we are facing the problem sometimes in engine starting, we used 6165 frequency detection for the running feedback and frequency setting is 32HZ but after cranking frequency does not reach at set value.

1 comments:

Mr. Anderson

February 28, 2025

The engine starting issue with the Deif AGC-4 Mk II could be due to the 6165 frequency detection level setting. The frequency detection level range is specified as 20-35 Hz. If the frequency is set at 32 Hz, it is close to the upper limit. If the engine does not reach this frequency consistently or there are fluctuations, the controller may not detect a successful start, triggering a start failure alarm. Adjusting the frequency detection setting or ensuring stable frequency output within the acceptable range may resolve the issue.

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Summary of Contents for Deif AGC-4 Mk II

Page 1 DESIGNER'S HANDBOOK AGC-4 Mk II DEIF A/S · Frisenborgvej 33 · DK-7800 Skive Tel.: +45 9614 9614 · Fax: +45 9614 9615 Document no.: 4189341275A info@deif.com · www.deif.com SW version: 6.00.0 or later...
Page 2: Table Of Contents
1. Introduction 1.1 About the Designer's Handbook ....................................... 1.1.1 General purpose ..........................................1.1.2 Intended users ............................................. 1.1.3 Options ..............................................1.1.4 Parameter list ............................................1.1.5 Glossary ..............................................1.2 Warnings, legal information and safety ..................................1.2.1 Warnings and notes .......................................... 1.2.2 Factory settings ..........................................
Page 3 2.6 Single-line diagrams (no power management) ............................... 2.6.1 Automatic Mains Failure ....................................... 2.6.2 Island operation ..........................................2.6.3 Fixed power/base load ........................................2.6.4 Peak shaving ............................................. 2.6.5 Load takeover ........................................... 2.6.6 Mains power export ........................................2.6.7 Multiple gensets, load sharing (hardware option M12 required) .........................
Page 4 3.7 Over-excitation ............................................3.8 Voltage-dependent (restraint) over-current ................................3.9 Decision of measurements ........................................ 4. PID regulator for governor and AVR 4.1 Description of PID controller ......................................4.2 Controllers ..............................................4.3 Principle drawing ............................................. 4.4 Proportional regulator .......................................... 4.4.1 Speed range ............................................
Page 5 6.1.2 Analogue tacho feedback ......................................6.1.3 Oil pressure ............................................. 6.1.4 Double starter ..........................................6.2 Running output ............................................6.3 Idle running .............................................. 6.3.1 Description ............................................6.3.2 Examples ............................................6.3.3 Configuration of digital input ..................................... 6.3.4 Temperature-dependent idle start-up ................................... 6.3.5 Inhibit ..............................................
Page 6 6.14 Oil renewal function .......................................... 6.15 Breaker functions ..........................................6.15.1 Breaker types ..........................................6.15.2 Breaker position failure ......................................6.15.3 Breaker spring load time ......................................6.15.4 Breaker spring load time principle ..................................6.15.5 Racked out breaker ........................................6.16 Digital mains breaker control ......................................
Page 7 6.37.1 Function descriptions ........................................ 6.38 Multi-inputs ............................................6.39 Input function selection ........................................6.40 Wire fail detection ..........................................6.41 External analogue set points ....................................... 6.41.1 External analogue set point terminals ................................6.41.2 Other sources of external analogue set points .............................. 6.42 Outputs ..............................................
Page 8: Introduction
By default, a genset controller. With option G5, also a mains or BTB controller. AGC-4 Mk II AGC-4 Mk II With option G7, also a group or plant controller. AGC-4 Mk II is based on AGC-4, with updated hardware. Automatic Load Controller...
Page 9: Warnings, Legal Information And Safety
Menu (XXXX) A group of parameters. M-Logic The PLC-type tool accessible from the utility software. Multi-line-2 ML-2 A DEIF platform, which includes the AGC-4 Mk II. Nominal power P nom Nominal reactive power Q nom Nominal voltage U nom A configurable setting (sometimes also called Channel in the PC utility...
Page 10: Factory Settings
1.3 Legal information and disclaimer DEIF takes no responsibility for installation or operation of the generator set or switchgear. If there is any doubt about how to install or operate the engine/generator or switchgear controlled by the Multi-line 2 unit, the company responsible for the installation or the operation of the equipment must be contacted.
Page 11: Functions
2. Functions 2.1 Standard functions This chapter includes functional descriptions of standard functions as well as illustrations of the relevant application types. Flowcharts and single-line diagrams will be used in order to simplify the information. The standard functions are listed in the following paragraphs. 2.1.1 Operation modes •...
Page 12: M-Logic
• Push-buttons for breaker operations • Status texts Alternatively, you can use TDU 107. 2.1.6 M-Logic • Simple logic configuration tool • Selectable input events • Selectable output commands 2.2 AC configuration The AGC is designed to measure voltages between 100 and 690 V AC. The AC wiring diagrams are shown in the Installation Instructions.
Page 13: Split Phase System
INFO The AGC has two sets of BB transformer settings, which can be enabled individually in this measurement system. 2.2.2 Split phase system This is a special application where two phases and neutral are connected to the AGC. The AGC shows phases L1 and L3 in the display.
Page 14: Nominal Settings
INFO The AGC has two sets of BB transformer settings, which can be enabled individually in this measurement system. 2.3 Nominal settings The AGC holds four sets of nominal settings, configured in channels 6001 to 6036. It is possible to switch between the nominal settings 1 to 4, to match different voltages and frequencies.
Page 15: Scaling
Table 2.2 AOP example Event A Event B Event C Output Button07 Not used Not used Command Parameter set, Set parameter 1 Button08 Not used Not used Command Parameter set, Set parameter 2 INFO See the Help file in the PC utility software for details. Four nominal settings of GOV/AVR offsets Use menu 6006 to select the required set of nominal settings (1 to 4 ).
Page 16: Applications
With up to 8 x ALC-4 Remote maintenance with one genset Requires option H12.x and a remote maintenance box from DEIF. Remote maintenance with multiple gensets Requires options T4, G5, H12.x and a remote maintenance box from DEIF. Genset mode Running mode Auto...
Page 17: Amf (No Back Synchronisation)
Genset mode Running mode Multiple gensets, analogue load sharing (hardware option M12) Multiple gensets, power management Remote maintenance with one genset INFO For a general description of the available running modes, see Running modes. 2.4.2 AMF (no back synchronisation) Auto mode description The controller automatically starts the genset and switches to generator supply at a mains failure after an adjustable delay time.
Page 18: Island Operation
INFO For a general description of the available running modes, see Running modes. 2.4.4 Island operation Auto mode description The controller automatically starts the genset and closes the generator breaker at a digital start command. When the stop command is given, the generator breaker is tripped, and the genset will be stopped after a cooling down period. The start and stop commands are used by activating and deactivating a digital input or with the time-dependent start/stop commands.
Page 19 Stop signal Power set point Power ramp [%/s] GB closed Time [sec] Ramp up, Ramp down read from load share line Ramp up with load steps When the GB is closed, the power set point continues to rise in ramp-up steps, determined by the number of steps in menu 2615. 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 the configured delay time, ramp to 40 %, wait, ramp to 60 %, wait and then ramp to the present power set point.
Page 20: Q Ramp
determines if the ramp 2 is activated by droop or M-Logic. If automatic "ramp selection" is activated, then the second ramp is enabled during power droop. If it is disabled, then the second ramp can only be activated by M-Logic. 2.4.6 Q ramp A ramp function for reactive power regulation can be activated.
Page 21: Warm Up Ramp
INFO The values in menu 7050 set the cos phi. This is not the PF value displayed in the display. Cos phi and PF are only equal if it is a true sinusoidal wave. INFO For a general description of the available running modes, see Running modes.
Page 22 A 4 to 20 mA transducer is used for indication of the power imported from the mains, see Mains power transducer. Diagram, peak shaving – example Peak/total power Max. mains import level Mains power Genset start level Genset stop level Generator power Genset minimum load STOP...
Page 23: Load Takeover
INFO For a general description of the available running modes, see Running modes. 2.4.10 Load takeover Auto mode description - Back synchronising ON The purpose of the load takeover mode is to transfer the load imported from the mains to the genset for operation on generator supply only.
Page 24: Mains Power Export (Fixed Power To Mains)
Semi-auto mode description When the generator breaker is closed and the mains breaker is opened, the controller will use the nominal frequency as set point for the speed governor. If AVR control is used, the nominal voltage is used as set point. When the generator is paralleled to the mains, it will be controlled so the imported power from the mains will be kept at 0 kW.
Page 25: Mains Power Transducer
When the generator is paralleled to the mains, it will be controlled according to the mains power export set point. If AVR control is used, then the set point will either be adjusted power factor or reactive power (7050 Fixed power set). INFO For a general description of the available running modes, see Running...
Page 26: Mains Reactive Power Or Voltage Transducer
P measurement from a transducer Text Parameter Default Range Description Transducer Range 7261 0 kW 0 to 20000 kW* Maximum active power Transducer Range 7262 0 kW -20000 to 0 kW* Minimum active power Multi input 102 (transducer) Mains P measure 7263 Multi input 102 Selection of the analogue input...
Page 27: Running Modes
2.5 Running modes 2.5.1 Semi-auto mode The controller can be operated in semi-auto mode. Semi-auto means that the controller will not initiate any sequences automatically, 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.
Page 28: Manual Mode
The settings for the test function are set up in menu 7040. Parameter Item Range Default Notes 7041 Set point 1 to 100 % 80 % Load set point when paralleling to mains. 7042 Timer 0.0 to 999.0 min 5.0 min Engine run time during the test period.
Page 29: Block Mode
Command Description Comment The start sequence is initiated and continues until the genset starts or the Start No regulation. maximum number of start attempts has been reached. The genset will be stopped. After disappearance of the running signal, the stop Stop sequence will continue to be active in the "extended stop time"...
Page 30: Single-Line Diagrams (No Power Management)
CAUTION 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. Block mode on a mains controller If the mains controller is in block mode, it cannot perform any breaker operations. If any breaker is closed when the mains controller is put into block mode, the mains breaker will be opened, but the tie breaker will remain closed to ensure the genset's ability to support the load.
Page 31: Island Operation
2.6.2 Island operation Load Controller 2.6.3 Fixed power/base load Load Controller 2.6.4 Peak shaving TRANSDUCER 4-20 mA Load Controller DESIGNER'S HANDBOOK 4189341275A EN Page 31 of 196...
Page 32: Load Takeover
2.6.5 Load takeover TRANSDUCER 4-20 mA Load Controller 2.6.6 Mains power export TRANSDUCER 4-20 mA Load Controller DESIGNER'S HANDBOOK 4189341275A EN Page 32 of 196...
Page 33: Multiple Gensets, Load Sharing (Hardware Option M12 Required)
2.6.7 Multiple gensets, load sharing (hardware option M12 required) Load Controller Controller 2.7 Single-line diagrams with power management The following single-line diagrams show a variety of AGC applications that use power management (option G5). More information See Option G7 Extended power management for information about using group and plant controllers. 2.7.1 Island operation Display 1 Display 2...
Page 34: Parallel To Mains
2.7.2 Parallel to mains Display mains Mains Mains AGC Mains breaker (MB) Consumers breaker (TB) Display 1 Display 2 Busbar AGC Genset AGC Genset Generator Generator breaker breaker (GB 1) (GB 2) Diesel generator set 1 Diesel generator set 2 DESIGNER'S HANDBOOK 4189341275A EN Page 34 of 196...
Page 35: Multiple Mains
2.7.3 Multiple mains Multiple mains with two mains, two tie breakers, one bus tie breaker and four gensets Optional Optional AOP 1 AOP 2 AOP 1 AOP 2 Display Display Display Display Mains 17 Mains 18 Mains Mains breaker breaker AGC Mains AGC Mains (MB 17)
Page 36: Automatic Transfer Switch
2.7.4 Automatic transfer switch ATS plant, Mains controller Display Mains Mains OK AGC Mains Consumers ON/OFF breaker (TB) Display 1 Display 2 Display 3 Busbar AGC Genset AGC Genset AGC Genset Diesel generator 1 Diesel generator 2 Diesel generator 3 INFO The simple ATS function (a Mains OK signal is sent to an AGC digital input) is shown here.
Page 37: Energy Management System
2.7.5 Energy management system CAN bus AGC Mains ASC Solar AGC Genset ASC Battery 2.7.6 Remote maintenance AGC Genset Load Relay More information See the Operator’s manual of the remote maintenance box for more information. 2.8 Flowcharts Using flowcharts, the principles of the most important functions will be illustrated in the next sections. The functions included are: •...
Page 38: Mode Shift
• MB close sequence • GB close sequence • Fixed power • Load takeover • Island operation • Peak shaving • Mains power export • Automatic Mains Failure • Test sequence INFO The flowcharts on the following pages are for guidance only. For illustrative purposes, the flowcharts are simplified in some extent.
Page 39: Mb Open Sequence
2.8.2 MB open sequence Start MB closed Load take Mains failure over Deload MB Load too Load = 0 Alarm high Open MB Alarm ”MB MB open open failure” DESIGNER'S HANDBOOK 4189341275A EN Page 39 of 196...
Page 40: Open Sequence
2.8.3 GB open sequence Start Stop conditions Is GB closed Fail class Soft open shutdown Deload DG Load < open Ramp down set point timer expired Open GB GB open Alarm DESIGNER'S HANDBOOK 4189341275A EN Page 40 of 196...
Page 41: Stop Sequence
2.8.4 Stop sequence Start Stop conditions GB open seq OK AUTO mode Cooldown timer run out Run coil Stop relay Deactivate Activate stop ”stop” relay relay Genset Alarm stopped DESIGNER'S HANDBOOK 4189341275A EN Page 41 of 196...
Page 42: Start Sequence
2.8.5 Start sequence Start Start condition Start prepare timer Start relay Start relay timer Genset started timeout Off relay Run feedback Alarm detected Stop relay timer F/U OK timed out Max start Ready to attempts close GB Start failure alarm DESIGNER'S HANDBOOK 4189341275A EN Page 42 of 196...
Page 43: Mb Close Sequence
2.8.6 MB close sequence Start Is MB open Voltage on mains/bus Voltage on GB closed Direct close OK GB open Back sync ON sequence Sync timer Alarm sync. Alarm GB Sync MB runout failure open failure Synchronised Close MB Close failure MB closed alarm DESIGNER'S HANDBOOK 4189341275A EN...
Page 44: Close Sequence
2.8.7 GB close sequence Start Is GB open Start seq OK Single DG application Voltage on busbar Island mode All GBs OFF Voltage on bus MB close TB Present TB open MB open Direct closing Sync GB Time runout DG freq match BB freq Alarm sync failure...
Page 45: Fixed Power
2.8.8 Fixed power Start Activate start input Start sequence GB close sequence Ramp-up to Operation load set point Deactivate start input GB open sequence Stop sequence DESIGNER'S HANDBOOK 4189341275A EN Page 45 of 196...
Page 46: Load Takeover
2.8.9 Load takeover Start Activate start input Start sequence GB close sequence Ramp-up Mains load = 0 kW genset load MB open Genset sequence operation Deactivate start input MB close GB open Stop sequence sequence sequence DESIGNER'S HANDBOOK 4189341275A EN Page 46 of 196...
Page 47: Island Operation
2.8.10 Island operation Start Start input active Start sequence GB close Operation sequence Start input deactivated GB open sequence Stop sequence DESIGNER'S HANDBOOK 4189341275A EN Page 47 of 196...
Page 48: Peak Shaving
2.8.11 Peak shaving Start Mains power above start set point Start sequence Operation: GB close produce power sequence above set point Mains power below stop set point GB open sequence Stop sequence DESIGNER'S HANDBOOK 4189341275A EN Page 48 of 196...
Page 49: Mains Power Export
2.8.12 Mains power export Start Activate start input Start sequence Close GB sequence Ramp up to operation MPE set point Deactivate start input GB open sequence Stop sequence DESIGNER'S HANDBOOK 4189341275A EN Page 49 of 196...
Page 50: Automatic Mains Failure
2.8.13 Automatic Mains Failure Start Mains failure Start eng + open MB (7065) Open MB Start sequence Start sequence Open MB GB close GB close sequence sequence Mains ok MB close Time out sequence DESIGNER'S HANDBOOK 4189341275A EN Page 50 of 196...
Page 51: Test Sequence
2.8.14 Test sequence Start Select test mode Start sequence Test timer Timer run out Engine running Stop sequence Freq/voltage OK Sync of GB Engine stopped allowed Return to running mode Sync GB (7043) Opening og MB Ramp up to allowed P setpoint P Mains = 0kW Open MB...
Page 52: Start Sequence
If island operation is selected, the digital input "MB closed" must NOT be activated with a 12/24 volt input signal. A "mains breaker failure" will occur if the wiring of the mains breaker feedback inputs is wrong. INFO Refer to our application notes or installation instructions for information about the required breaker wiring. INFO We recommend not using small relays for stop coil output.
Page 53: Start Sequence Conditions
Start sequence: Extended start prepare Start prepare Crank (Starter) Run coil 1 sec. Stop coil Running feedback 1st start attempt 2nd start attempt 3rd start attempt INFO Run coil can be activated from 1 to 600 sec. before crank (starter) will be executed. In the above example, the timer is set to 1 sec.
Page 54: Running Feedback
Start sequence: Cranking depends on RMI Start prepare (3 start attempts) Stop relay Crank relay 1 sec. Run coil Running feedback RMI measurement OK RMI value Cranking starts 2.9.3 Running feedback Different types of running feedback can be used to detect if the motor is running. Refer to menu 6170 for selection of the running feedback type.
Page 55 Running feedback failure Running feedback failure Primary running feedback Secondary running feedback 1 sec. Start relay (crank) ALARM Alarm Interruption of start sequence The start sequence is interrupted in the following situations: Event Comment Stop signal Start failure Remove starter feedback Tacho set point.
Page 56: Start-Up Overview
2.9.4 Start-up overview 6160 Run status (0-300 s) Inhibit status Not running Oil pressure inhibit 1500 6165 1000 Frequency detecton level (20-35 Hz) 6173 Running detection level (0-4000 RPM) 6174 6160 Remove Run status starter (0-300 s) 6351 6180 2740 4560 Cranking Running...
Page 57 Running detection This timer can be set to the needed level. This will make sure that the engine goes from the RPM level set in 6174 Remove starter and 6173 Running detection level. If the timer is exceeded and the level is not reached, the start sequence will start over and will have used a start attempt.
Page 58: Start-Up Overview With Idle Run
2.9.5 Start-up overview with idle run 6160 Run status (0-300 sec) Inhibit status: Not running Oil pressure inhibit 1500 6165 1000 Frequency detection level (20-35 Hz) 6173 Running detection level (0-4000 RPM) 6290 6160 Idle run 6174 Run status Remove (0-300 sec) starter 4560...
Page 59 Stop sequence Run coil Cooling down time COOL stop Run coil Running feedback Sequence initiated Stop sequence Stop coil Cooling down time COOL Stop coil stop Running feedback Sequence initiated The stop sequence will be activated if a stop command is given. The stop sequence includes the cooling down time if the stop is a normal or controlled stop.
Page 60: Breaker Sequences
Event Comment Binary start input Auto mode: Island operation and fixed power, load takeover or mains power export. Exceeding set point Auto mode: Peak shaving. GB close button is pressed Semi-auto mode only. INFO The stop sequence can only be interrupted during the cooling down period. INFO When the engine is stopped, the analogue speed governor output is reset to the offset value.
Page 61: Amf Timers And Set Points
Mode Genset mode Breaker control Manual Push-button Block None Before closing the breakers it must be checked that the voltage and frequency are OK. The limits are adjusted in menu 2110 Sync. blackout. Set points related to MB control 7080 MB control When enabled, the AGC will perform the AMF sequence in case of a mains failure regardless of the actual Mode shift genset mode.
Page 62 Timer Description Menu number 7072 f mains failure Mains failure OK delay 7062 U mains failure GB ON delay 6231 GB control MB ON delay 7082 MB control The timer t is only active if back synchronisation is deactivated. Example 1: 7065 Mains fail control: Start engine and open MB Mains OK MB On GB On...
Page 63 When the mains voltage/frequency has returned, some hystereses can be adjusted. The Multi-line 2 controller has four separate hystereses which are located in menu 7090. The first hysteresis is for the “low voltage limit”. If the mains “low voltage” is set at 90 % (7063), the Multi-line 2 will start the “Automatic Mains Failure”...
Page 64: Standard Protections
When the timer runs out, the output is activated. The total delay will be the delay setting + the reaction time. When configuring the parameters in the DEIF controller, the measuring class of the controller and an adequate "safety" margin must be considered.
Page 65: Phase Sequence Error And Phase Rotation
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 % under-voltage situation in a 400/230 volt system. Phase-neutral Phase-phase Nominal voltage...
Page 66 INFO The table above is only for Single DG application! In the AGC there are two different alarms concerning the phase sequence error, and hereby two different fail classes. The alarm for phase sequence error and phase rotation is set in parameter 2150. The parameters are described in the table below: Parameter Menu text Description 2151 Output A...
Page 67: Standard/Multiple Controller Applications
3.2.2 Standard/multiple controller applications In these applications there are different types of controllers. The three different types are: Genset, Bus Tie Breaker (BTB) and Mains. The phase sequence alarms are located at parameter 2150. From here it is possible to configure both the alarms for phase sequence errors and also the phase rotation.
Page 68 For Genset controllers in a power management application, the table below is applicable: Genset voltage terminals Busbar voltage terminals 79-84 85-89 Parameter 2150 is consisting of two alarms, and the phase rotation direction setting. The phase rotation setting is the same for the both terminal sets.
Page 69: Loss Of Excitation
3.3 Loss of excitation To prevent damage to the generator because of a pole slip, the AGC can trip a breaker if loss of excitation occurs. The protection is configured in menu 1520. The percentage in parameter 1521 is the maximum percentage of imported kvar compared to the nominal kW of the genset. Genset example The genset has a nominal of 1000 kW.
Page 70: Voltage-Dependent Over-Current
3.4 Voltage-dependent over-current The voltage-dependent over-current is a protection for generators without permanent magnets. This protection occurs when a short circuit is present and the voltage drops. When a short circuit occurs, the voltage will make a drop and the current will rise for a very short period and then drop to a lower level afterwards.
Page 71: Unbalanced Current
3.5 Unbalanced current The generator can be in a situation where it is not delivering its rated load, but the current is very high in one of the phases. This can be caused by an unbalanced load. When a generator load is unbalanced, the stress on the generator will be higher than normal. The heat in one of the windings can also be very high.
Page 72: Over-Excitation
In parameter 1512 the timer can be set, and in parameter 1515 this protection is enabled. In parameter 1516 the fail class is decided. It is also possible to enable two relay outputs when the alarm occurs. The two relay outputs can be set in parameters 1513 and 1514.
Page 73: Decision Of Measurements
% Nominal Voltage INFO The voltage values for the six points on the curve are fixed; the current values can be adjusted in the range 50-200%. INFO Voltage and current % values refer to the nominal settings. INFO Timer value can be adjusted in the range 0.1- 60.0 sec. 3.9 Decision of measurements The protection for unbalanced voltage, for example, can be set to either a phase-phase or a phase-neutral measurement.
Page 74 Parameter 1202 influences 1270, 1280, 1290, 1940 Busbar over-voltage protection 1, 2, 3 and 4. 1300, 1310, 1320, 1330, Busbar under-voltage protection 1, 2, 3, 4 and 5. 1950 1620 Busbar unbalanced voltage protection. Busbar time-dependent over-voltage 1 and 2 (measured on busbar side of generator breaker, only in 1660, 1700 generator controllers).
Page 75: Pid Regulator For Governor And Avr
4. PID regulator for governor and AVR 4.1 Description of PID controller The AGC includes a PID controller for governor and AVR regulation. It consists of a proportional regulator, an integral regulator and a derivative regulator. The PID controller is able to eliminate the regulation deviation and can easily be tuned in. More information See General Guidelines for Commissioning.
Page 76: Principle Drawing
4.3 Principle drawing The drawing below shows the basic principle of the PID controller. P-part I-part Set point Σ Σ Output (Kp) (Ti) D-part (Td) As illustrated in the above drawing and equation, each regulator (P, I and D) gives an output which is summarised to the total controller output.
Page 77: Dynamic Regulation Area
1% regulation deviation A 1% regulation deviation occurs. With the Kp setting adjusted, the deviation causes the output to change 5 mA. The table shows that the output of the AGC changes relatively much if the maximum speed range is low. Max.
Page 78: Integral Regulator
4.4.3 Integral regulator The main function of the integral regulator is to eliminate offset. The integral action time Ti is defined as the time the integral regulator uses to replicate the momentary change of the output caused by the proportional regulator. In the drawing below the proportional regulator causes an immediate change of 2.5 mA.
Page 79: Load Share Controller
• de/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 Deviation 2 D-output 2, Td = 1 s...
Page 80: Synchronising Controller
The regulation deviation from the power regulator can therefore have great or less influence on the PID controller. An adjustment of 0% means that the power control is switched off. An adjustment of 100% means that the power regulation is not limited by the weight factor.
Page 81: Relay Adjustments
The regulation with relays can be split up into five steps. # Range Description Comment The regulation is active, but the increase relay will be constantly activated because of the 1 Static range Fix up signal size of the regulation deviation. The regulation is active, and the increase relay will be pulsing in order to eliminate the 2 Dynamic range Up pulse...
Page 82: Signal Length
4.7.2 Signal length The signal length is calculated compared to the adjusted period time. In the drawing below the effect of the proportional regulator is shown. P-regulator 0.5 % In this example we have a 2 percent regulation deviation and an adjusted value of the Kp = 20. The calculated regulator value of the controller is 4 0%.
Page 83: Voltage Droop Example
Activating droop regulation The following M-Logic commands are used to activate droop regulation. This gives more options to activate the regulation, for example a digital input, an AOP button or an event. M-Logic command Description Output, Command, Act. Frequency droop regulation Activates the use of frequency droop parameters mentioned above Output, Command, Act.
Page 84: Low Droop Setting
INFO This can be used if the generator must operate base-loaded. 4.8.4 Low droop setting To illustrate the influence of a low droop setting, the diagram below shows how a frequency variation gives a change in the load, the principle is the same with voltage droop regulation. The load change is marked as ΔP. In this diagram, the load change (ΔP) is larger than before.
Page 85: Synchronisation
5. Synchronisation 5.1 Synchronisation principles The controller can be used for synchronisation of generator and mains breaker (if installed). Two different synchronisation 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.
Page 86: Close Signal
INFO Of course both three-phase systems are rotating, but for illustrative purposes the vectors for the generator on load are not shown to be rotating. This is because we are only interested in the slip frequency for calculating when to release the synchronisation pulse.
Page 87: Adjustments
NEGATIVE slip frequency FUEL INDEX Gen1 100% LOAD FUEL INDEX Gen2 100% Reverse power 5.2.3 Adjustments The dynamic synchroniser is selected in menu 2000 Sync. type in the control setup and is adjusted in menu 2020 Synchronisation. Setting Description Comment Adjust the maximum positive slip frequency where "Sync df "...
Page 88: Static Synchronisation
INFO Dynamic synchronisation is recommended where fast synchronisation is required, and where the incoming gensets are able to take load just after the breaker has been closed. INFO Static and dynamic synchronisation can be switched by using M-Logic. 5.3 Static synchronisation In static synchronisation, the synchronising genset is running very close to the same speed as the generator on the busbar.
Page 89: Close Signal
5.3.2 Close signal The close signal will be issued when phase L1 of the synchronising generator is close to the 12 o’clock position compared to the busbar which is also in 12 o’clock position. It is not relevant to use the response time of the circuit breaker when using static synchronisation, because the slip frequency is either very small or non-existing.
Page 90: Close Before Excitation
Setting Description Comment Maximum df 2032 The maximum allowed voltage difference between the +/- value related to the nominal generator voltage. Maximum dU busbar/mains and the generator. 2033 The size of the window where the synchronisation pulse can +/- value. Closing window be released.
Page 91: Flowchart 1, Gb Handling
• Delay 3 = Parameter 2271 • SP1 = Parameter 2251 • SP2 = Parameter 2263 5.4.1 Flowchart 1, GB handling Start Start DG(s) RPM > SP1 Delay 1 expired Close GB Start RPM > SP2 Delay 1 expired Trip GB excitation Delay 1 expired on all DG(s)
Page 92: Flowchart 2, Tb Handling (Option G5)
5.4.2 Flowchart 2, TB handling (option G5) Start TB Open Any GB closed > P AVAIL ”GB + TB” MB OFF Close TB Sync TB 5.4.3 Genset start actions The start sequence of the AGC is changed in order to achieve the function "close before excitation". The following parameters must be adjusted: Menu Description Comment...
Page 93: Breaker Sequence
INFO The relay that is used for close before excitation must be a non-configured relay that is not used for anything else. Vo lt age Nom in al RPM Nom in al Voltage Exc. st art RPM (2263) CBE close RPM (2251) Rem ove start er (6174) t [s] St art er/ cran k...
Page 94: Close Before Excitation" Failure
3. 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 the generator breaker must be closed or both the generator breaker and also the tie breaker. The breaker sequence adjustments are the following: Menu Description Comment...
Page 95 Voltage rerun level At parameter 2265, it is set how low the voltage must be, before it is allowed to close the breaker during the rerun. If the voltage is not below the “voltage rerun level” before the “voltage discharge timer” has expired, the specific genset will be excluded from the CBE rerun sequence.
Page 96: Separate Synchronising Relay
% of nominal voltage New start CBE Break Lim GB open request GB close (2252) expired Voltage discharge (2264) Voltage rerun level (2265) Time In the diagram above, the excitation is ON during cooldown. Then a new start request is made, which means that the excitation will be shut off.
Page 97: Inhibit Conditions Before Synchronising Mains Breaker
Relay selected Relay not selected Relay Two relays used One relay used Synchronising: Synchronising: The breaker ON relay activates when The breaker ON relay and the sync. relay activate at the same time synchronising is OK. when synchronising is OK. Not used Blackout closing: Blackout closing:...
Page 98 Mains failure Delay act. rec2 (2291) Mains condition OK (2281-2284) Delay act. rec2 expires (2291) Mains condition OK (2281-2284) Recovery Recovery del.2 del.1 (2294) (2292) Close Mains breaker If the "Delay activate recovery 2" timer runs out, the long interruption timer (menu 2294 "Recovery del. 2") will start to run. Example 1: Recovery timer 1 (short interruption timer) •...
Page 99: Additional Functions
6. Additional functions 6.1 Start functions The controller will start the genset when the start command is given. The start sequence is deactivated when the remove 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 run status. If it is not possible to activate the run status alarms at low revolutions, the remove starter function must be used.
Page 100: Analogue Tacho Feedback
Running feedback The diagram illustrates how the digital running feedback (terminal 117) is activated when the engine has reached its firing speed. Remove starter When the digital remove starter input is present, the start relay is deactivated and the starter motor will be disengaged. Running feedback Remove...
Page 101 Running feedback The diagram below shows how the running feedback is detected at the firing speed level. The factory setting is 1000 RPM (6170 Running detect.). Running feedback menu 6173 CAUTION Notice that the factory setting of 1000 RPM is higher than the RPM level of starter motors of typical design. Adjust this value to a lower value to avoid damage of the starter motor.
Page 102: Oil Pressure
6.1.3 Oil pressure The multi-inputs on terminals 102, 105 and 108 can be used for the detection of running feedback. The terminal in question must be configured as a RMI input for oil pressure measurement. When the oil pressure increases above the adjusted value (6175 Pressure level) then the running feedback is detected and the start sequence is ended.
Page 103: Double Starter
6.1.4 Double starter In some emergency installations, the prime mover is equipped with an extra start motor. Dependent on the configuration, the double starter function can toggle between the two starters or try several attempts with the standard starter before switching to the double starter.
Page 104: Idle Running
Select the correct relay number in output A and output B and enable the function. Change the relay function to limit in the I/O menu. Then the relay will activate, but no alarm will appear. Note that to avoid an alarm, both output A and output B need to be configured to a relay.
Page 105: Description
It is possible to use the idle run function with or without timers. Two timers are available. One timer is used in the 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 the function flexible. INFO The speed governor must be prepared for the idle run function if this function is to be used.
Page 106: Examples
6.3.2 Examples Idle speed during starting and stopping In 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. 1500 START STOP...
Page 107: Temperature-Dependent Idle Start-Up
6.3.4 Temperature-dependent idle start-up This is an example of how to set up a system that will start up in idle speed, if the coolant temperature is below a specified value. When the temperature exceeds the specified value, the genset will ramp up to nominal values. Example The function is made with delta analogue 1 (menus 4601, 4602 and 4610) and one M-Logic line.
Page 108: Inhibit
In order for this function to work, menu 6295 Idle active must be enabled, and the relay output must be configured. Otherwise the low speed function will not work. 6.3.5 Inhibit The alarms that are deactivated by the inhibit function are inhibited in the usual manner, except for the oil pressure alarms; RMI oil 102, 105 and 108 which are active during "idle run"...
Page 109 Start Start Auto start/stop Temp. control No starting Start the genset Idle timer Start the genset speed Idle timer expired Genset running Genset running at f at idle speed DESIGNER'S HANDBOOK 4189341275A EN Page 109 of 196...
Page 110: Analogue Load Sharing
Stop Start Auto Temp. Genset running start/stop control at Nom. speed Idle timer on Low speed Genset running Idle timer at idle speed expired Genset stop sequence 6.4 Analogue load sharing If hardware option M12 is installed, the controller can use analogue load sharing lines to share the load equally (as a percentage of the nominal power).
Page 111: Analogue Load Sharing Terminals
Analogue load sharing is automatically not active when: • The genset breaker is open. Analogue load sharing is automatically ignored when the power management system gives the genset controller a power set point: • You can use M-Logic to force the controller to use analogue load sharing. This allows analogue load sharing with externally controlled gensets.
Page 112 If the measured voltage is higher than the voltage from the internal power transducer, the controller increases its load to match the voltage on the load sharing line. If the measured voltage is lower than the voltage from the internal power transducer, the controller decreases its load to match the voltage on the load sharing line.
Page 113: Island Ramp Up With Load Steps
6.4.3 Island ramp up with load steps Analogue load share set point One step before the load share setpoint is reached the ramp up function is switched off Power ramp [%/s] Time [sec] GB closed The genset controller includes a load ramp up function. If enabled, this also controls the load ramp up for analogue load sharing. When menu 2614 is enabled, the power set point continues to rise in ramp up steps, determined by menu 2615, towards the load sharing set point.
Page 114: Load Sharing Type
To be able to adjust the maximum range, set 6391 to Adjustable. The AGC can provide between 1.0 and 5.0 V DC at 100 % load. Load sharing interfacing to DEIF Uni-line LSU (load sharing unit) and Multi-line 2 version 1 and version 2 can require a 0 to 5 V DC range.
Page 115 Figure 6.1 PCC interface to AGC PCC in the DEIF power management system If the AGC is part of a power management system, it normally gets load sharing information from the power management system over CAN bus. You can force an AGC to use the analogue load sharing lines: Activate Output, Command Power management, Use Ana LS instead of CAN in M-Logic.
Page 116: Ventilation
6.5 Ventilation This function can be used to control the cooling of the engine. The purpose is to use a multi-input for measuring the cooling water temperature and that way activate an external ventilation system to keep the engine below a maximum temperature. The functionality is shown in the below diagram.
Page 117: Fan Logic
6.6 Fan logic The AGC is able to control four different fans. This could for example be air supply fans for supplying air to a genset in 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.
Page 118: Fan Start/Stop
Fan temperature input is set up in parameter 6561, and this input can be selected between these inputs: • Three multi-inputs in slot #7 are available • EIC measurement (engine interface communication) • External analogue input 1-8 (H12.X) • Analogue inputs (M15.X) •...
Page 119: Fan Output
6.6.4 Fan output At parameter 6581 to 6584, the output relays for fans A to D are selected. The purpose of these relays is to issue a signal to the fan starter cabinet. The relay must be energised for the fan to run. 6.6.5 Fan start delay If two or more fans are requested to be started at the same time, it is possible to add a start delay between each fan start.
Page 120: Fan Running Feedback
6.6.6 Fan running feedback To make sure that the fan is running, it is possible to assign a digital input as a running feedback. The running feedback has to be programmed through M-Logic. Here is an example. The Fan A/B/C/D running command output tells the AGC that the fan is running. The output is found under Output, Command as shown above.
Page 121: Fan Priority (Running Hours)
6.6.8 Fan priority (running hours) The priority of the fans A to D rotates automatically from 1 to 4 priority. This is done automatically, because 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, the following M-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 be used to indicate that the...
Page 122: Fan Priority Update
INFO Only reset is possible. It is not possible to add an offset to the run hour counter. 6.6.9 Fan priority update In parameter 6562, the priority update rate (the hours between priority changes) is selected: If the fan priority update is set to 0 hours, the priority order is: Fan A, Fan B, Fan C, Fan D. 6.7 Derate genset The derate function reduces the maximum output power of the genset when specific conditions require this.
Page 123: Input Selection
INFO The derate function is typically used when cooling problems are expected. 6.7.1 Input selection Each derate function can be assigned to one of the following inputs (using parameter 6241, 6251 or 6261): Input Comment Multi-input 102 (slot #7) 0-40V DC 4-20 mA Multi-input 105 (slot #7) Pt100/1000...
Page 124: Derate Characteristic
Inverse derating example LIMIT Start derate 6.7.3 Derate characteristic The derating can be proportional or inverse. Proportional derating example LIMIT Start increase Use Enable in parameter 6246/6256/6266 to select the derate characteristic: • Enable OFF: Inverse. A higher control value gives a lower power. •...
Page 125: Trip Of Non-Essential Load (Nel)
EIC derate with derating function Using parameter 6241, 6251 or 6261, select EIC Derate request (SPN 3644). To calculate the derated power, the AGC uses the value from the EIC in the derate function. EIC derate using parameter 7551 Enable parameter 7551 to use the EIC value Engine Derate Request (that is, SPN 3644) as the derated power in the AGC. That is, the EIC value is used directly, without a derate calculation.
Page 126: Engine Heater Alarm
Principle diagram 43°C 37°C Engine heater relay Start attempt DG running INFO The engine heater function is only active when the engine is stopped. 6.9.1 Engine heater alarm If the temperature keeps dropping after the start set point has been exceeded, an alarm will be raised if configured in menu 6330. 6.10 Fuel pump logic The fuel pump logic is used to start and stop the fuel supply pump to maintain the fuel level in the service tank at predefined levels.
Page 127: Fuel Fill Check
Fuel level Fuel service tank level Time Fuel pump start level Fuel pump stop level 6.10.1 Fuel fill check The 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 menu 6553. If the fuel level does not increase by 2% within the adjusted delay time, then the fuel pump relay deactivates and a Fuel fill alarm occurs.
Page 128: Service Timers
Automatic Gen-set Controller multi-line AGC 400 400V 9120 Service menu Timers Time Misc Available selections Time Shows the alarm timer and the remaining time. The indicated remaining time is minimum remaining time. The timer will count downwards when the set point has been exceeded. Automatic Gen-set Controller multi-line AGC 400 400V...
Page 129: Command Timers
The function in the controller is to activate a relay under defined conditions. Then the relay must be used for the oil renewal system (not part of the DEIF scope of supply) where lubricating oil is removed and added to the engine. Any freely configurable relay is available for this feature.
Page 130: Breaker Functions
When the running hours counter has reached 1000 hours, the controller will reset the hours just for the oil renewal function. If, for example, the set point has been set to 750 hours and inverse is not enabled, the relay will close at 750 hours and remain closed until 1000 hours is reached, and then the hours counter starts from 0 hours again.
Page 131: Breaker Position Failure
6.15.2 Breaker position failure At all times, the controller must get feedback from the breaker about its position, that is, whether it is opened or closed. The position failure alarm is activated: • When the controller is not getting either an open or close feedback from the breaker. •...
Page 132: Breaker Spring Load Time Principle
found in menus 6230, 7080 and 8190. On the AGC Mains controller (option G5), the spring load feedback from the tie breaker can be connected instead of the GB spring load feedback. 2. Digital input: Two configurable inputs to be used for feedbacks from the breakers: One for GB/TB spring loaded and one for MB spring loaded.
Page 133 A DG or mains controller that has the breaker racked out feature active, will inform the other controllers in the system that the breaker is open but also that the power source is not available on the busbar. In the input list from the USW, the tag “breaker racked out” is assigned to specific inputs, see screen shot below. INFO Depending on the controller type, GB, TB, MB or BTB -racked out is shown in the input list.
Page 134: Digital Mains Breaker Control
removed, a close command to the breaker from the controller could potentially connect a generator and a live BB out of sync. INFO When a genset controller is in racked out breaker mode it will not be possible to use ground relay function. See Option G5 for more information about ground relay.
Page 135: Frequency- Or Voltage-Dependent Droop
The diagram shows that when the generator breaker is synchronised, the mains breaker will be opened automatically after a time delay (t). Later the mains breaker is synchronised, and the generator breaker is opened after the time delay (t). The time delay is measured in seconds and can be adjusted from 0.10 to 99.90 seconds.
Page 136 Parameter Default Description The Y-axis for the droop curve is frequency. Select U for voltage-dependent Curve select (7142)* droop. Note that you the droop curve function is disabled by default. Change this Curve enable (7143)* Disable parameter to enable it. The timer starts when the grid frequency returns to the deadband.
Page 137: Power And Cos Phi Offsets
This droop function is performed based on the actual value for the power set point in the moment the droop is activated. If the function for an example is activated during ramping and the actual power value at this moment is 200 kW, the droop is performed based on 200 kW as the Fixed Power Set point stated in the diagram.
Page 138: Rrcr External Set Point Control
6.20 RRCR external set point control The grid can use a Radio Ripple Control Receiver (RRCR) for load management. The AGC can use the RRCR signals for power and reactive power regulation. You can use four binary inputs (from an external RRCR) to configure 16 signal combinations. Each of the 16 signal combinations can used for a set point for Power, and a set point for Reactive Power or cos phi.
Page 139 Figure 6.3 Example of RRCR for power set point inputs RRCR Power set point inputs example As the figure shows, the power set point inputs for RRCR are enabled. When only input 1 is activated, the controller power set point is 0 %. When only input 2 is activated, the controller power set point is 30 %.
Page 140 Configure the RRCR inputs for Q or cos phi set point inputs • Under Q [%] (green box), choose the required reactive power set points. Note that Q [%] must be negative for capacitive set points. • Under Cosphi (purple box), choose the required cos phi set points. •...
Page 141 Figure 6.5 Example of power set point outputs for RRCR RRCR Power set point output example As the figure shows, the power set point output for RRCR is enabled. If the controller power set point is 30 to 39 %, R1 and R2 are activated. If the controller power set point is 40 to 49 %, R3 is activated.
Page 142: Manual Governor And Avr Control
Under P Select (orange box), select P for the controller to use P [%] as the set point for regulation. If P Select is Off, the controller does not use that RRCR output combination to output the power set point. INFO The curve of P % values must be linear.
Page 143: Fail Class
6.22 Fail class All activated alarms must be configured with a fail class. The fail classes define the category of the alarms and the subsequent alarm action. The tables below show the action of each fail class for a genset controller when the engine is running or stopped. INFO All fail classes trigger the alarm Warning, which is shown in the active alarm log.
Page 144: Engine Stopped
6.22.2 Engine stopped Fail class Action Block engine start Block MB sequence Block GB sequence 1 Block 2 Warning 3 Trip GB 4 Trip + stop 5 Shutdown 6 Trip MB 7 Safety stop 8 Trip MB/GB 9 Controlled stop *Note: The fail class "Trip MB/GB"...
Page 145: Alarm Inhibit
6.23 Alarm inhibit In order to select when the alarms are to be active, a configurable inhibit setting for each alarm has been made. The inhibit functionality is only available via the PC utility software. For each 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.
Page 146: Run Status (6160)
Function Description 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 Redundant controller...
Page 147: Event Log
Run. feedback Alarms active INFO The timer is ignored if digital running feedback is used. 6.24 Event log 6.24.1 Logs The logging of data is divided in three different groups: • Event log containing 500 entries. • Alarm log containing 500 entries. •...
Page 148: Not In Auto
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.
Page 149 Select the TCP-IP button to enter the IP address. Press the Test button to check if the connection is successful, then press the OK button. Press the Communication button in the top toolbar to connect to the controller via TCP-IP. Enter the controller password to be able to change the parameters.
Page 150: M-Logic
When all the controllers have got separate IP addresses, they can be connected to a network switch. The PC can then be connected to the switch, and only the IP address that the Utility Software will have to communicate to, has to be changed. The cable can be in the same port of the switch at all times.
Page 151: Parameter Id
INFO If "Setup stand-alone" is activated while the genset is running, an info text, "Quick setup error", will appear. 6.29 Parameter ID You can add a short text name in parameter 11200 to identify the parameter file used in the controller. 6.30 Language selection The controller can display different languages.
Page 152: Compensation Time
Setting Description Comment The compensation period starts at the adjusted 6401 Start Start time. time. The compensation period stops at the adjusted 6402 Stop Stop time. time. 6403 Difference The set point in seconds that initiates the compensation. 6404 Compensation Frequency difference when the compensation is initiated.
Page 153: Battery Test
6.34 Battery test This function gives the possibility to test the condition of the battery. The battery test can be initiated with a digital 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 the automatic mains failure start up sequence will be activated.
Page 154: Input Configuration
Battery test X + Start Sequence Start Prepare (3 start attempts) Start relay Stop coil relay Start failure alarm A battery test configured as X + Start sequence, as shown in the above example, will use: Start prepare timer, Start on time and Start off time.
Page 155: Auto Configuration
6.34.2 Auto configuration If the automatic battery test is used, the function must be enabled in menu 6420. When the function is enabled, the battery test will be carried out with a specified interval, for example, once a week. Completed battery tests will be logged in a separate battery test log.
Page 156 Application 3: Application 4: Multi-line 2 Multi-line 2 MI 3 MI 1 MI 1 - + - + Manoeuvre battery Start battery Manoeuvre battery Application 5: Multi-line 2 MI 2 MI 1 Manoeuvre battery Application 6: Application 7: Multi-line 2 Multi-line 2 MI 3 MI 2...
Page 157: Internal Battery
When changing the internal battery for the memory, all settings will be lost. The memory backup feature gives the possibility to back up the controller settings, and after replacing the battery the settings can be restored. DEIF recommends that a backup is made at least when the commissioning is tested and done. The following settings will be stored in the backup:...
Page 158: Switchboard Error
Type Stored Views configuration Inputs configuration Outputs configuration Translations M-Logic configuration AOP-1 configuration AOP-2 configuration Application configuration Parameters Modbus configuration Permissions Logs INFO If new firmware is flashed to the controller, the backup will be erased. INFO The controller will reboot after a backup has been restored. The backup is found in parameter 9230 Memory backup with the jump menu.
Page 159: Stop Swbd Error (Menu 6510)
6.36.2 Stop swbd error (menu 6510) When activated, this function will stop the genset if the genset is running in Auto mode. Set points available: • Delay: When the input is active and the delay has expired, the genset will trip the breaker, cool down and stop. The function is active regardless of the "Enable"...
Page 160: Function Descriptions
Input function Auto Semi Test Block Mains Input type Manual GOV down Constant Manual AVR up Constant Manual AVR down Constant Battery test Pulse GB/TB/BTB close inhibit Constant MB close inhibit Constant Low speed Constant Temperature control Constant Enable mode shift Constant Enable GB black close Constant...
Page 161 4. Semi-auto: Changes the present running mode to semi-auto. 5. Test: Changes the present running mode to test. 6. Auto: Changes the present running mode to auto. 7. Manual:Changes the present running mode to manual. 8. Block: Changes the present running mode to block. INFO When block mode is selected, the running mode cannot be changed by activating the digital inputs.
Page 162 20. External var control: The reactive power set point will be controlled from the analogue inputs terminal 41/42. The internal set point will not be used. Note that a -10 V to 10 V signal is used for control. INFO With M-Logic "Gov/AVR control"...
Page 163: Multi-Inputs
41. GB/TB/BTB spring loaded: The AGC will not send a close signal before this feedback is present. 42. MB spring loaded: The AGC will not send a close signal before this feedback is present. 43. Deload: A running genset will start to ramp down the power. 44.
Page 164 Option Option Input type Standard Notes The controller uses the standard Pt100 curve. You can use the Engineering Pt100 • units parameter to change the units from °C to °F. The controller uses the standard Pt1000 curve. You can use the Pt1000 •...
Page 165: Input Function Selection
6.39 Input function selection Digital input alarms can be configured with a possibility to select when the alarms are to be activated. The possible selections of the input function are normally open or normally closed. The drawing below illustrates a digital input used as an alarm input: 1.
Page 166: External Analogue Set Points
Input signal (mA, °C,b, %) Wire failure Upper failure limit Lower failure limit Wire failure Wire break 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 be raised if the wire connection between the AGC and MPU breaks.
Page 167: External Analogue Set Point Terminals
INFO The standard genset controller has a limited number of digital inputs. To have all the required the digital inputs, the controller may need additional hardware options. 6.41.1 External analogue set point terminals Terminal Function Technical data Description -10/+10 V DC Analogue input f/P set point Com.
Page 168: Limit Relay
INFO For more information, see Trip of NEL. 6.43 Limit relay For all alarm functions, you can activate one or two output relays as shown below. The following explains how to use an alarm function to activate an output without activating an alarm. ON and OFF delay timers are described too. If no alarm is needed, it is possible to do one of the following things: •...
Page 169: Step-Up And Step-Down Transformer
Alternatively, you can configure the relay in the USW under I/O Setup: The timer in the image above is an OFF delay, meaning that when the alarm level is OK again, the relay will remain activated until the timer runs out. The timer is only effective when it is configured as M-Logic / Limit relay. If it is configured to any Alarm relay, the relay is deactivated when the alarm conditions disappear and the alarm is acknowledged.
Page 170: Vector Group For Step-Up Transformer
setting in the ML-2, as long as the breaker and the step-up transformer are both placed between the generator and busbar, and mains voltage measuring points for the ML-2. The measuring points are shown as black dots in the figures above and below. The phase angle compensation would not be an issue if there was no phase angle shift across the step-up transformer, but in many cases there is.
Page 171 Vector group 0 The phase shift is 0 degrees. Figure 6.6 Yy0 example HV side LV (generator) side 1L1 to 2L1 phase angle is 0 degrees Table 6.1 Phase compensation setting Parameter Function Setting 9141 BB (mains)/generator angle compensation 0 degrees Figure 6.7 Connections Busbar...
Page 172 Figure 6.8 Dy1 example HV side LV (generator) side 1L1 to 2L1 phase angle is -30 degrees. Table 6.2 Phase compensation setting Parameter Function Setting 9141 BB (mains)/generator angle compensation 30 degrees Vector group 11 The phase angle shift is 11 × (-30) = -330/+30 degrees. Figure 6.9 Dy11 example HV side...
Page 173 Figure 6.10 Yy6 example HV side LV (generator) side 1L1 to 2L1 phase angle is -180/+180 degrees. Table 6.4 Phase compensation setting Parameter Function Setting 9141 BB (mains)/generator angle compensation 180 degrees INFO Select 179 degrees in parameter 9141 when vector group 6 is used. Table 6.5 Comparison table between different terminologies LV lag degrees...
Page 174: Setup Of Step-Up Transformer And Measurement Transformer
Yd11, Dy11, Yz11 -30 ° INFO DEIF does not take responsibility that the compensation is correct. Before closing the breaker, DEIF recommends that customers always measure the synchronisation themselves. INFO If voltage measurement is connected incorrectly, the setting in parameter 9141 will be wrong.
Page 175: Vector Group For Step-Down Transformer
• The nominal voltage of the busbar (BB) is 10 kV. Because the generator’s nominal voltage is 400 V, there is no need for a measurement transformer on the LV side in this example. The ML-2 can handle up to 690 V. But it is still required to set up current transformers on the LV side. In this example, the current transformers have a nominal current of 300/5 A.
Page 176: Setup Of Step-Down Transformer And Measurement Transformer
INFO If a step-down transformer is mounted with a genset controller, the settings shown in the table above should also be used. If a step-down transformer and mains controller are mounted, note how the measurements are mounted on the controller. The correct connection is shown below.
Page 177: Demand Of Peak Currents
Parameter Comment Setting 6002 Generator nominal power 6003 Generator nominal current 6004 Generator nominal voltage 6041 HV measurement transformer primary side (There is none here) 6042 HV measurement transformer secondary side (There is none here) 6043 Current transformer primary side 6044 Current transformer secondary side 6051...
Page 178: Differential Measurement
There are two levels of alarms in U> L-L, U< L-L, U> L-N, U< L-N, f>, f< and I>. In principle, the average calculation is done, for example, every time the main voltage measurement updates. The average is calculated based on the RMS value of the three phases. Parameter Item 14000...
Page 179 Example: Parameters for differential measurement 1 inputs Parameter Name Range Default 4601 Delta ana1 InpA See list below. Multi input 102 4602 Delta ana1 InpB See list below. Multi input 102 The following inputs are possible (depending on the controller options): •...
Page 180: Counters
6.48 Counters Counters for various values are included, and some of these can be adjusted if necessary, for instance if the controller 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...
Page 181: Pulse Input Counters
6.49 Pulse input counters Two configurable digital inputs can be used for counter input. The two counters can, for example, be used for fuel consumption or heat flow. The two digital inputs can ONLY be configured for pulse inputs via M-Logic, as shown in the example below. •...
Page 182: General Purpose Pid
8. Output: This is the final output from the PID, controlling the transducer. 7.1.2 GP PID interface in USW Configuration of the GP PID’s input and output settings is done with the “PID” interface in the DEIF USW, it cannot be done from the display of the controller.
Page 183: Inputs
7.2 Inputs 7.2.1 Inputs Each output can have up to three inputs. Only one input at a time is used for calculation of output signal. See Dynamic input selection for how the selection is handled. DESIGNER'S HANDBOOK 4189341275A EN Page 183 of 196...
Page 184 Explanation of GP PID settings 1. Activation drop-down: Enables the PID or allows it to be enabled from M-Logic. 2. Top drop-down: The source of this input is chosen here. 3. “Input 1 min.” and “Input 1 max.”: Defines the scale of the input value evaluated. 4.
Page 185: Dynamic Input Selection
• A weight factor of 1 means that the real input value is used in calculations. • A weight factor of 3 means that the input value is considered three times as big in calculations. 6. Bottom drop-down • On: This input will be evaluated. •...
Page 186: Output
7.3 Output 7.3.1 Explanation of output settings DESIGNER'S HANDBOOK 4189341275A EN Page 186 of 196...
Page 187 1: Priority This setting determines whether it is min. or max. output that is prioritised. This setting is used for the dynamic input selection feature. “Maximum output” results in selection of the input that gives the greatest output. “Minimum output” results in selection of the input that gives the smallest output.
Page 188 Cooling circuit Heating circuit Process Variable Controller Set point For this application, two controllers must be configured: one with direct output for the heating pump and one with inverse output for the cooling pump. To achieve the illustrated inverse output, an offset of 100 % is needed. See the sections about “Analogue offset” and “Example of inverse output with 100 % offset”...
Page 189: Kp Gain Compensation
Analogue offset 50 % 100 % 50 % 100 % Output Input Direct Inverse 100 % 50 % 50 % Above set point 100 % 100 % Set point 50 % 50 % 100 % 100 % Below set point 50 % 50 % 100 %...
Page 190: Load Change Gain Compensation
function allows slower PID settings for when there are no changes or stabilising, and when there are significant changes in the system it will increase the reaction of the PID. The "Kp gain compensation" consists of two separate functions: 1. The load change gain compensation. 2.
Page 191: Set Point Deviation Compensation
Example of load change gain compensation % of nom. load Load % PID gain The diagram above shows the reaction of the gain, based on two load changes. In the first situation, there is a large load impact that triggers the load change gain compensation and increases the gain instantaneously.
Page 192 Explanation of settings 1. Set point deviation: Enables/disables set point deviation compensation. 2. Set point deviation activation: Deviation deadband. As long as the actual value does not deviate more than the deadband in this parameter, the function is not activated. 3.
Page 193: M-Logic
7.5 M-Logic 7.5.1 Introduction All functions of the GP PIDs can be activated and deactivated by means of M-Logic. In the following, events and commands regarding the GP PIDs are described. 7.5.2 Events M-Logic, Events, General Purpose PID Notes PID [1-4] active Activated when the PID is active.
Page 194 In this example, the ECM (Engine Control Module) measures both the intercooler coolant temperature as well as the jacket cooling water temperature. The generator controller receives these values by an EIC option (Engine Interface Communication). DESIGNER'S HANDBOOK 4189341275A EN Page 194 of 196...
Page 195 EIC Intercool temp. is selected as input 1, and EIC Cooling water temp. as input 2. Min. and max. values are configured for full range. Input 1 reference set point is set at 500 to achieve a temperature set point of 50.0 °C for intercooler coolant. Input 2 has a reference set point set at 900 to achieve a set point of 90.0 °C jacket water coolant.
Page 196 • An offset of 100 % is chosen to achieve 100 % output at the set point. • Full range of output is selected. As this is output for a fan, it may be preferred to use a minimum output. •...

Deif AGC-4 Mk II Designers Handbook

1 Introduction

2 Functions

3 Standard Protections

4 PID Regulator for Governor and AVR

5 Synchronisation

6 Additional Functions

7 General Purpose PID

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