mains unit

1 Genset unit 10 Genset/multiple mains unit



4 Genset unit 13 Genset unit




8 Genset unit

t1: User-defined text.

t2: Name of the fail class.

t3: Specific alarm text:The alarm texts for the individual alarms will be used.

An example of a message could be:"MsgNo._1_IDNo._3_User defined text_WARNING_Dig. input 23"

17.8.1 Alarm transfer function selection from the option N configuration softwareThe alarm transfer is a user-selectable option. Open the "Settings" menu of the option N configuration SW toenable or disable this option.

Select the required option here:

The Modbus TCP/IP option is marked with grey because it is not a user-selectable option. This option is al-ways selected as standard.



Check that the IP address is right, correct it if necessary and click "OK".

You must now reboot the option N board to enable this new option.

To reboot, use the "Reboot" icon of the option N configuration SW ( ).

17.9 Option N firmware upgrade

The jump menu no. 9000 of the Multi-line 2 unit display shows the option N firmware version, also called im-age software (see the example below).

Image Ver. 2.00.0 APPL REV W1 W2

G 0 0 0 VGW: 192.168.001.001

In the example, the image software version is 2.00.0.

This chapter will explain how to update the image software.

17.9.1 Obtain the option N firmware from DEIFThe USW is normally obtained from DEIF via the internet. Visit www.deif.com.





Select "Documentation & Software" in the top menu, and select "Software download".

There are two hardware versions of the option N card. One supports software version 1.xx.x and the otherversion 2.xx.x. You can only store software of the same major version as that of the hardware. So, for exam-ple, an option N card with software of the version 2.00.1 can only support other software versions with majorversion number 2. The current software version can be retrieved from the jump menu 9000 of the Multi-line 2unit.

17.9.2 How to write the option N firmwareFollow the steps described in this chapter to write a new firmware on the option N card, also called imagesoftware.

Click the "option N" icon in the USW to open the option N configuration software.



Click the "Send firmware to device" icon,

- or use the "Connection" menu and the "Firmware" submenu.

Open the new image file "xxx.mm21" to be written to the unit if it is for a version 2.xx.x software type

- or open the new image file "xxx.bin" to be written to the unit if it is for a version 1.xx.x software type.

Enter IP address, user name and password (the factory settings are: user name = admin and password =admin).



Remember to check the jump menu 9000 to see the IP address of the unit.

Upgrade of the firmware is in progress.

Download of the new image software is now completed.

17.10 Parameters, further information

The option N relates to the parameter 9000.









18. Additional display and operator's panel18.1 Description of option, Option X2

The option includes an additional standard display (DU-2) for the ML-2 unit to be connected to the originaldisplay unit via a CANbus connection.

With additional DU-2 units it is possible to operate the system from various positions, e.g. start/stop, alarmacknowledge, readings, access setpoints, etc.

A maximum of three standard displays can be connected to each ML-2 unit.

The maximum length of the CANbus line is 200 m.

18.1.1 Rear side view

AOP-1

CAN 1 CAN 2

ML - 2

Standard display DU-2

OFF

ON

2 1

End resistor

18.1.2 Connectors

ML-2: The serial connection to/from the display port of the ML-2 unit.AOP-1: The connector for the cable to an AOP-1.CAN 1: DC supply and CANbus communication to/from other DU-2 or AOP-2 units.CAN 2: CANbus communication to/from other DU-2 or AOP-2 units.End resistor: Dip switch for 120 Ohm end resistor for the CANbus communication.

Dip switch no. 2 is not to be used.

18.2 Description of option, Option X3

The option includes an additional operator’s panel (AOP-1) which is to be connected directly to a standarddisplay (DU-2) via a serial communication line, and only one AOP-1 can be connected to each DU-2. TheAOP-1 has 16 configurable LEDs and eight configurable buttons, which are programmed with the PC utilitysoftware. It can be used as an interface to the ML-2 units for indication of status and alarms together withbuttons for e.g. alarm acknowledge and mode selection.

Since a DU-2 is required for each AOP-1, the possible number of AOP-1 units is determined bythe number of DU-2 units.

The maximum distance between the DU-2 and the AOP-1 is 0.5 m.

AGC-4 manual, November 2011, UK Additional display and operator's panel



DU-2

Additional operator´s panel AOP-1

18.2.2 Connectors

DU-2: DC power supply and serial communication to/from the DU-2.

18.3 Description of option, Option X4

This option includes an additional operator’s panel (AOP-2) which can be connected to the standard displayvia a CANbus communication line. The AOP-2 has 16 configurable LEDs and eight configurable buttons,which are programmed with the PC utility software. It can be used as an interface to the ML-2 units for indica-tion of status and alarms together with buttons for e.g. alarm acknowledge and mode selection.

A maximum of five AOP-2 units can be connected to each ML-2 unit.



CAN 1 CAN 2


OFF

ON

2 1

End resistor

18.3.2 Connectors

CAN 1: DC supply and CANbus communication to/from other DU-2 or AOP-2 units.CAN 2: CANbus communication to/from other DU-2 or AOP-2 units and status relay output.End resistor: Dip switch for 120 Ohm end resistor for the CANbus communication.

Dip switch no. 2 is not to be used.

18.4 Functional description, Additional displays and operator's panels

Below is a principle diagram of the connection of the additional displays and operator’s panels.



ML-2

DU-2 DU-2 DU-2 AOP-2 AOP-2 AOP-2

AOP-1AOP-1AOP-1

Serial comm. and

DC power supplyDC power supply DC power supply DC power supply DC power supply DC power supply

CANbus

comm.

CANbus

comm.

CANbus

comm.

CANbus

comm.

CANbus

comm.

Serial comm. and

DC power supply

Serial comm. and

DC power supply

Serial comm. and

DC power supply

Only three AOP-2 units are shown in the diagram, but up to five units are supported.

Only one DU-2 has to be connected to the ML-2 unit. The rest of the displays and AOP units are connected toeach other with communication lines (serial or CANbus) and get their information through the DU-2 unit con-nected to the ML-2 unit.



18.5 Functional description, Display unit - DU-2

18.5.1 Wiring

It is recommended to keep a fair distance to power cables.


A DC/DC converter for the DC supply voltage and 2 x 1 m cable with an RJ45 plug in one endand stripped wires in the other end are included in the DU-2 delivery.



18.5.2 End resistor

2 units connected: Dip switch no. 1 has to be set to ON on both units.3 units connected: Dip switch no. 1 has to be set to ON on unit 1 and unit 3.More than 3 units connec-ted:

Dip switch no. 1 has to be set to ON on the first and the last unit on theCANbus line.

18.5.3 CAN ID configurationThe CAN ID on the DU-2 can be set from 0 to 3. If it is set to zero, the CANbus communication is deactivated.

The CAN ID selection is done in the following way:

1. On the DU-2, press the left , up and right buttons at the same time to activate a CAN IDselection menu.

2. Select the desired CAN ID with the up and down buttons and press ENTER.

The CAN ID of the DU-2 has now been selected.

The DU-2 which is connected to the ML-2 unit has to have CAN ID no. 1.

If the CANbus communication to other DU-2 or AOP-2 units are not used, the CAN ID should beset to zero.

18.5.4 Protocol selectionThe DU-2 contains three protocols for the data transmission between the ML-2 unit and the display. Normallythe protocol is set automatically, however if the display is used with older ML-2 units, it is necessary tochoose the protocol which supports these according to the following table.

Protocol Supports Comment

1 Std. ML-2 with software version 1.xx.x and 2.xx.x

2 AGC units with software version 1.xx.x and 2.xx.xPPM units with software version 2.xx.x

3 AGC units with software version 3.xx.x and 4.xx.xPPM units with software version 3.xx.x

Change of protocol is done like this:

1. On the DU-2, press the left , ENTER and right buttons at the same time to activate a protocolselection menu.

2. Select the desired protocol with the up and down buttons and press ENTER.



18.6 Functional description, Additional operator's panel - AOP-1

18.6.1 Front side view

As shown on the drawing, the configurable LEDs are named 1 to 16, and the buttons are named 1 to 8.

18.6.2 WiringThe AOP-1 is connected to the connection on the DU-2 named AOP-1 by means of the enclosed cable. Thisconnection handles the communication and power supply.

AOP-1

CAN 2

ML - 2

Standard display DU-2

OFF

ON

2 1

End resistor

DU-2


The maximum distance between the DU-2 and the AOP-1 is 0.5 m.

The cable for connection between the AOP-1 and DU-2 is included in the AOP-1 delivery.

18.6.3 CAN ID configurationThe ID of the AOP-1 is decided by the DU-2 unit to which it is connected.

18.6.4 ProgrammingThe programming of the AOP-1 is made with the PC utility software, which can be downloaded from www.de-if.com. Please refer to the Help function in the PC utility software for programming instructions.



18.7 Functional description, Additional operator's panel - AOP-2

18.7.1 Front side view

As shown on the drawing, the configurable LEDs are named 1 to 16, and the buttons are named 1 to 8.



18.7.2 Wiring

Standard display DU-2 Additional operator´s panel AOP-2

OFF

ON

Ap

p./B

oo

tl.

En

d R

es.

CAN 1

AOP-1

CAN 2

ML - 2

Re

d

Re

d/w

hite

Terminal block

OFF

ON

Ap

p./B

oo

tl.

En

d R

es.

CAN 1

Re

d

Re

d/w

hite

DIN Rail

5V DC

24V DC

+-

+-

Bla

ck

Bla

ck/W

hite

Bro

wn

/wh

ite

Bro

wn

/wh

ite

Re

dB

row

n/w

hite

Re

d/w

hite

Bla

ck/w

hite

Bla

ck

Bro

wn

6 - Black: GND

5 - Black/White: +5 VDC

4 - Brown: Not used

3 - Red: CAN L

2 - Brown/white: CAN GND

1 - Red/white: CAN H

6 - Black: Relay common

5 - Black/White: Relay NO

4 - Brown: Relay NC

3 - Red: CAN L

2 - Brown/white: CAN GND

1 - Red/white: CAN H

Left CAN port (CAN 1) Right CAN port (CAN 2)

1 2 1 2

Cable shield

CAN 2

1...61...6

Comm. to

next units

NC

Co

mm

on

NO

Status relay

A DC/DC converter for the DC supply voltage and 2 x 1 m cable with an RJ12 plug in one endand stripped wires in the other end is included in the AOP-2 delivery.

The cable between the terminal blocks should be shielded twisted pair.




18.7.3 End resistor

2 units connected: Dip switch no. 1 on both units should be set to ON.3 units connected: Dip switch no. 1 on unit 1 and unit 3 should be set to ON.More than 3 units connec-ted:

Dip switch no. 1 on the first and the last unit on the CANbus line shouldbe set to ON.

18.7.4 CAN ID configurationThe CAN ID for the AOP-2 can be changed by the following procedure:

1. Push button no. 7 and no. 8 at the same time to activate the CAN ID change menu, this will activate theLED for the present CAN ID number, and LED no. 16 will be flashing.

2. Use button no. 7 (increase) and button no. 8 (decrease) to change the CAN ID according to the table be-low.

3. Press button no. 6 to save the CAN ID and return to normal operation.

Selection of CAN ID:

CAN ID Indication of CAN ID selection

0 CANbus OFF: LED 16 flashes

1 LED 1 light steady + LED 16 flashes (default value)

2 LED 2 light steady + LED 16 flashes




18.7.5 Status relayThe status relay will activate approximately five seconds after power up.

18.7.6 ProgrammingThe programming of the AOP-2 is made with the PC utility software, which can be downloaded from www.de-if.com. Please refer to the Help function in the PC utility software for instructions regarding the programming.

18.7.7 Lamp test/dimmerThe AOP-2 has a separate push-button for the combined lamp test and dimmer functionality.

A short activation of the push-button will activate the lamp test function. If no further actionis done within three seconds, the AOP-2 will turn back to normal indication.

To activate the dimmer function, the push-button has to be pressed more times or continu-ously to reach the desired light intensity.

18.8 Functional description, Error handling

18.8.1 Duplicate CAN IDDU-2:If two units on the CANbus have the same CAN ID, the following will be displayed:



Warning: Two displays have same CAN ID Press Enter.

When ENTER is pressed, the CAN ID change menu will be displayed and another CAN ID can be selectedfor the unit.

AOP-2:If two units on the CANbus have the same CAN ID, LED no. 1 to 4 will flash quickly. In this case, press buttonno. 6 to jump into the CAN ID change menu and select another CAN ID for the unit.



19. Installation instructions19.1 General product information, AGC-3 product information

19.1.1 IntroductionThe AGC is part of the DEIF Multi-line 2 product family. Multi-line 2 is a complete range of multi-function gen-erator protection and control products integrating all the functions you need into one compact and attractivesolution.

The concept of the AGC is to offer a cost-effective solution to genset builders, who need a flexible generatorprotection and control unit for medium to large genset applications. Being part of the Multi-line product family,the standard functions can be supplemented with a variety of optional functions.

19.1.2 Type of productThe Automatic Genset Controller is a micro-processor based control unit containing all necessary functionsfor protection and control of a genset.

It contains all necessary 3-phase measuring circuits, and all values and alarms are presented on the LCDdisplay.

19.1.3 OptionsThe Multi-line 2 product range consists of different basic versions, which can be supplemented with the flexi-ble options needed to provide the optimum solution. The options cover e.g. various protections for generator,busbar and mains, voltage/VAr/PF control, various outputs, power management, serial communication, addi-tional operator display etc.

19.2 General product information, Standard functions

This chapter includes functional descriptions of standard functions as well as illustrations of the relevant appli-cation types. Flowcharts and single-line diagrams will be used in order to simplify the information.

In the following paragraphs, the standard functions are listed.

19.2.1 Operation modes Automatic Mains Failure Island operation Fixed power/base load Peak shaving Load takeover Mains power export Remote Maintenance

19.2.2 Engine control Start/stop sequences Run and stop coil Relay outputs for governor control

19.2.3 Generator protection (ANSI) 2 x reverse power (32) 5 x overload (32) 6 x overcurrent (50/51) 2 x overvoltage (59) 3 x undervoltage (27)

AGC-4 manual, November 2011, UK Installation instructions


3 x over-/underfrequency (81) Voltage-dependent overcurrent (51V) Current/voltage unbalance (60) Loss of excitation/overexcitation (40/32RV) Non-essential load/load shedding, 3 levels (I, Hz, P>, P>>) Multi-inputs (digital, 4-20 mA, 0-40V DC, Pt100, Pt1000 or VDO) Digital inputs

19.2.4 Busbar protection (ANSI) 3 x overvoltage (59) 4 x undervoltage (27) 3 x overfrequency (81) 4 x underfrequency (81) Voltage unbalance (60)

19.2.5 Display Prepared for remote mounting Push-buttons for start and stop Push-buttons for breaker operations Status texts

19.2.6 M-Logic Simple logic configuration tool Selectable input events Selectable output commands

19.3 General product information, Standard and optional applications

In the following sections, the standard and optional applications of the AGC will be presented. In addition, thecorrect application configuration for the different applications is listed. It is only possible to use the unit for oneof the purposes, e.g. AMF (Automatic Mains Failure). The selection must be made on site.

All units are supplied with AMF as factory setting.

19.3.1 Automatic Mains Failure, AMF

G

Controller

Load



No. Setting Setting

6071 Genset mode AMF AMF


G

Controller

Load

No. Setting Setting

6071 Genset mode Island operation Island operation

19.3.3 Fixed power/base load

G

Controller

Load

No. Setting Setting

6071 Genset mode Fixed power Fixed power

19.3.4 Peak shaving

G

Controller

Load

P/4-20 mA

TRANSDUCER



No. Setting Setting

6071 Genset mode Peak shaving Peak shaving

19.3.5 Load takeover

G

Controller

Load

P/4-20 mA

TRANSDUCER

No. Setting Setting

6071 Genset mode Load takeover Load takeover

19.3.6 Mains power export (fixed power to mains)

G

Controller

Load

P/4-20 mA

TRANSDUCER

No. Setting Setting

6071 Genset mode Mains power export Mains power export

19.3.7 Multiple gensets, load sharing

G

Controller

Load

G

Controller



No. Setting Setting

6071 Genset mode Island operation Island operation

19.3.8 Multiple gensets, power management

For information about the power management application, please refer to "Description of Op-tion G4, G5 and G8".

19.4 Mounting, AGC-3 mounting

19.4.1 Mounting of the unitThe unit is designed for mounting inside the switchboard. The display can be installed on the switchboarddoor and connected to the main unit with a display cable. The technical specifications include detailed infor-mation about:

Unit dimensions Panel cut-out Screw hole positions and dimensions

19.4.2 Panel cut-outIn order to ensure optimum mounting, the switchboard door must be cut out according to the panel cut-outillustration in the chapter Technical information.

19.4.3 Mounting instructionsThe unit can be mounted in two different ways:

1. Directly mounted on a DIN rail.2. Fastened with screws to the rear side of the cabinet. Six screw holes are available for this mounting

method.

DEIF recommends using the screw hole fastening.

19.5 Hardware, Board slot positions

The unit housing is divided into board slot positions. This means that the unit consists of a number of printedcircuit boards (PCB) mounted in numbered slots. The green terminal blocks are then mounted in the PCBs.Some of these board slots are standard and some are intended for options. The board slot positions are ar-ranged as illustrated below.



Slot type Option Slot #1 Slot #3 Slot #5 Slot #7

Terminals 1-28 37-64 73-89 98-125

Power supply Standard X

AC measurements Standard X

Engine interface Standard X

Load sharing G3 X

Power management G4/G5/G8 X

Engine communication H7 X

I/O extension M12 X

Slot type Option Slot #2 Slot #4 Slot #6 Slot #8

Terminals 29-34 65-72 90-97 126-133

Analogue controller outputs E1/E2 X

Analogue transducer outputs F1 X

Combination outputs EF2/EF4/EF5/EF6 X

Serial communication H2/H3/H8.2 X

Engine communication H5/H6 X

I/O extension cards M13.2 X

I/O extension cards M13.6/M14.6/M15 X

I/O extension cards M13.8/M14.8/H8.8 X

Plant management G7 X

Only hardware options, which will affect the hardware of the unit, are represented in the table.The software options will be seen through the PC utility software. The software options that arenot represented in the above table can be found in the data sheet.

19.5.1 Unit top side overviewAn overview of the terminals is presented below. The slot positions are as follows:

Ethernet

787776757473 96 979594929190 9389888785 8683 8482818079

727169 70686765 6662 6359 60 615856 575553 54 645251504947464443 45 4841403837 39 42

Service port Display

Ethernet

CAN BCAN A

Power

Self check okAlarm inhibit

1

4

9

5 6

3

7 8

2

1 :The numbers in the drawing above refer to the slot numbers indicated in the table below.



No. Slot

1 #1, terminal 1-28, power supply (standard)

2 #2, terminal 29-36, communication

3 #3, terminal 37-64, in-/outputs/load sharing

4 #4, terminal 65-72, governor, AVR, in-/outputs (standard)

5 #5, terminal 73-89, AC measuring (standard)

6 #6, terminal 90-97, in-/outputs

7 #7, terminal 98-125, engine I/F (standard)

8 #8, terminal 126-133, engine communication, in-/outputs

9 LED I/F

19.5.2 Terminal strip overviewsStandard unit



The hardware shown in slot #3 is option M12 and G3. For a detailed description of these op-tions, please refer to the option manuals.



Mains unit






BTB unit




19.5.3 Input/output listsIn the I/O lists, the following terms will be used in connection with the relay outputs:

NO means Normally OpenNC means Normally ClosedNE means Normally EnergisedND means Normally DeenergisedCom. means common terminal



19.5.4 Slot #1, power supply PCB


1 +12/24V DC 12/24V DC+/-30%

Power supply

2 0V DC

3 NC Status relay24V DC/1 A

Normally closed relay, processor/power supplystatus supervision4 Com.

5 NO Relay 05250V AC/8 A

Central alarm HORN/configurable

6 Com.

7 NC


Open mains breaker/configurable

9 Com.

10 NC


Close mains breaker (synchronising)/configurable

12 Com.

13 NC

14 NO Relay250V AC/8 A

Open generator breaker

15 Com.

16 NC

17 NO Relay250V AC/8 A

Close generator breaker (synchronising)

18 Com.

19 NC

20 Open collector 1 Transistor output/Relay 20 Pulse output 1, kWh counter/configurable

21 Open collector 2 Transistor output/Relay 21 Pulse output 2, kVArh counter/configurable

22 Com. Common Common terminal for terminals 20 and 21


24 Digital input 24 Optocoupler Mains breaker open/configurable

25 Digital input 25 Optocoupler Mains breaker closed/configurable

26 Digital input 26 Optocoupler Generator breaker open

27 Digital input 27 Optocoupler Generator breaker closed




19.5.5 Slot #1, power supply PCB - AGC mains unit

The I/O list below is for the AGC mains unit.


1 +12/24V DC 12/24V DC+/-30%

Power supply

2 0V DC

3 NC Status relay24V DC/1 A

Normally closed relay, processor/power supplystatus supervision4 Com.


Central alarm HORN/configurable

6 Com.

7 NC


Open mains breaker/configurable

9 Com.

10 NC


Close mains breaker (synchronising)/configurable

12 Com.

13 NC


Open tie breaker/configurable

15 Com.

16 NC


Close tie breaker/configurable

18 Com.

19 NC

20 Open collector 1 Transistor output/Relay 20 Pulse output 1, kWh counter/configurable

21 Open collector 2 Transistor output/Relay 21 Pulse output 2, kVArh counter/configurable

22 Com. Common Common terminal for terminals 20 and 21


24 Digital input 24 Optocoupler Mains breaker open/configurable

25 Digital input 25 Optocoupler Mains breaker closed/configurable

26 Digital input 26 Optocoupler Tie breaker open/configurable

27 Digital input 27 Optocoupler Tie breaker closed/configurable


19.5.6 Slot #2, serial communication (option H)Modbus (option H2)




29 DATA + (A) Modbus RTU, RS485

30 GND

31 DATA - (B)

32 Not used

33 DATA + (A)

34 Not used

35 DATA - (B)

36 Not used

The serial communication line should be terminated between DATA + and DATA - with a resistor equal to thecable impedance. The terminals 29/33 and 31/35 are internally connected.

Never connect the GND terminal 30 to earth. Only connect it to a third wire in the communica-tion cable!

Profibus (option H3)


29 DATA + (B) Pin 3 on 9 pole sub-D connectorPin 5 on 9 pole sub-D connectorPin 8 on 9 pole sub-D connector

30 GND

31 DATA - (A)

32 DATA + (B)

33 GND

34 DATA - (A)

35 Not used

36 Not used

Never connect the GND terminal 30 to earth. Only connect it to a third wire in the communica-tion cable!



19.5.7 Slot #2, external I/O module (option H8.2)


29 CAN-H CANbus card option H8.2

30 CAN-GND

31 CAN-L

32 CAN-H

33 CAN-GND

34 CAN-L

35 Not used

36 Not used

Terminals 29 and 32 are internally connected. Terminals 31 and 34 are internally connected.



19.5.8 Slot #3, load sharing control (option G3)


37 -5…0…5V DC Analogue I/O Active load sharing line

38 Com. Common Common for load sharing lines

39 -5…0…5V DC Analogue I/O Reactive load sharing

40 -10…0…10V DC Analogue I/O f/P setpoint (passive)

41 Common Common for 40/42

42 -10…0…10V DC Analogue I/O U/Q setpoint (passive)

43

Not used

44

45

46

47

48

49

50

51

52

53

54

55

56

57

58

59

60

61

62

63

64



19.5.9 Slot #3, 13 binary inputs and 4 relay outputs (option M12)


37

Not used38

39

40 -10/+10V DC Analogue I/O f/P setpoint


42 -10/+10V DC Analogue I/O U/Q setpoint

43 Binary input Optocoupler Configurable














57 NE/ND Relay 57250V AC/5 A

Configurable

58 Com.


Configurable

60 Com.


Configurable

62 Com.


Configurable

64 Com.



19.5.10 Slot #4, relay outputs (option M14.4, standard)



Generator GOV: Increase frequency/configurable

66 Com.


Generator GOV: Decrease frequency/configurable

68 Com.

69 Not used Relay 69250V AC/5 A

Configurable

70 Com.

71 Not used Relay 71250V AC/5 A

Configurable

72 Com.

19.5.11 Slot #4, analogue outputs for GOV/AVR or transducer (option E1)


65 Not used

66 +/-25 mA Configurable

67 0

68 Not used

69 Not used


71 0

72 Not used

19.5.12 Slot #4, analogue outputs for GOV/AVR or transducer (option EF2)


65 Not used


67 0

68 Not used

69 Not used

70 0(4)-20 mA Configurable

71 0

72 Not used



19.5.13 Slot #4, combination outputs for GOV/AVR or transducer (option EF4)



66 0

67 Not used

68 Not used

69 NO Relay 69

70 Com.

71 NO Relay 71

72 Com.

19.5.14 Slot #4, PWM output for GOV and combination output for AVR (option EF5)


65 +/-25 mA AVR setpoint output

66 0

67 PWM + PWM speed governor signal

68 PWM -

69 NO Relay output for AVR. Raise voltage

70 Com.

71 NO Relay output for AVR. Lower voltage

72 Com.

19.5.15 Slot #4, PWM output for GOV and combination output for AVR (option EF6)


65 Not used

66 Not used


68 +/-25 mA

69 PWM - PWM speed governor signal

70 PWM +


72 +/-25 mA

Connect PWM - to the engine battery negative and PWM + to the engine control system S-SPD(speed) input (called RATED SPEED on the ADEM controller and PRIMARY THROTTLE on thePEEC controller).



AVR control requires the D1 option.

19.5.16 Slot #4, analogue outputs for GOV/AVR or transducer (option E2)


65 Not used


67 0

68 Not used

69 Not used


71 0

72 Not used

19.5.17 Slot #5, AC measuring


73 I L1, s1 Generator current L1 x/1 A or x/5 A input

74 I L1, s2


76 I L2, s2


78 I L3, s2

79 U L1 Generator voltage L1 Max. 690V AC phase-phase value

80 Not used


82 Not used


84 UNEUTRAL Generator voltage neutral

85 U L1 Mains/bus voltage L1 Max. 690V AC phase-phase value

86 Not used


88 UNEUTRAL Mains/bus voltage neutral




19.5.18 Slot #5, AC measuring - AGC mains unit

The I/O list below is for the AGC mains unit.


73 I L1, s1 Mains current L1 x/1 A or x/5 A input

74 I L1, s2


76 I L2, s2


78 I L3, s2

79 U L1 Mains voltage L1 Max. 690V AC phase-phase value

80 Not used


82 Not used


84 UNEUTRAL Mains voltage neutral

85 U L1 Bus voltage L1 Max. 690V AC phase-phase value

86 Not used


88 UNEUTRAL Bus voltage neutral




19.5.19 Slot #5, AC measuring - AGC BTB unit

The I/O list below is for the AGC BTB unit.


73 I L1, s1 Bus A current L1 x/1 A or x/5 A input

74 I L1, s2


76 I L2, s2


78 I L3, s2

79 U L1 Bus A voltage L1 Max. 690V AC phase-phase value

80 Not used


82 Not used


84 UNEUTRAL Bus A voltage neutral

85 U L1 Bus B voltage L1 Max. 690V AC phase-phase value

86 Not used


88 UNEUTRAL Bus B voltage neutral


19.5.20 Slot #6, 7 digital inputs (option M13.6)



91 Binary input 91 Optocoupler Configurable









19.5.21 Slot #6, 4 relay outputs (option M14.6)


90 NE/ND Relay 90250V AC 5 A

Configurable

91 Com.


Configurable

93 Com.


Configurable

95 Com.


Configurable

97 Com.

19.5.22 Slot #6, 4 analogue inputs (option M15.6)


90 Analogue input 91 - Common Configurable

91 Analogue input 91 + 4-20 mA in







19.5.23 Slot #6, analogue outputs for GOV/AVR or transducer (option F1)


90 Not used

91 0 Transducer output

92 0(4)-20 mA

93 Not used

94 Not used

95 0 Transducer output

96 0(4)-20 mA

97 Not used



19.5.24 Slot #7, engine interface card (standard)


98 +12/24V DC 12/24V DC+/-30%

DC power supply

99 0V DC

100 MPU input 0.5-70V AC/10-10,000 Hz

Magnetic pick-up

101 MPU GND


Multi-input 1

103 B

104 C

105 A Multi-input 2

106 B

107 C

108 A Multi-input 3

109 B

110 C









119 NO Relay24V DC/5 A

Run coil


Start prepare

121 Com. Relay250V AC/5 A

Crank (starter)

122 NO

123 Com. Relay24V DC/5 A

Stop coil w/wire failure detection

124 NO

A1 CAN-H CANbus interface A(option G4, G5 or H7)A2 GND

A3 CAN-L

B1 CAN-H CANbus interface B(option G4 or G5)B2 GND

B3 CAN-L



19.5.25 Slot #7, engine interface card (standard) AGC mains/BTB


98 +12/24V DC 12/24V DC+/-30%

DC power supply

99 0V DC

100 MPU input 0.5-70V AC/10-10,000 Hz

Magnetic pick-up

101 MPU GND


Multi-input 1

103 B

104 C

105 A Multi-input 2

106 B

107 C

108 A Multi-input 3

109 B

110 C










Not used


Not used

121 Com. Relay250V AC/5 A

Not used

122 NO

123 Com. Relay24V DC/5 A

Not used

124 NO

A1 CAN-H CANbus interface A(option G4 or G5)A2 GND

A3 CAN-L

B1 CAN-H CANbus interface B(option G4 or G5)B2 GND

B3 CAN-L



19.5.26 Slot #8, engine interface communication (option H5)


126 Not used CANbus-based engine interface communication

127 Not used

128 CAN-L

129 GND

130 CAN-H

131 CAN-L

132 GND

133 CAN-H

19.5.27 Slot #8, Cummins engine interface communication (option H6)


126 Not used Modbus RTU (RS485)

127 DATA - (B)

128 Not used

129 DATA + (A)

130 Not used

131 DATA - (B)

132 GND

133 DATA + (A)

19.5.28 Slot #8, 7 digital inputs (option M13.8)












19.5.29 Slot #8, 4 relay outputs (option M14.8)



Configurable

127 Com.


Configurable

129 Com.


Configurable

131 Com.


Configurable

133 Com.

19.5.30 Slot #8, external I/O module (option H8.8)


126 Not used CANbus card option H8.8

127 Not used

128 CAN-L

129 GND

130 CAN-H

131 CAN-L

132 GND

133 CAN-H

Terminals 133 and 130 are internally connected. Terminals 131 and 128 are internally connec-ted.

19.6 Wirings, AC connections

The Multi-line 2 unit can be wired up in 1-phase, 2-phase or 3-phase configuration.

Contact the switchboard manufacturer for accurate information about required wiring for thespecific application.

19.6.1 Neutral line (N)When three-phase distribution systems are used, the neutral line (N) is only necessary if it is a three-phase +neutral system. If the distribution system is a three-phase system without neutral, then leave the terminals 84and 88 empty.

19.6.2 Current transformer groundingThe current transformer ground connection can be made on s1 or s2 connection, whichever is preferred.



19.6.3 FusesIf the cables are protected with fuses, then use 2 A, slow blow.

19.6.4 Breaker wiringThe breaker off wiring is an example only.

19.6.5 3-phaseAMF, fixed power, peak shaving, load takeover, mains power export.



19.6.6 Single phase



19.6.7 2-phase L1L2



19.6.8 2-phase L1L3 (split phase)



19.6.9 Island mode and power management (option G4/G5/G8)

1-phase and 2-phase systems also supported.



19.6.10 Power management (option G5), AGC mains




19.6.11 Power management (option G5), dual mains - AGC mains




19.6.12 Power management (option G5), AGC BTB


19.7 Wirings, DC connections

19.7.1 Load sharing lines (option G3)

37 38 39

PS COMMON QS

LOAD SHARING LINES

±0...5 ±0...5

V DC V DC

Multi-line 2

37 38 39

PS COMMON QS

LOAD SHARING LINES

±0...5 ±0...5

V DC V DC

Multi-line 2

37 38 39

PS COMMON QS

LOAD SHARING LINES

±0...5 ±0...5

V DC V DC

Multi-line 2

Always use screened cable



19.7.2 Digital inputs

Battery positive to input: Battery negative to input:

Multi-line 2

23

28 (COM.)

Switch

12/24V DC

Multi-line 2

23

28 (COM.)

Switch

12/24V DC

Emergency stop:

Multi-line 2

118

99 (COM.)

12/24V DC

0V DC

19.7.3 Analogue inputs4-20 mA (option M15)

Active transducer

91

0V DC

Multi-line 2

Analogue input 91

90 (Common)

+12/24V DC + +- -

4-20 mA

transducer

Measurement



Passive transducer

91

0V DC

Multi-line 2

Analogue input 91

90 (Common)

+12/24V DC + -

4-20 mA

transducer

Measurement

V DC sensor

91

Multi-line 2

Analogue input 91

90 (Common)

0-10V DC

sensor

R = 450 Ω

External setpoints (option G3)The setpoint inputs are passive, i.e. an external power source is needed. This can be an active output frome.g. a PLC, or a potentiometer can be used.

0-10V DC input using potentiometer

Multi-line 2

40 or 42

41 (Common)

10V DC

0V DC

Ø

Ø

2000 Ohm ¼ W

potentiometer

+/-10V DC input using potentiometer

Multi-line 2

40 or 42

41 (Common)

10V DC

-10V DC

Ø

Ø

2000 Ohm ¼ W

potentiometer

0V DC Ø

19.7.4 Multi-inputsThe multi-inputs are placed in slot #7, the terminal numbers for the individual multi-inputs can be seen in the"Input/output list".

0(4)-20 mA



Active transducer

0V DC

Multi-line 2

Multi-input+12/24V DC + +

- -

4-20 mA

transducer

Measurement

A

B

C

Passive transducer

0 V DC

Multi-line 2

Multi-input+12/24V DC + -

4-20 mA

transducer

Measurement

A

B

C

If the passive sensor has its own battery supply, the voltage must not exceed 30V DC.

19.7.5 Digital inputs

Multi-line 2

Multi-input

A

B

C

R

The resistor is only mounted if wire fail supervision is required. The value of the resistorshould be 270 Ω +/-10%.

19.7.6 Pt100/Pt1000

2-wireMulti-line 2

Multi-input

A

B

C

Pt100/1000

3-wireMulti-line 2

Multi-input

A

B

C

Pt100/10000

I

P

19.7.7 VDO

1-wire 2-wireMulti-line 2

Multi-input

A

B

C

VDO Multi-line 2

Multi-input

A

B

C

VDO



19.7.8 0-40V DCMulti-line 2

Multi-input

A

B

C

Battery

0-40V DC

0V DC

19.7.9 RPM inputMagnetic pick-up (MPU)

Multi-line 2

100

MPU

Output

101

NPN sensorMulti-line 2

100

NPN

Output

101

+V DC

0V DC

R+12/24V DC

0V DC

C

C

C = 22 nF, 100V foil typeR = 1200Ω@24V DC, 600Ω@12V DC

PNP sensorMulti-line 2

100

PNP

Output

101

+V DC

0V DC

+12/24V DC

0V DC

C

CR

C = 22 nF, 100V foil typeR = 1200Ω@24V DC, 600Ω@12V DC

Charger, W outputMulti-line 2

100

Charger

W

101

C

C = 22 nF, 100V foil type



19.7.10 Stop coil

Multi-line 2

+12/24V DC

123

124

0V DC

Stop coilA1

A2

Remember to mount the free wheel diode.

19.7.11 Transistor outputs (open collector outputs)The open collector outputs can be used as kWh and kVArh counter outputs or as relay outputs. The outputsare low power outputs. For that reason, one of the following circuits must be applied.

External counter: Relay outputs:

20 kWh

Multi-line 2

22 (Com. For 20/21)

External

counter

+12/24 VDC

0 VDC

0,5 µF 100 V

20 (Relay 20)

Multi-line 2

22 (Common)

+12/24 VDC

0 VDC

Relay

A1

A2

Connection to PLC:

20 kWh

Multi-line 2

22 (Com. For 20/21)

+12/24 VDC

0 VDC

4,7 kΩPLC

Input (positive)



Remember to mount the free wheel diode.

Maximum load on the open collector outputs is 10 mA at 24V DC.

19.8 Wirings, Communication

19.8.1 CANbus (option G4/G5/G8)Examples with three AGC units connected, e.g. one AGC mains and two generator AGC units.

It is not possible to mix CANbus interface A and B.

Multi-line 2

CANbus interface A

A1 A2 A3

H GND L

Multi-line 2

CANbus interface A

A1 A2 A3

H GND L

Multi-line 2

CANbus interface A

A1 A2 A3

H GND L

120 Ω 120 Ω

Multi-line 2

CANbus interface B

B1 B2 B3

H GND L

Multi-line 2

CANbus interface B

B1 B2 B3

H GND L

Multi-line 2

CANbus interface B

B1 B2 B3

H GND L

120 Ω 120 Ω

Connect shield to earth at one end only. Shield ends must be insulated with tape or insulationtubing.

Use shielded twisted cable.

End resistor R = 120 Ohm.



19.8.2 Modbus (option H2)Connection with 2-wire screened cable (recommended):

Multi-line 2DA

TA

+ (A

)

29 30 31

DA

TA

(GN

D)

DA

TA

- (B)

Multi-line 2DA

TA

+ (A

)

29 30 31

DA

TA

(GN

D)

DA

TA

- (B)

Multi-line 2DA

TA

+ (A

)

29 30 31

DA

TA

(GN

D)

DA

TA

- (B)

DA

TA

- (B)

PLC or other device

DA

TA

(GN

D)

DA

TA

+ (A

)

Connect shield to ground at one end only. Shield ends must be insulated with tape or insula-tion tubing.




Connection with 3-wire shielded cable:Multi-line 2D

AT

A +

(A)

29 30 31

DA

TA

(GN

D)

DA

TA

- (B)

Multi-line 2DA

TA

+ (A

)

29 30 31

DA

TA

(GN

D)

DA

TA

- (B)

Multi-line 2DA

TA

+ (A

)

29 30 31

DA

TA

(GN

D)

DA

TA

- (B)

DA

TA

- (B)

PLC or other device

DA

TA

(GN

D)

DA

TA

+ (A

)



This solution is only feasible if the COM line is insulated. Check PLC/other device before con-necting.

A non-insulated COM line may result in damage to the equipment.

Normally, the Modbus does not need bias resistors (end terminators). These are only neededin case of very long lines and/or many nodes (>32) on the Modbus network. If bias resistorsare needed, the calculation should be based on the following data:

- A line internal pull-up bias resistor: 22 kΩ- B line internal pull-down bias resistor: 22 kΩ- Receiver input sensitivity: +/-200 mV- Receiver input impedance: 12 kΩ

Cable: Belden 3105A or equivalent. 22 AWG (0.6 mm2) twisted pair, shielded, <40 mΏ/m, min.95% shield coverage.



19.8.3 Profibus DP (option H3)Connection with 2-wire screened cable (recommended):

Multi-line 2DA

TA

+ (B

)

29 30 31

CO

M

DA

TA

- (A)

Multi-line 2DA

TA

+ (B

)

29 30 31

CO

M

DA

TA

- (A)

Multi-line 2DA

TA

+ (B

)

29 30 31

CO

M

DA

TA

- (A)

DA

TA

- (A)

PLC or other device

CO

M

DA

TA

+ (B

)



19.8.4 CANbus engine communication (option H5)Connection with 2-wire screened cable (recommended):

Multi-line 2

CA

N-H

133 132 131

CA

N-G

ND

CA

N-L

CA

N-L

ECM

engine control module

CA

N-G

ND

CA

N-H

120 Ω

120 Ω



Connection with 3-wire shielded cable:Multi-line 2

CA

N-H

133 132 131

CA

N-G

ND

CA

N-L

CA

N-L

ECM


CA

N-G

ND

CA

N-H

120 Ω

120 Ω




The terminating resistor at the engine side might not be needed, please refer to the enginemanufacturer’s literature.



19.8.5 Cummins GCS (option H6)Multi-line 2, option H6

DA

TA

- B

131 132 133

DA

TA

(GN

D)

DA

TA

+ A

Engine controller,

connector 06

DA

TA

- B

18 20 31

DA

TA

(GN

D)

DA

TA

+ A

RR



Normally, the communication does not need bias resistors (end terminators). These are onlyneeded in case of very long lines between the two modules. If bias resistors are needed, thecalculation should be based on the following data:

- A line internal pull-up bias resistor: 22 kΩ- B line internal pull-down bias resistor: 22 kΩ- Receiver input sensitivity: +/-200 mV- Receiver input impedance: 12 kΩ

Cable: Belden 3105A or equivalent. 22 AWG (0.6 mm2) twisted pair, shielded, <40 mΏ/m, min.95% shield coverage.



19.8.6 CANbus engine communication (option H7)Multi-line 2

CA

N-H

A1 A2 A3

CA

N-G

ND

CA

N-L

CA

N-L

ECM


CA

N-G

ND

CA

N-H

120 Ω

120 Ω




The terminating resistor at the engine side might not be needed, please refer to the enginemanufacturer’s literature.

19.8.7 External I/O module (option H8)

12

0 Ω

CAN-H

CAN-L

CANopen

CANopen

BE

CK

HO

FF

1 2

3 4

5 6

7 8

ON

DIP

Op

tion

H 8

.8

Op

tion

H 8

.22

9

13

31

31

31

12

0 Ω

Multi-line 2



19.8.8 Display cable (option J)A standard computer extension cable can be used (9-pole SUB-D male/female plugs) or a cable can be tail-ored.

4

5

6

7

8

9

2

1

3

1

2

3

4

5

6

7

8

9

9-p SUB D

male

9-p SUB D

female

Connect shield to plug metallic casing

Wires min. 0.22 m2, max. cable length 6 m.Cable types: Belden 9540, BICC H8146, Brand Rex BE57540 or equivalent.



19.9 Technical information, AGC-3

19.9.1 Technical specifications

Accuracy Class 1.0Class 0.5 with option Q1Positive, negative and zero sequence alarms: class 1 within 5% voltage unbalanceClass 1.0 for negative sequence currentFast overcurrent: 3% of 350%*InAnalogue outputs: class 1.0 according to total rangeOption EF4: class 4.0 according to total rangeTo IEC/EN60688

Operatingtemperature

-25…70°C (-13...158°F)(UL/cUL Listed: max. surrounding air temperature: 55°C/131°F)

Storage tem-perature

-40…70°C (-40...158°F)

Climate 97% RH to IEC 60068-2-30

Measuringvoltage

100-690V AC +/-20%(UL/cUL Listed: 480V AC phase-phase)Consumption: max. 0.25 VA/phase

Measuringcurrent

-/1 or -/5 A AC(UL/cUL Listed: from CTs 1-5 A)Consumption: max. 0.3 VA/phase

Current over-load

4 x In continuously20 x In, 10 sec. (max. 75 A)80 x In, 1 sec. (max. 300 A)

Measuringfrequency

30...70 Hz

Aux. supply Terminals 1 and 2: 12/24V DC (8...36 V continuously, 6 V 1 sec.). Max. 11 W consump-tionTerminals 98 and 99: 12/24V DC (8...36 V continuously, 6 V 1 sec.). Max. 5 W consump-tionThe aux. supply inputs are to be protected by a 2 A slow blow fuse. (UL/cUL Listed: AWG24)

Binary inputs Optocoupler, bi-directionalON: 8...36V DCImpedance: 4.7 kΩOFF: <2V DC

Analogue in-puts

-10...+10V DC: not galvanically separated. Impedance: 100 kΩ0(4)...20 mA: impedance 50 Ω. Not galvanically separatedRPM (MPU): 2...70V AC, 10...10000 Hz, 250...3000 Ω

Multi-inputs 0(4)...20 mA: 0-20 mA, +/-1%. Not galvanically separatedBinary: max. resistance for ON detection: 100 Ω. Not galvanically separatedPt100/1000: -40...250°C, +/-1%. Not galvanically separated. To IEC/EN60751VDO: 0-1700 Ω, +/-2%. Not galvanically separatedV DC: 0...40V DC, +/-1%. Not galvanically separated



Relay outputs Electrical rating: 250V AC/30V DC, 5 A. (UL/cUL Listed: 250V AC/24V DC, 2 A resistiveload)Thermal rating @ 50°C: 2 A: continuously. 4 A: ton= 5 sec., toff = 15 sec.(Unit status output: 1 A)

Open collec-tor outputs

Supply: 8...36V DC, max. 10 mA

Analogue out-puts

0(4)...20 mA and +/-25 mA. Galvanically separated. Active output (internal supply). Loadmax. 500 Ω. (UL/cUL Listed: max. 20 mA output)Update rate: transducer output: 250 ms. Regulator output: 100 ms

Load sharinglines

-5...0...+5V DC. Impedance: 23.5 kΩ

Galvanic sep-aration

Between AC voltage, AC current and other I/Os: 3250V AC, 50 Hz, 1 min.Between analogue outputs and other I/Os: 500V DC, 1 min.Between binary input groups and other I/Os: 500V DC, 1 min.

Responsetimes(delay set tomin.)

Busbar:Over-/undervoltage: <50 msOver-/underfrequency: <50 msVoltage unbalance: <250 ms

Generator:Reverse power: <250 msOvercurrent: <250 msFast overcurrent: <40 msDirectional overcurrent: <150 msOver-/undervoltage: <250 msOver-/underfrequency: <350 msOverload: <250 msCurrent unbalance: <250 msVoltage unbalance: <250 msReactive power import: <250 msReactive power export: <250 msVoltage-dependent I>: <250 msNegative sequence I: <500 msNegative sequence U: <500 msZero sequence I: <500 msZero sequence U: <500 msOverspeed: <500 msDigital inputs: <250 msEmergency stop: <200 msMulti-inputs: 800 msWire failure: <600 ms

Mains:df/dt (ROCOF): <130 ms (4 periods)Vector jump: <40 msPositive sequence: <60 msTime-dependent undervoltage, Ut<: <50 msUndervoltage and reactive power low, UQ<: <250 ms



Mounting DIN-rail mount or base mount with six screws

Safety To EN 61010-1, installation category (overvoltage category) III, 600 V, pollution degree 2To UL 508 and CSA 22.2 no. 14-05, overvoltage category III, 300 V, pollution degree 2

EMC/CE To EN 61000-6-1/2/3/4. IEC 60255-26. IEC 60533 power distribution zone. IACS UR E10power distribution zone

Vibration 3…13.2 Hz: 2 mmpp. 13.2…100 Hz: 0.7 g. To IEC 60068-2-6 & IACS UR E1010…60 Hz: 0.15mmpp. 60…150 Hz: 1 g. To IEC 60255-21-1 Response (class 2)10…150 Hz: 2 g. To IEC 60255-21-1 Endurance (class 2)

Shock (basemount)

10 g, 11 ms, half sine. To IEC 60255-21-2 Response (class 2)30 g, 11 ms, half sine. To IEC 60255-21-2 Endurance (class 2)50 g, 11 ms, half sine. To IEC 60068-2-27

Bump 20 g, 16 ms, half sine. To IEC 60255-21-2 (class 2)

Material All plastic materials are self-extinguishing according to UL94 (V1)

Plug connec-tions

AC current: 0.2-4.0 mm2 stranded wire. (UL/cUL Listed: AWG 18)AC voltage: 0.2-2.5 mm2 stranded wire. (UL/cUL Listed: AWG 20)Relays: (UL/cUL Listed: AWG 22)Terminals 98-116: 0.2-1.5 mm2 stranded wire. (UL/cUL Listed: AWG 24)Other: 0.2-2.5mm2 stranded wire. (UL/cUL Listed: AWG 24)Display: 9-pole Sub-D femaleService port: USB A-B

Protection Unit: IP20. Display: IP52 (IP54 with gasket: option L). (UL/cUL Listed: Type CompleteDevice, Open Type). To IEC/EN 60529

Governors Multi-line 2 interfaces to all governors, including GAC, Barber-Colman, Woodward andCumminsSee interfacing guide at www.deif.com

Approvals UL/cUL Listed to UL508

UL markings Wiring: use 60/75°C copper conductors onlyMounting: for use on a flat surface of type 1 enclosureInstallation: to be installed in accordance with the NEC (US) or the CEC (Canada)

AOP-2:Maximum ambient temperature: 60°CWiring: use 60/75°C copper conductors onlyMounting: for use on a flat surface of type 3 (IP54) enclosure. Main disconnect must beprovided by installerInstallation: to be installed in accordance with the NEC (US) or the CEC (Canada)

DC/DC converter for AOP-2:Tightening torque: 0.5 Nm (4.4 lb-in)Wire size: AWG 22-14

Weight Base unit: 1.6 kg (3.5 lbs.)Option J1/J3/J4/J6/J7: 0.2 kg (0.4 lbs.)Option J2: 0.4 kg (0.9 lbs.)Display: 0.4 kg (0.9 lbs.)



19.10 Technical information, Unit dimensions

Display or AOP

220 (8.661)

16

5 (

6.4

96

)

14

4 (

5.6

69

)

11

5 (

4.5

28

)

220 (8.661)

115 (4.528)

20.0 (0.787)

Dimensions are given in mm (inches).

19.11 Technical information, Panel cut-out

Required space 222X115mm

Gasket outer 186X77mm

Screws for fastning:

3.5mm selfcutting threads

max. depth in display 9 mm

26.0

= =

=

=

50.5

66

.0

26.0

61.0

174.0

15

.0

41

.0



Dimensions are given in mm.



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AGC 4 Manual

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