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Deif PPM 300 Designers Handbook

Deif PPM 300 Designers Handbook

Protection and power management

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DESIGNER'S HANDBOOK

Protection and Power Management

PPM 300

DEIF A/S · Frisenborgvej 33 · DK-7800 Skive

Tel.: +45 9614 9614 · Fax: +45 9614 9615

info@deif.com · www.deif.com

Document no.: 4189340911K

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Page 1 DESIGNER'S HANDBOOK Protection and Power Management PPM 300 DEIF A/S · Frisenborgvej 33 · DK-7800 Skive Tel.: +45 9614 9614 · Fax: +45 9614 9615 info@deif.com · www.deif.com Document no.: 4189340911K...
Page 2: Table Of Contents
........................... 1.1.4 Recommended design process ....................................1.1.5 Software versions ..........................................1.1.6 Technical support ..........................................1.1.7 List of technical documentation for PPM 300 ..............................1.2 Warnings and safety ..........................................1.2.1 Safety during installation and operation ................................. 1.2.2 Controller power supply ........................................
Page 3 2.4.2 General controller functions ......................................3. AC configuration and nominal settings 3.1 AC configuration ............................................3.1.1 System ..............................................3.1.2 [Source] and [Busbar] for each controller type ..............................3.1.3 [Source] AC configuration ......................................3.1.4 [Busbar] AC configuration ......................................3.1.5 Voltage and frequency as digital outputs ................................
Page 4 3.6.3 Neutral inverse time over-current (ANSI 51N) ..............................3.7 ACM voltage measurement errors ....................................3.7.1 [Source]/[Busbar] L1-L2-L3 wire break ................................... 3.7.2 [Source]/[Busbar] L# wire break ....................................3.8 ACM module general protections ....................................3.8.1 ACM 1 protections not running ....................................3.8.2 ACM 1 data is missing ........................................
Page 5 4.7.6 NEL # reactive overload ......................................4.8 Input alarms ............................................. 4.8.1 Digital input (DI) alarms ......................................4.8.2 Analogue input (AI) alarms ....................................... 4.9 Miscellaneous alarms ......................................... 4.9.1 System not OK ..........................................4.9.2 Critical process error ........................................4.9.3 Required I/O card(s) not found ....................................
Page 6 5.4.3 Regulator synchronisation parameters ................................5.5 Synchronisation and breaker alarms ..................................5.5.1 Breaker synchronisation failure ....................................5.5.2 De-load failure ..........................................5.5.3 Vector mismatch ..........................................5.5.4 Breaker opening failure ......................................5.5.5 Breaker closing failure ........................................ 5.5.6 Breaker position failure ....................................... 5.5.7 Breaker trip (external) .........................................
Page 7 6.7.2 AVR relay setup incomplete ..................................... 6.7.3 GOV output selection failure ....................................6.7.4 AVR output selection failure ..................................... 6.7.5 GOV stand-alone configuration error ..................................6.7.6 AVR stand-alone configuration error ..................................6.8 Regulation alarms ..........................................6.8.1 GOV regulation error ........................................6.8.2 AVR regulation error ........................................
Page 8 7.6.4 Asymmetric P load sharing ....................................... 7.6.5 Asymmetric Q load sharing ....................................... 7.6.6 SHAFT generator base load ..................................... 7.6.7 SHORE connection base load ....................................7.6.8 DEIF network load sharing failure ..................................7.7 Heavy consumer management ...................................... 7.7.1 Introduction ............................................7.7.2 Configuring heavy consumers ....................................
Page 9 8.2.3 Run coil or stop coil ........................................8.2.4 Running detection ......................................... 8.2.5 Regulation ............................................8.2.6 Power management ........................................8.2.7 Load sharing ........................................... 8.2.8 Ready for operation ........................................8.2.9 AC configuration ..........................................8.2.10 Breaker configuration ........................................ 8.3 Engine start .............................................. 8.3.1 Engine start function ........................................
Page 10 8.7.17 Trip running hours notification ....................................8.7.18 Voltage or frequency not OK ....................................8.7.19 DG-SG max. parallel time ....................................... 8.7.20 DG-SC max. parallel time ....................................... 8.7.21 Other GENSET controller alarms ..................................9. EMERGENCY genset controller 9.1 EMERGENCY genset controller overview ................................
Page 11 9.8.6 Temperature-dependent start/stop ..................................9.8.7 Engine states as digital outputs ....................................9.8.8 Engine operating values as analogue outputs ..............................9.8.9 Counters ............................................9.8.10 EMERGENCY genset controller without regulation ............................. 9.8.11 Trip AVR ............................................9.9 EMERGENCY genset controller protections ................................. 9.9.1 EMERGENCY genset controller alarms ................................
Page 12 10.5.2 Alarm actions ..........................................10.5.3 Inhibits ............................................. 10.5.4 Breaker alarms ..........................................10.5.5 AC alarms ............................................10.5.6 SG-DG max. parallel time ....................................... 10.5.7 SG-SG max. parallel time ....................................... 10.5.8 Overspeed ............................................. 10.5.9 Other SHAFT generator controller alarms ............................... 11. SHORE connection controller 11.1 SHORE connection controller overview ................................
Page 13 12.2.1 Configuring a BUS TIE breaker controller ................................ 12.2.2 Nominal settings ......................................... 12.2.3 AC configuration ......................................... 12.2.4 Breaker configuration ........................................ 12.3 BUS TIE breaker controller sequences .................................. 12.3.1 Splitting the busbar ........................................12.3.2 Connecting busbar sections ....................................12.3.3 Bus tie breaker blackout close ....................................
Page 14 13.5.1 Alternating current module ACM3.1 ................................... 13.5.2 ACM3.1 terminal overview ...................................... 13.5.3 Voltage measurement characteristics ................................13.5.4 Current measurement characteristics ................................13.6 Alternating current module ACM3.2 ..................................13.6.1 Alternating current module ACM3.2 ................................... 13.6.2 ACM3.2 terminal overview ...................................... 13.6.3 Current measurement characteristics ................................
Page 15 13.13.2 Display unit terminal overview .................................... 13.13.3 Frame ground characteristics ..................................... 13.13.4 Power supply characteristics ....................................13.13.5 Relay output characteristics ....................................13.14 DEIF Ethernet network ........................................13.14.1 Communication ......................................... 13.14.2 Communication information ....................................13.14.3 Restrictions ..........................................13.15 DEIF internal communication ....................................
Page 16 17.2 Modbus implementation in the controller ................................17.2.1 Modbus TCP protocol ....................................... 17.2.2 Modbus communication port ....................................17.2.3 Controller identifier ........................................17.2.4 Data handling ..........................................17.3 Modbus tables ............................................17.3.1 Download Modbus tables ......................................17.3.2 Modbus table overview ......................................17.4 Specific Modbus function groups .....................................
Page 17 19.3.5 Flowchart symbols ........................................19.3.6 Module faceplate symbols ...................................... 20. Appendix: Pre-configured curves 20.1 Overview ..............................................20.1.1 Introduction ........................................... 20.2 Analogue input level curves ......................................20.2.1 Datcon level ..........................................20.2.2 VDO level ............................................20.3 Analogue input pressure curves ....................................20.3.1 Datcon 5 ............................................
Page 18: About The Designer's Handbook
1.1 About the Designer's handbook 1.1.1 General purpose This is the designer's handbook for DEIF’s Protection and Power Management controller, PPM 300. The designer's handbook provides information required to design a system with PPM 300 controllers, and for configuring the controllers.
Page 19: Recommended Design Process
20,000 kW = 20 MW 1.1.4 Recommended design process DEIF recommends the following design process: 1. Sketch the single-line diagram for the system. From the sketch, identify how many controllers are needed to control the system's equipment and breakers: •...
Page 20: Software Versions
PC software 1.0.10.x 1.1.6 Technical support You can read about service and support options on the DEIF website, www.deif.com. You can also find contact details on the DEIF website. You have the following options if you need technical support: •...
Page 21: List Of Technical Documentation For Ppm 300
• Support: DEIF offers 24-hour support. See www.deif.com for contact details. There may be a DEIF subsidiary located near you. You can also e-mail support@deif.com. • Service: DEIF engineers can help with design, commissioning, operating and optimisation. 1.1.7 List of technical documentation for PPM 300...
Page 22: Warnings And Safety
Document Contents PICUS manual Using PICUS and CustomLogic • Modbus address list ◦ PLC addresses Modbus tables ◦ Corresponding controller functions • Descriptions for function codes, function groups 1.2 Warnings and safety 1.2.1 Safety during installation and operation Installing and operating the equipment may require work with dangerous currents and voltages. The installation must only be carried out by authorised personnel who understand the risks involved in working with electrical equipment.
Page 23: Automatic And Remote-Controlled Starts
Only use the hardware modules that are listed in the controller data sheet. Unsupported hardware modules can make the controller malfunction. 1.2.11 Data security To minimise the risk of data security breaches DEIF recommends: • As far as possible, avoid exposing controllers and controller networks to public networks and the Internet.
Page 24: Legal Information
1.3 Legal information 1.3.1 Third party equipment DEIF takes no responsibility for the installation or operation of any third party equipment, including the genset. Contact the genset company if you have any doubt about how to install or operate the genset.
Page 25: Description
2.1.1 Overall description The PPM 300 Protection and Power Management controller is a highly configurable controller designed for marine use. It includes a wide range of control, protection and supervision functions. Applications range from simple genset control and protection, to fully integrated and engineered power management solutions, developed for fuel-efficient operation.
Page 26: Controller Types
2.1.2 Controller types The PPM 300 controller types listed in the table below are available. The hardware listed is for the recommended configuration. Additional modules may be ordered and mounted as required. A customised PPM 300 controller may also be ordered. For example, you may need additional inputs and outputs.
Page 27: Understanding The System Versatility
A number of controllers are used together to create a controller system. Each controller has configurable hardware, which in turn has configurable inputs and outputs. The controller gets information from the measurements, the inputs, and the DEIF network. The controller sends out information using the outputs, and the DEIF network.
Page 28 Variety of input and output types The DEIF controllers often allow the same function to use a number of alternative types of inputs and/or outputs. This makes the controllers very versatile and compatible with a wide range of equipment and systems.
Page 29 Table 2.2 Example of information flow to and from a GENSET controller Point Type Description Uses The controller measures the AC voltage and Protection, running detection, control, AC measurements current from the genset and the voltage on the synchronisation, power management, and busbar.
Page 30: Maximum Number Of Controllers
(PSM). extension units. 2.2.4 Maximum number of controllers The DEIF power management system allows a total of up to 32 controllers per DEIF network ring. That is, you can assign up to 32 Controller ID numbers. These restrictions also apply:...
Page 31: Priority Of Input Sources
2.2.6 Priority of input sources Each controller can receive inputs from a variety of sources. The rules for when a source can be used, as well as how the controller handles conflicting inputs, are described below. Digital input functions Digital input functions can be activated by wiring connected to hardware, Modbus and/or CustomLogic coils. Rules for digital input functions: 1.
Page 32: Power Management System Control
Type PMS control AUTO mode SEMI mode SWBD control SHAFT generator controller ● ● SHORE connection controller ● ● BUS TIE breaker controller ● ● • The GENSET and EMERGENCY genset controllers normally run in AUTO mode. Alternatively, they can run in SEMI mode, so that an operator or external command can initiate a controller sequence.
Page 33: Switchboard Control
2.3.3 Switchboard control Under Switchboard control, the operator controls and operates the equipment from the switchboard. The operator can manually regulate the frequency and voltage using digital inputs (if configured) or Modbus. Under Switchboard control, the controller does not accept any commands from the display unit or other external sources (for example, PLC and Modbus) to open or close the breaker.
Page 34 Function Type Details When this input is activated, the controller resets the governor output to the offset. This cancels the accumulated effect of the Manual GOV increase and/or Manual GOV decrease digital inputs. Table 2.6 Optional inputs for manual AVR regulation Function Type Notes...
Page 35 Parameter Range Default Notes For relay outputs, depending on the relay output settings, the effect might not be linear. The controller increases or decreases the analogue output by this amount when the digital input is activated. 10 %/s of genset Manual AVR 0 to 200 %/s nominal reactive...
Page 36 ◦ Different power management rules activated ◦ Controller ID not configured The controllers return to power management system control when the cause is removed. More information See Power management, Power management protections for the Forced to switchboard control alarm. EMERGENCY genset controller and force to switchboard control The events that force controllers to switchboard control (listed above) only apply to the EMERGENCY genset controller when it is in Harbour operation.
Page 37: Automatic (Auto) Mode
AUTO mode, then the controller acknowledges the request. Effect of switchboard control on other controllers If a connected GENSET, SHAFT generator or SHORE connection controller is under Switchboard control, all the other GENSET controllers go into SEMI mode. Power management is disabled. DEIF network Switchboard GENSET GENSET...
Page 38: Semi-Automatic (Semi) Mode
Function Type Details If it is possible, the controller is put into AUTO mode when this input is Mode > AUTO mode Digital input Pulse activated. This input has the same effect as pressing the AUTO push- button on the display unit. If it is possible, each GENSET controller in the section is put into Power management >...
Page 39: Controller Unpowered
Effect of the unpowered controller hardware DEIF network links through the unpowered controller are broken. If a redundant DEIF network link is not available, the controllers on either side of the unpowered controller cannot communicate with each other. If a redundant DEIF network link is available, then the controllers on either side of the unpowered controller communicate through the redundant link.
Page 40: Functions
More information See Alarms and Power management for more information about the system protections and power management functions of the controller. 2.4.2 General controller functions Table 2.8 General functions for all PPM 300 controllers Functions • Compact, all-in-one controller ◦...
Page 41 Each controller performs all calculations, then acts accordingly ◦ Power management inputs and outputs may be connected to any controller Communication ◦ Load sharing communication • DEIF network ◦ Controller display unit ◦ Other controllers • Internal communication DESIGNER'S HANDBOOK 4189340911K UK...
Page 42 If a genset governor or AVR fails, the bus tie breaker trips and disconnects the genset • True multi-master control • Busbar can have a ring connection • DEIF network ring connection Redundancy • Internal communication ring connection • Controller commands and operation using the display unit, inputs, PICUS, and/or Modbus •...
Page 43 Functions ◦ Modbus table • Context-sensitive help in the display unit *Note: Only for the GENSET and EMERGENCY genset controllers. DESIGNER'S HANDBOOK 4189340911K UK Page 43 of 521...
Page 44: Ac Configuration
3. AC configuration and nominal settings 3.1 AC configuration 3.1.1 System Phase configuration: AC configuration This parameter must be the same for all the controllers in the system. Configure this parameter under Configure > Parameters > [Source] > AC setup > Phase configuration. Parameter Range Default...
Page 45 • L1-L3-L2 L1-L3-L2: DEIF does not recommend that you wire the system L1-L3-L2, due to the potential for confusion. However, this parameter allows the controller to function correctly even though the generator is wired L1-L3-L2. DESIGNER'S HANDBOOK 4189340911K UK...
Page 46: Source] And [Busbar] For Each Controller Type
Parameter Range Default Notes Voltage Time DANGER! Never attempt to connect gensets to the same busbar if they do not have the same phase rotation. DANGER! Do not use this parameter to attempt to correct for incorrect wiring of the controller's AC measurement terminals. Rewire the terminals correctly.
Page 47 Parameter Range Default Notes Note: No phase shift is allowed in the voltage transformer. That is, the phase angle must be the same on the high and low voltage sides of the voltage measurement transformer. Note: The minimum normal operating voltage for the controller is 100 V. However, this range starts at 17 V to allow switchboard tests.
Page 48 Parameter Range Default Notes Protected object Away: CT - ACM3.2 - Neutral side Configure these parameters under Configure > Parameters > [Source] > AC setup > CT - ACM3.2 - Neutral side. These parameters are only visible if you have an ACM3.2 installed. More information See the Installation instructions >...
Page 49: Busbar] Ac Configuration
During a blackout, the controller uses these parameters to calculate whether the voltage and frequency from the generator measurements are OK, so that the breaker can close. Parameter Range Default Notes If the voltage and frequency from the source are OK for this time in seconds, then Voltage and 0 s to 1 h the equipment LED becomes steady green.
Page 50: Voltage And Frequency As Digital Outputs
Parameter Range Default Notes If the busbar voltage and frequency are OK for this time in seconds, then the Voltage and 0 s to 1 h busbar LED becomes steady green. The breaker is not allowed to close before frequency OK the busbar LED is steady green (that is, not flashing).
Page 51: Nominal Settings
Nominal setting Nominal setting Nominal setting Nominal setting Parameter Range Notes The maximum 4th current Nominal (4th) 1 A to 9 kA 867 A 345 A 345 A 345 A flow during normal operation. Current transformer You can configure the 4th current input current transformer under Configure > Parameters > Local > 4th current input > Current transformer (I4).
Page 52 1. [Busbar] voltage measurements 2. [Source] voltage measurements ACM3.1 • For example: GENSET controller: The voltage at the genset 3. [Source] current measurements • For example: GENSET controller: The current from the genset 4. 4th current measurement • For example: Earth current Inputs and outputs Assign the nominal settings inputs and outputs under Configure >...
Page 53: Nominal Power Calculations
Table 3.2 Local nominal setting parameters Parameter Range Default Notes The selected nominal setting group for the controller when Source is set to • Nominal setting 1 Local. • Nominal setting 2 Nominal Selection setting 1 • Nominal setting 3 Changing the nominal setting group using a digital input, analogue input, or •...
Page 54: Ac Measurements As Analogue Outputs
Q nominal = S nominal: The controller uses the nominal apparent power as the nominal reactive power. INFO It is normally not necessary to change these defaults. The DEIF ML-2 products use Q nominal = P nominal. P or S nominal Table 3.5...
Page 55 Controller type [Source] [Equipment] SHORE connection Shore busbar Shore BUS TIE breaker Busbar B Busbar A Table 3.7 [Source] voltage analogue output functions Function Details [Source] > Voltage (V) > [Equipment] | L1-N [V AC] The controller outputs the L1-N voltage from the source. [Source] >...
Page 56 Function Details [Source] > Frequency (f) (from current) > [Equipment] | L1 The controller outputs the L1 frequency (based on the current [Hz] measurement). [Source] > Frequency (f) (from current) > [Equipment] | L2 The controller outputs the L2 frequency (based on the current [Hz] measurement).
Page 57 Function Details [Source] > Current (I) - ACM3.2 > [Equipment] | L2 (Neutral The controller outputs the L2 current from the neutral side. side) [A] [Source] > Current (I) - ACM3.2 > [Equipment] | L3 (Neutral The controller outputs the L3 current from the neutral side. side) [A] [Source] >...
Page 58 Table 3.12 [Source] reactive power analogue output functions Function Details [Source] > Reactive power (Q) > [Equipment] | L1 [kvar] The controller outputs the L1 reactive power. [Source] > Reactive power (Q) > [Equipment] | L2 [kvar] The controller outputs the L2 reactive power. [Source] >...
Page 59: Busbar] Ac Measurements
Table 3.15 [Source] phase angle analogue output functions Function Details [Source] > Phase angle > [Equipment] | Phase angle L1-L2 The controller outputs the phase angle between L1 and L2. [degrees] [Source] > Phase angle > [Equipment] | Phase angle L2-L3 The controller outputs the phase angle between L2 and L3.
Page 60: Th Current Input
Function Details [Busbar] > Voltage (V) > [Equipment] | Negative sequence [V The controller outputs the magnitude of the negative sequence voltage. The controller outputs the magnitude of the zero sequence [Busbar] > Voltage (V) > [Equipment] | Zero sequence [V AC] voltage.
Page 61: Source Ac Protections
Table 3.21 4th current input frequency analogue output function Function Details The controller outputs the 4th frequency (based on the 4th current Local > 4th current input > Frequency (f) > L4 [Hz] measurement). Table 3.22 4th current input power analogue output function Function Details The controller outputs the 4th power (based on the 4th current measurement and...
Page 62: Source] Over-Voltage (Ansi 59)
Controller type Source Breaker SHORE connection Shore connection BUS TIE breaker Busbar A *Note: The EMERGENCY genset controller also controls the tie breaker to the emergency busbar. The Trip generator breaker alarm action trips the emergency genset breaker (EGB), while Trip tie breaker trips the tie breaker. The controllers include the following alternating current (AC) protections, according to IEEE Std.
Page 63: Source] Under-Voltage (Ansi 27)
3.4.3 [Source] under-voltage (ANSI 27) Protection IEC symbol (IEC60617) ANSI (IEEE C37.2) IEC 61850 Operate time Under-voltage U<, U<< PTUV < 100 ms Value Delay The alarm response is based on the lowest phase-to-phase voltage, or the lowest phase-to- neutral voltage, from the source, as measured by the controller. The phase-to-phase voltage is point the default.
Page 64: Negative Sequence Voltage (Ansi 47)
The alarm response is based on the highest difference between any of the three phase-to- phase voltage or phase-to-neutral true RMS values and the average voltage, as measured by the controller. The phase-to-phase voltage is the default. Value Delay If phase-to-phase voltages are used, the controller calculates the average phase-to-phase voltage.
Page 65: Zero Sequence Voltage (Ansi 59Uo)
Negative sequence voltages arise when the virtual representation of the phase rotation for an unbalanced system appears negative. Negative sequence voltages can occur where there are single phase loads, unbalanced line short circuits and open conductors, and/or unbalanced phase-to-phase or phase-to-neutral loads.
Page 66: Over-Current (Ansi 50Td)
3.4.7 Over-current (ANSI 50TD) Protection IEC symbol (IEC60617) ANSI (IEEE C37.2) IEC 61850 Operate time Over-current 3I>, 3I>> 50TD PTOC < 100 ms Value Delay The alarm response is based on the highest phase current true RMS values from the source, as measured by the controller.
Page 67: Current Unbalance (Ansi 46)
Parameter Range Fast over-current 1 Fast over-current 2 Latch Not enabled, Enabled Enabled Enabled Action Trip [Breaker] Trip [Breaker] 3.4.9 Current unbalance (ANSI 46) Protection IEC symbol (IEC60617) ANSI (IEEE C37.2) IEC 61850 Operate time Current unbalance IUB> < 200 ms* *Note: This operate time includes the minimum user-defined delay of 100 ms.
Page 68: Directional Over-Current (Ansi 67)
Nominal method example A GENSET controller controls a genset with a nominal current of 100 A. The L1 current is 80 A, the L2 current is 90 A, and the L3 current is 60 A. The current unbalance is (90 A - 60 A) / 100 A = 0.3 = 30 %. 3.4.10 Directional over-current (ANSI 67) Protection IEC symbol (IEC60617)
Page 69 t(I) This is an inverse time over-current alarm. The alarm response is based on the highest phase current true RMS values, based on IEC 60255 part 151, as measured by the controller. The alarm response time depends on an approximated integral of the current measurement over time.
Page 70 Parameter Range Inverse time over-current Latch Not enabled, Enabled Enabled Alarm action Trip [Breaker] Standard inverse time over-current curves The controller includes these standard inverse time over-current curves, in accordance with IEC 60255. Table 3.40 Parameters for the inverse time over-current curves Curve name alpha (α, or a) IEC inverse...
Page 71 Figure 3.1 Standard curve shapes for inverse time over-current, with time multiplier setting (TMS) = 1 1000 time IEC Inverse IEEE Moderately inverse IEC Very inverse IEEE Very inverse IEC Extremely inverse IEEE Extremely inverse G / Gs Definite time characteristic is the point where the alarm shifts from an inverse curve to a definite time characteristic, as the following graph shows.
Page 72: Negative Sequence Current (Ansi 46)
= 3.5 × 500 = 1750 A CT primary INFO If the performance of the inverse time over-current protection is important, DEIF recommends using a current transformer that is rated for a 1 A secondary current (that is, -/1 A). 3.4.12 Negative sequence current (ANSI 46)
Page 73: Zero Sequence Current (Ansi 51Io)
Negative sequence currents arise when the virtual representation of the phase rotation for an unbalanced system appears negative. Negative sequence currents can occur where there are single phase loads, unbalanced line short circuits and open conductors, and/or unbalanced phase-phase or phase-neutral loads. This protection is used to prevent the generator from overheating.
Page 74: Source] Over-Frequency (Ansi 81O)
Parameter Range Zero sequence current Enable Not enabled, Enabled Not enabled Action Warning 3.4.14 [Source] over-frequency (ANSI 81O) Protection IEC symbol (IEC60617) ANSI (IEEE C37.2) IEC 61850 Operate time Over-frequency f>, f>> PTOF < 100 ms Value Delay The alarm response is based on the lowest fundamental frequency (based on phase voltage), from the source.
Page 75: Overload (Ansi 32)
Value Delay The alarm response is based on the highest fundamental frequency (based on phase voltage), from the source. This ensures that the alarm only activates when all of the phase frequencies point are below the set point. time Configure the parameters under Configure > Parameters > [Source] > Frequency protections > Under-frequency #, where # is 1 or 2.
Page 76: Reverse Power (Ansi 32R)
Table 3.47 Default parameters Parameter Range Overload 1 Overload 2 Set point 0 to 200 % of nominal power 95 % 110 % Delay 0.00 s to 1 h 30.00 s 30.00 s Enable Not enabled, Enabled Enabled Enabled Latch Not enabled, Enabled Not enabled Enabled...
Page 77: Reactive Power Import (Ansi 40U)
Value Delay The alarm response is based on the reactive power (Q) from the source, as measured and calculated by the controller. point time Configure the parameters under Configure > Parameters > [Source] > Reactive power protections > Reactive power export #, where # is 1 or 2.
Page 78 The differential current protection detects current faults in the protected Differential Region 1 Region 2 Region 3 zone between the current transformers. The differential current current protection consists of two parts, the stabilised differential current protection and the high set differential current protection. The alarm response of the stabilised differential current protection is dependent on the operating characteristic and the measured restraint diff min...
Page 79: Synchronisation Check, Including Blackout Close (Ansi 25)
3.4.21 Synchronisation check, including blackout close (ANSI 25) Protection IEC symbol (IEC60617) ANSI (IEEE C37.2) IEC 61850 Operate time Synchronisation check (including blackout close) RSYN Voltage For all breakers under power management system (PMS) control, the sync check ensures that the voltages, frequencies, and phase angles are within the allowed limits before the controller closes the breaker.
Page 80: Busbar] Under-Voltage (Ansi 27)
Table 3.54 Default parameters Parameter Range Busbar over-voltage 1 Busbar over-voltage 2 Set point 90 to 120 % of nominal voltage 105 % 115 % Delay 0.00 s to 1 h 5.00 s 3.00 s Enable Not enabled, Enabled Enabled Enabled Latch Not enabled, Enabled...
Page 81: Busbar] Voltage Unbalance (Ansi 47)
Table 3.57 Default inhibits Controller type Inhibit(s) • Generator breaker open GENSET • ACM wire break • Generator breaker open EMERGENCY genset • Tie breaker open • EDG handling blackout • Shaft breaker open SHAFT generator • ACM wire break •...
Page 82: Busbar] Over-Frequency (Ansi 81O)
Controller type Inhibit(s) SHORE connection ACM wire break BUS TIE breaker ACM wire break Busbar voltage unbalance example The busbar has a nominal voltage of 230 V. The L1-L2 voltage is 235 V, the L2-L3 voltage is 225 V, and the L3-L1 voltage is 210 V.
Page 83: Busbar] Under-Frequency (Ansi 81U)
Controller type Inhibit(s) SHAFT generator • Shaft breaker open SHORE connection • Shore breaker open 3.5.5 [Busbar] under-frequency (ANSI 81U) Protection IEC symbol (IEC60617) ANSI (IEEE C37.2) IEC 61850 Operate time Under-frequency f<, f<< PTUF < 50 ms Value The alarm response is based on the highest fundamental frequency (based on phase voltage), Delay from the busbar.
Page 84: Other Ac Protections
3.6 Other AC protections 3.6.1 Lockout relay (ANSI 86) The lockout relay ensures that the alarm action continues for an alarm, until the lockout relay is reset. The controller can function as a lockout relay for alarm conditions which have the Latch parameter enabled. The protection is in effect until the alarm condition is cleared, the alarm acknowledged and the latch is reset.
Page 85: Earth Inverse Time Over-Current (Ansi 51G)
CAUTION Alarms that are latched will not trip the breaker again if the breaker is closed manually by the operator. Optional: Configuring an external lockout relay An external lockout relay with manual reset functionality can be connected to a digital output. The digital output activates if a specific alarm condition is triggered by the controller.
Page 86: Neutral Inverse Time Over-Current (Ansi 51N)
Earth inverse time Parameter Range over-current Time multiplier setting (TMS) 0.01 to 100.0 Threshold 1.0 to 1.3 k (only used if custom curve is selected) 0.001 s to 2 min 0.14 s c (only used if custom curve is selected) 0 s to 1 min alpha (α, or a) (only used if custom curve is 0.001 to 1...
Page 87: Acm Voltage Measurement Errors
Parameters Configure the parameters under Configure > Parameters > Local > 4th current input > Neutral inverse time over-current. Table 3.65 Default parameters Neutral inverse time Parameter Range over-current Curve See the reference IEC Inverse Limit (the set point, also known as LIM) 2 to 200 % of nominal current (4th current input) 30 % Time multiplier setting (TMS)
Page 88: Source]/[Busbar] L# Wire Break
Configure > Parameters > [Busbar] > AC setup > Multiple phase wire break Table 3.66 Default parameters Parameter Range Default Enable Not enabled, Enabled Enabled Latch Not enabled, Enabled Enabled Alarm action Warning 3.7.2 [Source]/[Busbar] L# wire break Controller types: GENSET, SHAFT generator, SHORE connection and BUS TIE breaker controllers These alarms alert the operator to a measurement failure on a phase: •...
Page 89: Acm 1 Data Is Missing
The alarm communicates that the data protocol in the alternating current module (ACM) is not correct. This can occur when the ACM software version is incorrect. Contact DEIF support if you see this error. The alarm action is Warning, and the alarm is always enabled. The alarm parameters are not visible.
Page 90: Introduction
4. Alarms 4.1 Introduction 4.1.1 Overview of alarm processing The controller alarms prevent unwanted, damaging, or dangerous situations from occurring. The alarm handling is an adaptation of the ISA 18.2 standard. You can configure alarm parameters to suit your design and operational needs. Some of the alarms are Enabled by default in the controller.
Page 91 INFO Auto acknowledge can be useful during commissioning and troubleshooting. However, DEIF does not recommend Auto acknowledge during normal operation. During operation the system continues to monitor the Alarm condition(s) and moves alarms between different states as necessary.
Page 92: Alarm Levels
More information See Alarm handling later in this chapter for more information. Alarm latch An additional layer of protection can be added by using a Latch on most alarms. When a Latch is enabled on an alarm, an extra confirmation must be made by the operator, before the alarm can be cleared. The alarm action remains active, even if the Alarm condition clears, until the operator resets the latched alarm.
Page 93: Operate Time
Figure 4.1 Example of alarm levels for busbar voltage Over-voltage 2 Over-voltage 1 No voltage alarms Under-voltage 1 Under-voltage 2 Delay [s] If the operation is in the green area, the controller does not activate any busbar voltage alarms. In the example, an over-voltage Warning alarm is activated if the busbar voltage has been over 105 % of the busbar's nominal voltage for 5 seconds.
Page 94: Alarm Parameters
INFO You can also create custom alarms for the input/output configurations for both analogue and digital terminals. Limitations There are a few limitations to the customising of alarm parameters. These are stated below. Table 4.1 Alarm parameters that cannot be customised Not customisable Notes The list of alarms is fixed, and you cannot add more alarms.
Page 95 Figure 4.2 Typical alarm parameters in PICUS Parameter Range Notes The setting at which the alarm is triggered. Set point Varies Must be considered with Trigger level setting. Reset hysteresis Varies See Reset hysteresis for more information. Delay Varies Delay before the alarm becomes active. Trigger level (fixed)* High, Low Whether the alarm is triggered at a High or Low setting.
Page 96: Set Point
Parameter Range Notes Inhibit(s), that if active, can inhibit the alarm from becoming active. Inhibit(s) #1 to #32 Varies Note that there are only four fields for inhibits in PICUS. Action Varies Action to be taken. *Note: Trigger level is typically fixed and cannot be changed. However, the set point for Directional over-current determines the Trigger level.
Page 97 Alarm actions are used to assign a set of responses for each alarm. Each alarm Action consists of a group of actions that the system takes when the alarm conditions are met. Alarm actions also act as a type of alarm categorisation. Minor alarm situations may be assigned warnings, while a critical situation may trip the breaker and shutdown the genset.
Page 98 Trip tie breaker Controller type EMERGENCY genset controller Priority High Effect The controller trips the tie breaker to the emergency busbar (that is, without de-loading). Trip shore connection breaker Controller type SHORE connection controller Priority High Effect The controller trips the shore connection breaker (that is, without de-loading). Trip bus tie breaker Controller type BUS TIE breaker controller...
Page 99: Delay
Trip generator breaker + AVR + shutdown engine Controller types GENSET and EMERGENCY genset controllers Priority Highest The controller trips the genset breaker (that is, without de-loading) and the AVR (that is, stops Effect reactive power regulation). The controller shuts down the engine, without a cooldown period. Priority of alarm action It is possible for two or more alarm actions to be active for the same equipment at the same time.
Page 100: Inhibit(S)
INFO The total delay before the alarm Action is activated is the Operate time for the alarm plus the Delay parameter. 4.2.6 Inhibit(s) Inhibits stop the alarm Action when the inhibit conditions are active. When an inhibit is active, the controller does not activate the alarm Action, even if all the other alarm conditions are met.
Page 101: Auto Acknowledge
INFO For most alarms the Trigger level is set and cannot be changed. Custom I/O alarms can be configured for High or Low setting of the Trigger level. 4.2.9 Auto acknowledge When Auto acknowledge is selected, the alarm is immediately marked as acknowledged in the alarm display when the alarm is activated.
Page 102: Additional Alarm Information
More information See Alarms > Tasks > Perform an alarm test in the PICUS manual for more information about the alarm test buttons available on the Alarms page in PICUS. 4.2.13 Additional alarm information The additional alarm information provides information about the state of the alarm. This information can be useful during commissioning and trouble shooting.
Page 103: Suppress Action Inhibit
Table 4.4 Inhibit parameters Range Notes The controller inhibits, plus Inhibit #, where # is 1 If you select Inhibit #, and the digital input Activate inhibit # is activated, then to 3 the controller inhibits the alarm. 4.3.2 Suppress action inhibit It can be useful to use a digital input function to suppress the alarm action for certain alarms.
Page 104 Figure 4.5 Alarm processing states (excluding state G, H and I) State A Normal Alarm condition occurs Auto acknowledge State C State B Acknowledge Acknowledged Unacknowledged alarm alarm alarm Acknowledge Alarm Alarm alarm condition condition clears? clears? State D Return to normal Latched Latched Unacknowledged...
Page 105: Acknowledge
Alarm state Description Alarm condition* Alarm** Unacknowledged latched alarm Active Acknowledged latched alarm Active *Note: The alarm condition that triggers the alarm, typically the Set point, may be present Yes or not present No. **Note: Any alarm may be Active or Inactive in the system. If active the alarm Action is also active. INFO Inhibited, shelved, or out of service alarm states force the alarm to be Inactive in the system, even if the Alarm condition is still present.
Page 106: Shelve
Table 4.6 Acknowledgement status and operator actions Acknowledged? Latch? Alarm condition? Alarm action* Required operator actions • The alarm condition must be corrected. Active Active • The alarm must be acknowledged. • The alarm must be reset (unlatched). Latch • The alarm must be acknowledged.
Page 107: Out Of Service
Any state Shelve Operator shelves the alarm. alarm for a period Operator unshelves the alarm. Unshelve State G alarm shelved Operator action Automatic action Check whether the shelve Shelve period has expired. period expired? The controller automatically Unshelve unshelves the alarm after the State A alarm period expires.
Page 108: Latch Reset
4.4.5 Latch reset You can enable a Latch on most alarms. When an alarm with a Latch is activated, the alarm Action remains in force after the Alarm condition clears. The latched alarm then requires acknowledgement and resetting to clear the alarm Action. INFO Alarm latching can provide an extra layer of safety for the system.
Page 109: Alarm Test And Status
Table 4.8 Optional hardware Function Type Details Alarm system > Command > Reset all The controller resets all its latched alarms (that are ready to be Digital input Pulse latched alarms reset) when this input is activated. 4.5 Alarm test and status 4.5.1 Alarm test The alarm tests activate controller alarms AND all their alarm actions.
Page 110: Alarm Status Digital Outputs
4.5.2 Alarm status digital outputs You can configure a digital output with a function for an alarm status. The controller activates the digital output if the alarm status is present. Assign the function to a digital output under Configure > Input/output. Select a hardware module with a digital output, then select the output to configure.
Page 111: Horn Outputs
Function Type Details Alarm system > State > Any latched Continuous Activated if there are any active alarms with active latches in the controller. alarm Alarm system > State > Any shelved Continuous Activated if there are any shelved alarms in the controller. alarm Alarm system >...
Page 112 You can configure up to three horn output functions, and the parameter settings for each of these functions. By adjusting the parameters, each horn output function can be configured as one of four different types of horn output: • Simple horn •...
Page 113 Table 4.12 Simple horn parameters Parameter Default Notes Reset when new alarm Not enabled Minimum down time No effect on the output. Minimum up time No effect on the output. De-energise when all alarms are acknowledged Not enabled INFO Acknowledging alarms (or not acknowledging alarms) has no effect on this horn output. Simple horn example Acknowledge Alarm 1...
Page 114 Acknowledge Alarm 1 Alarm 1 Acknowledge Alarm 2 Alarm 2 Horn The horn output is deactivated when both alarms are acknowledged (even though both alarms are still active). Siren The horn output is activated when one or more alarms are active. The horn output is deactivated when there are no active alarms.
Page 115 Siren with acknowledge The horn output is activated when one or more alarms are active. The horn output is deactivated when there are no active alarms. The horn output is also deactivated when all alarms are acknowledged, even if there are still active alarms. The horn output is affected when a new alarm is activated.
Page 116: Silencing Alarms
4. All alarms are acknowledged during the Minimum down time for alarm 3. After the Minimum down time for alarm 3, the horn output is activated for the Minimum up time, to complete the horn output for alarm 3. 5. The horn output is deactivated after the Minimum up time, since all alarms are acknowledged. 4.6.2 Silencing alarms When the operator presses Horn silence on the display unit, the controller immediately deactivates all horn outputs.
Page 117: Non-Essential Load Trip (Nel) Function
◦ For example, in the same section, there can be an NEL 2 (assigned to DG 1 and DG 2) and also a different NEL 2 (assigned to DG 3 and DG 4). 3. Broadcast the changes to all the controllers in the system. •...
Page 118 Example of three non-essential loads that are connected for full redundancy NEL 1 NEL 2 NEL 3 For redundancy and secure operation, DEIF strongly recommends that all controller NEL trip settings are identical. DESIGNER'S HANDBOOK 4189340911K UK Page 118 of 521...
Page 119 Example of 12 non-essential loads that are connected with no redundancy DEIF recommends that you connect each non-essential load to each controller, so that any controller can trip the non-essential loads. As a minimum, each non-essential load should be connected to at least two controllers. However, it is possible to connect each controller to up to three non-essential loads, with no interaction from the other controllers.
Page 120 Parameter Range Default Notes Enabled: Whenever the controller breaker trips, then the controller also activates the Non-essential load trip # output. The NEL trip remains active as long as the breaker trip is active. The parameters for each alarm are given in the following sections. How the NEL function works Table 4.19 Sequence diagram example with NEL 1 over-current, without a latch...
Page 121: Nel # Over-Current
4.7.3 NEL # over-current These non-essential load trips (NELs) are for over-current protection. The over-current trip may, Value for example, be activated by inductive loads and an unstable power factor (PF < 0.7), which increase the current. Delay The trip response is based on the highest phase current true RMS values from the source, as point measured by the controller.
Page 122: Nel # Overload
*Note: The NEL function also trips NEL #. You cannot reconnect the NEL until the alarm is deactivated. The alarm action cannot be changed. 4.7.5 NEL # overload These non-essential load trips (NEL) are for overload protection. Tripping the NEL groups reduces the active power load at the busbar, and thus reduce the load percentage on all the Value running gensets.
Page 123: Nel # Reactive Overload
4.7.6 NEL # reactive overload These non-essential load trips (NELs) are for reactive overload protection. Tripping the NELs reduces the reactive power load at the busbar, and thus reduce the load percentage on all the Value running gensets. This can prevent a possible blackout at the busbar due to overloading the Delay running gensets.
Page 124: Analogue Input (Ai) Alarms
LOW input trigger example Digital input Alternatively, configure the digital input (DI) so that the alarm is activated if the digital input is open for longer than the HIGH Time delay. Select Low for the alarm trigger level. Time The custom alarm can be configured with typical alarm parameter settings. Configure the alarm under Configure >...
Page 125: Miscellaneous Alarms
Parameter Range Default Notes Set point Varies Depends upon selected input scale unit Reset hysteresis Varies Depends upon selected input scale unit Action Selectable list Inhibit(s) Selectable list Low oil pressure analogue input alarm example Configure the analogue input for the oil pressure sensor under Configure > Input/output > [Hardware module] > AI > Sensor setup.
Page 126: Critical Process Error
1. Restart the controller. 2. If restarting does not help, update the controller software to the latest version. 3. Contact DEIF. 4.9.3 Required I/O card(s) not found This alarm communicates that some of the default hardware modules for the controller type were not found. The alarm action is Warning.
Page 127: Priority Error
This alarm communicates that the same setting in Power management rule 1 to 8 changed at the exact same time on two or more controllers. If the alarm activates, all the controllers where the setting changed at the same time are forced to switchboard control. The alarm condition can be cleared by resetting the controllers on which the alarms occurred.
Page 128: Advanced Blackout Prevention
ALL the ABP alarms enabled in the BUS TIE breaker controller(s). Recommendations for ABP Before closing the bus tie breaker during critical operation, DEIF recommends that you: • Ensure that there is at least one connected genset in each section.
Page 129 Figure 4.8 Example of ABP with two bus tie breakers BUS TIE BUS TIE breaker breaker controller controller Bus tie Bus tie breaker 1 breaker 2 Busbar Busbar Busbar Busbar Genset A Genset B Genset C Genset D Genset E Genset F If all the ABP protections are enabled in both BUS TIE breaker controller 1 and BUS TIE breaker controller 2: •...
Page 130 Parameter Range Default Comment • A BTB opens. The timer starts when de-loading starts. • Asymmetric load sharing is activated/deactivated in a GENSET controller. • An asymmetric load sharing parameter is changed in a GENSET controller. Use this delay to stop ABP from tripping the generator breaker due to normal load sharing changes.
Page 131: Calculating The Load Sharing Error
For these examples: • The system is running with the bus tie breaker closed. • There are no recent load share changes, and so the "Delay after load share changes" timers are not relevant. • Gensets A, B and C are connected, and have equal load sharing. Genset A governor set point failure example The GOV increase relay that regulates Genset A is stuck in a closed position.
Page 132: P Load Sharing Failure (Low Frequency) On Dg
The total load is 900 kW. The internal controller set point Genset A is therefore 600 kW, and the set point for Genset B is 300 kW, that is, 60 % of nominal power. Genset A supplies 500 kW, and Genset B supplies 400 kW. For Genset A, the load sharing error is (500 kW - 600 kW) / (1 000 kW) = -0.1 = -10 % For Genset B, the load sharing error is (400 kW - 300 kW) / (500 kW) = 0.2 = 20 % 4.10.3 P load sharing failure (low frequency) on DG...
Page 133: P Load Sharing Failure (High Frequency) On Dg
4.10.4 P load sharing failure (high frequency) on DG Limit This advanced blackout prevention alarm can be activated if there is both a high frequency and Delay a positive P load sharing error at the GENSET controller. point time GENSET controllers Configure the parameters under Configure >...
Page 134: Q Load Sharing Failure (Low Voltage) On Dg
4.10.5 Q load sharing failure (low voltage) on DG Limit This advanced blackout prevention alarm can be activated if there is both a low voltage and a negative Q load sharing error at the GENSET controller. Delay time point GENSET controllers Configure the parameters under Configure >...
Page 135: Q Load Sharing Failure (High Voltage) On Dg
4.10.6 Q load sharing failure (high voltage) on DG Limit This advanced blackout prevention alarm can be activated if there is both a high voltage and a Delay positive Q load sharing error at the GENSET controller. point time GENSET controllers Configure the parameters under Configure >...
Page 136: Reverse Power On Dg
Configure the parameters under Configure > Parameters > Local power management > Advanced blackout prevention > Overload on a DG. Table 4.37 Default parameters Parameter Range Default Set point 70 to 250 % 120 % Delay 0 s to 1 h Enable Not enabled, Enabled Not enabled...
Page 137: Reactive Power Import On Dg
Table 4.39 Default parameters Parameter Range Default Set point 0.1 to 250 % 120 % Delay 0 s to 1 h 10 s Enable Not enabled, Enabled Not enabled Latch Not enabled, Enabled Enabled Action Trip bus tie breaker Inhibit Bus tie breaker open 4.10.10 Reactive power import on DG Value...
Page 138 Table 4.41 Default parameters Parameter Range Default Set point 70 to 250 % 200 % Delay 0 s to 1 h 0.3 s Enable Not enabled, Enabled Not enabled Latch Not enabled, Enabled Enabled Action Trip bus tie breaker Inhibit Bus tie breaker open DESIGNER'S HANDBOOK 4189340911K UK Page 138 of 521...
Page 139: Introduction
5. Breakers, synchronisation and de-loading 5.1 Introduction 5.1.1 Introduction to synchronisation and de-loading A number of power sources can supply power to the same busbar. These power sources must be synchronised in order to safely connect them. Synchronisation consists of matching the voltage, frequency and phases on both sides of the breaker that must be closed.
Page 140: Regulation Required For De-Loading
5.1.3 Regulation required for de-loading Whenever possible, the breakers are de-loaded before they are opened, to reduce the wear on them. A breaker is de-loaded by reducing the flow of power through the breaker to the required level. In AUTO and SEMI mode, the power management system de- loads a breaker by regulating and/or starting the appropriate gensets to take the load off that breaker.
Page 141: Synchronisation Under Switchboard Control
Switchboard control equipment The following table lists the third party equipment (hardware not generally supplied by DEIF) that may be used for switchboard control. The switchboard buttons are connected directly to the genset or breaker, and are not connected to the controller.
Page 142: Configuring Breakers
Synchronising during switchboard control During switchboard control, if the operator wants to synchronise and close a breaker, the operator must use the switchboard to operate the system. The operator manually adjusts the speed of the relevant equipment until the frequencies are almost the same. The operator then finely adjusts the speed until the power sources are in phase.
Page 143 Wiring examples More information See Wiring examples for controller functions, Breaker wiring in the Installation instructions for an example of pulse breaker wiring. Inputs and outputs Assign the breaker inputs and outputs under Configure > Input/output. Select the hardware module, then select the input/output to configure.
Page 144 Table 5.5 Closing a pulse breaker Pulse on (Parameters > Breakers > [Breaker] > Pulse time ON) To close a pulse breaker: Close breaker 1. Close breaker: Breakers > [Breaker] > Control > [*B] close (digital output). The controller activates this output until there is breaker closed feedback, or for the Pulse time ON.
Page 145: Compact Breaker
5.3.3 Compact breaker To close a compact breaker, the controller sends an open pulse to load the spring, followed by a pause, and then a close pulse. Wiring examples More information See Wiring for controller functions, Breaker wiring in the Installation instructions for an example of compact breaker wiring.
Page 146 Table 5.10 Parameters for a compact breaker Parameter Range Default Notes Compact breaker: This is a type of pulse breaker. In addition, a compact breaker has a spring loaded opening mechanism, which must • Pulse breaker be allowed to charge before the compact breaker is allowed to close. Pulse Breaker type •...
Page 147: Continuous Breaker
4. Breaker closed feedback: Breakers > [Breaker] > Feedback > [*B] closed (digital input). This input is activated when the breaker is closed. Table 5.12 Opening a compact breaker Pulse on (Parameters > Breakers > [Breaker] > Pulse time ON) Open To open a compact breaker: breaker...
Page 148 Assign the breaker inputs and outputs under Configure > Input/output. Select the hardware module, then select the input/output to configure. INFO For a continuous breaker, DEIF recommends installing both of the breaker control relays to ensure precise synchronisation and AC protection operate times. Table 5.14...
Page 149 Table 5.16 Closing a continuous breaker 1. Close breaker: Breakers > [Breaker] > Control > [*B] close (digital Close output). The controller activates this output to close the breaker. breaker 2. Breaker closed feedback: Breakers > [Breaker] > Feedback > [*B] closed (digital input).
Page 150: Redundant Breaker Feedback
Table 5.18 Trip a continuous breaker 1. Number of trip breaker alarms: The number of active alarms with a Trip [breaker] (or similar) alarm Number of action. trip breaker alarms 2. Trip breaker: Breakers > [Breaker] > Control > [*B] trip (digital output).
Page 151: Short Circuit, And Short Circuit Close Attempts
5.3.7 Short circuit, and short circuit close attempts You can connect the breaker's short circuit detection to the controller. Hardware Configure this input under Configure > Input/output. Select the hardware module, then select the input to configure. Table 5.20 Breaker configuration Function Type Details...
Page 152: Synchronisation Functions
Table 5.21 Breaker states Function Type Details Breakers > [Breaker] > State > [*B] is open Digital output Continuous Activated when the breaker is open. Breakers > [Breaker] > State > [*B] is closed Digital output Continuous Activated when the breaker is closed. Breakers >...
Page 153 Name Range Default Notes If this value is too low, there can be reverse power when the breaker closes. For synchronisation: Add Delta frequency max. to the busbar frequency, for the maximum frequency of the synchronising generator. Delta frequency 0.0 to 2.0 Hz 0.3 Hz max.
Page 154 The slip frequency is 0.0 Hz. There is a risk that there will be no movement, and thus no synchronisation. Speed up for slip frequency under 0.3 Hz If the slip frequency is under 0.3 Hz, the controller automatically speeds up the synchronisation rotation until the phase angle difference is 30 degrees.
Page 155 = 1 / (f ) = 1 / (50.1 Hz - 50.0 Hz) = 10 s sync sync genset online genset INFO The phases for both three-phase systems rotate. However, in this example, the vectors for the busbar are shown as stationary to simplify the explanation.
Page 156: Static Synchronisation
INFO To avoid trips caused by reverse power, configure the synchronisation parameters for a positive slip frequency. Close breaker signal The controller always calculates when to send the close breaker signal to get the best possible synchronisation of the power sources.
Page 157 Name Range Default Notes Delta voltage min. 2 to 10 % of nominal The maximum that the voltage of the synchronising generator may be voltage below the voltage of the busbar for the breaker to close. Delta voltage max. 2 to 10 % of nominal The maximum that the voltage of the synchronising generator may be voltage above the voltage of the busbar for the breaker to close.
Page 158 Figure 5.4 Static synchronisation principle 1500 RPM 1501 RPM 50.0 Hz 50.03 Hz Connected genset Synchronising genset Synchronised Rotation (relative) Rotation (relative) α α α Time [s] Phase synchronisation regulation When static synchronisation starts, the frequency regulation regulates the synchronising genset frequency towards the busbar frequency.
Page 159: Regulator Synchronisation Parameters
Figure 5.5 Voltage and phase angle difference for static synchronisation - Phase window + Phase window Direction of busbar rotation + Delta voltage max busbar – Delta voltage min busbar genset Load distribution after synchronisation The difference between the frequencies of the sources is low. The load distribution therefore does not change much when the breaker closes.
Page 160: Synchronisation And Breaker Alarms
Table 5.25 Analogue phase synchronisation parameters Parameter Range Default Notes 0 to 60 The PID gain for the regulator. The PID control integral time. 0 s to 1 min 2.5 s To turn off the integral component, set Ti to 0. This might cause unexpected regulator behaviour.
Page 161: De-Load Failure
Table 5.28 Default parameters Parameter Range Default • GENSET, EMERGENCY genset, SHAFT generator, SHORE connection controllers: 1 min Delay 30 s to 5 min • BUS TIE breaker controller: 2 min Enable Not enabled, Enabled Enabled 5.5.2 De-load failure Value This alarm alerts the operator to breaker de-load failure.
Page 162: Vector Mismatch
Set point 1 to 20 degrees 20 degrees 10 s Delay 5 s to 1 min DEIF recommends that this delay is lower than the genset Breaker synchronisation failure delay. Enable Not enabled, Enabled Enabled Alarm action Warning Frequency-based inhibit The Vector mismatch alarm is inhibited outside of the synchronisation window.
Page 163: Breaker Closing Failure
Table 5.31 Default parameters Parameter Range Default Delay 0.1 to 10.0 s 2.0 s Alarm action Block INFO If no breaker feedback is configured in the Input/output for the breaker, then the parameters are not visible. 5.5.5 Breaker closing failure Breaker This alarm is for breaker closing failure.
Page 164: Breaker Trip (External)
The alarm is always Enabled and Latched when both breaker feedback functions are configured for the breaker. The alarm action is Warning for external breakers and Block for all other breakers. Table 5.33 Default parameters Parameter Range Default Delay 0.1 to 5.0 s 1.0 s INFO If only one or no breaker feedbacks are configured in the Input/output for the breaker, then the parameters are not visible.
Page 165: Phase Sequence Error
Table 5.35 Default parameters Parameter Range Default Enable Enabled, Not enabled Enabled Latch Enabled, Not enabled Enabled Hardware Configure this input under Configure > Input/output. Select the hardware module, then select the input to configure. Table 5.36 Breaker configuration Function Type Details •...
Page 166: Breaker Configuration Failure
5.5.10 Breaker configuration failure This alarm blocks breaker operation if the breaker is not properly configured. The alarm is activated if a breaker is present on the Single-line diagram, but the Input/output functions that are required for the breaker type are not fully configured. This alarm is always enabled, and has the alarm action Block, Latch enabled.
Page 167: Any Bus Tie Breaker Position Failure
5.5.12 Any bus tie breaker position failure This alarm is for any bus tie breaker position failure. Breaker Breaker open open feedback feedback The alarm is based on the breaker feedback signals, which are digital inputs to the controller. The alarm is activated if the breaker Closed and Open feedbacks are both missing for longer than Breaker Breaker...
Page 168: Introduction
See System principles, Control and modes, Switchboard control for more information about how to control the regulators manually through the controller. INFO All the input and output information in this chapter is written from the DEIF controller point of view, except if clearly stated otherwise. Overview of analogue control and relay control Analogue control generally achieves finer control results than relay control.
Page 169 Analogue PID controller A schematic of the analogue PID controller is given below. Analogue control is continuous, and consists of these steps: 1. The controller measures the operating value(s). 2. The controller deducts the measured value from the reference value (that is, the set point) to determine the error (also known as the deviation).
Page 170 A high Kp makes the system respond strongly to the error. However, the response can be too large, and can lead to long settling times. A high Kp may make operation unstable. A low Kp makes the system respond more weakly to the error. A low Kp reduces the settling time. However, the response can be too small, and therefore ineffective.
Page 171: Relay Regulation
From experience, the derivative part can improve regulation during load sharing, power regulation and static synchronisation, when the parameter is properly tuned. INFO Set Td to zero to turn off the derivative part. INFO Use the derivative part if the situation requires very precise regulation (for example, static synchronisation). If the derivative part is used, it MUST be properly tuned.
Page 172 Range Relay position Notes the deadband value. The [Regulator] increase* and [Regulator] decrease* relays remain deactivated continuously. See point 6 on the figures below. *Note: [Regulator] is either GOV, or AVR. If the output is in either the constant or the variable range, the controller activates the configured relay (governor increase or decrease, or AVR increase or decrease) for the required time.
Page 173: Regulation Mode Overview
The Minimum ON time sets the minimum amount of time a relay is allowed to be closed. This should be similar to the minimum time required for the system to respond to the output signal. The Maximum ON time sets the maximum amount of time a relay is allowed to be closed when the regulation is in the constant range.
Page 174 Condition Governor mode AVR mode The genset is running in parallel with another power producing component on the same busbar. The genset • Reactive controller receives a open breaker • Power regulation power command. regulation The controller sends commands to de-load the generator breaker.
Page 175: Governor Regulation Modes
6.2 Governor regulation modes 6.2.1 Overview The genset regulation system consists of a number of basic control modes for the governor. Each controller processes the input information and calculates what action the genset should take to reach the required operating value. The calculated value is then modified according to the governor interface, and sent to the governor.
Page 176: Frequency Synchronisation
6.2.3 Frequency synchronisation During the synchronisation sequence, the controller uses frequency synchronisation regulation to match the genset frequency to the frequency of the busbar. More information See Breakers, synchronisation and de-loading, Introduction, Regulation required for synchronisation for more information. 6.2.4 Phase synchronisation For static synchronisation, during the synchronisation sequence, the controller uses phase synchronisation regulation to match the genset phases to the phases of the busbar.
Page 177: Power Load Sharing
During load sharing the controller regulates the governor output to the gensets. The Power Management System calculates the GENSET controller load set point and communicates this over the DEIF network. By default, all gensets will share an equal portion of the load. Asymmetric power load sharing is also available. For asymmetric load sharing, some gensets can be prioritised to provide an optimum portion of the load per genset, while the other gensets absorb the varying load in the system.
Page 178: Governor Stand-Alone Mode
For stand-alone mode, the controller must have a correctly configured GAM3.2 module. If you want to use stand-alone mode during emergencies, DEIF recommends a reliable back-up power supply for GAM3.2. INFO Stand-alone mode is not related to a stand-alone genset.
Page 179 CAUTION All inputs or outputs used for manual control must be configured on the GAM3.2. The controller must not have any other governor inputs or outputs. Function Type Details The operator activates this input to activate stand-alone mode. Regulators > GOV > If you want one digital input to activate both GOV and AVR stand-alone Modes >...
Page 180: Avr Regulation Modes
INFO All inputs or outputs used for manual control must be configured on the GAM3.2. The controller must not have any other governor inputs or outputs. When the controller is disabled, activate the Stand-alone mode digital input. The GAM3.2 then sends regulation signals based on manual regulation inputs.
Page 181: Reactive Power Regulation
Parameter Range Default Notes 0 to 60 The PID gain for the regulator. The PID control integral time. 0 s to 1 min 2.5 s To turn off the integral component, set Ti to 0. This might cause unexpected regulator behaviour.
Page 182: Reactive Power Load Sharing
Configure these parameters under Configure > Parameters > Regulators > AVR analogue configuration > Reactive power regulation Parameter Range Default Notes 0 to 60 The PID gain for the regulator. The PID control integral time. 0 s to 1 min 2.5 s To turn off the integral component, set Ti to 0.
Page 183: Avr Stand-Alone Mode
GAM3.2. This mode can be used if the rest of the controller is disabled, or if the main controller power supply fails. For stand- alone mode, the controller must have a correctly configured GAM3.2 module. If you want to use stand-alone mode during emergencies, DEIF recommends a reliable back-up power supply for GAM3.2. INFO Stand-alone mode is not related to a stand-alone genset.
Page 184 Inputs and outputs Configure the inputs and outputs under Configure > Input/output. Select the GAM3.2, then select the input or output to configure. CAUTION All inputs or outputs used for manual control must be configured on the GAM3.2. The controller must not have any other AVR inputs or outputs.
Page 185: External Communication
The GAM3.2 regards the rest of controller disabled when it cannot communicate with the rest of the controller (you could even remove the GAM3.2 from the rack). As long as the GAM3.2 has power and the required wiring, you can use it for stand-alone manual regulation.
Page 186 Function Type Details + (V × Voltage offset) % of nominal When configured, the controller receives the reactive power set Regulators > AVR > Reactive Analogue reactive point from this analogue input. The internal controller value for power set point [%] input power the reactive power set point is ignored.
Page 187 Parameter Range Default Notes • Enabled: During frequency regulation, the controller uses the Frequency offset [%] analogue input or Modbus input to determine the frequency set point. • External: The controller uses the Frequency offset [%] analogue input or Modbus input. •...
Page 188: External Communication Using Modbus
Parameter Range Default Notes • Not enabled: The controller ignores the Cos phi set point analogue input • Not enabled and Modbus input. Cos phi set point enable enabled • Enabled • Enabled: During reactive power sharing, the controller uses the Cos phi set point analogue input or Modbus input as the cos phi set point.
Page 189 Function Type Details Regulators > AVR > External set When activated, the controller changes Configure > Parameters > Digital points > Deactivate external Q set Pulse Regulators > AVR general configuration > External offset > Q input point set point enable to Not enabled. Regulators >...
Page 190: Governor
Modbus Valid Modbus Scaling Parameter function Modbus Unit Comment address codes range The value is a percentage of the controller nominal reactive power. Regulators > AVR If the operator activates Activate external Cos phi > Cos phi set 8012 03; 06; 16 60 to 100 set point, the cos phi set point is determined by point...
Page 191 Parameter Range Default Notes Off: The controller does not attempt to regulate the governor, and ignores any configured hardware. • Regulator Relay: The controller uses the relay outputs to regulate the governor (only visible if both • Relay Relay output relays for the governor regulation are configured).
Page 192: Governor Analogue Regulation Function
If the genset load is 0 kW, and 50 kW is required from the genset, it takes at least 10 seconds to ramp up the genset load. If the genset load is 0 kW, and 70 kW is required from the genset, it takes at least 12 seconds to ramp up the genset load. Active power ramp down This parameter defines the speed of the ramp down of the genset active power when the fixed power set point changes or when the genset disconnects from the busbar.
Page 193 -100 to 100 % output [%] output DEIF recommends that you use the full range of the output, that is from -100 % to 100 %, when you configure the output. INFO The setup and parameters for governor regulation using pulse width modulation (PWM) is exactly the same as for an analogue output.
Page 194: Governor Relay Regulation Function
More information See Input/Output, Tasks, Configure the output setup in the PICUS manual for more information about how to configure an analogue output. Parameters You can configure the governor analogue control parameters under Configure > Parameters > Regulators > GOV analogue configuration.
Page 195 Wiring example Regulators > GOV > Control > GOV increase Regulators > GOV > Control > GOV decrease Outputs You must assign these outputs under Configure > Input/output. Select the hardware module, then select a digital output to configure. Table 6.7 Governor: Relay output hardware Function Type...
Page 196: Automatic Voltage Regulator
Parameter Range Default Notes If the controller needs to increase the governor output, the GOV increase digital output is activated for at least the Minimum ON time. While the controller is increasing the governor output, the GOV decrease digital output is not activated. If the controller needs to decrease the governor output, the GOV decrease digital output is activated for at least the Minimum ON time.
Page 197 Parameter Range Default Notes Analogue: The controller uses an analogue output to regulate the AVR (only visible if an analogue AVR regulator output is configured). Regulation delay This parameter sets the time the controller waits before starting to regulate the genset. The delay time starts after the running feedback confirms that the genset is running.
Page 198: Avr Analogue Regulation Function
Reactive power ramp down This parameter defines the speed of the ramp down of the genset active power when the fixed power set point changes or when the genset disconnects from the busbar. This reduces the mechanical strain on the genset and breaker when the breaker opens and the genset stops supplying power to the system.
Page 199 Figure 6.7 Example of pulse width modulation analogue output wiring for AVR regulation Regulators > AVR > AVR output [%] Inputs and outputs You must assign the AVR regulation analogue output under Configure > Input/output. Select the hardware module, then select an analogue output to configure.
Page 200: Avr Relay Regulation Parameters
Parameter Range Default Notes To set this parameter, start with AVR output offset = 0 %. Change the offset value in small increments to fine tune the voltage output of the genset. When you reach the desired genset voltage output, the offset is tuned. 6.6.3 AVR relay regulation parameters You can configure relay outputs on the controller to regulate the AVR.
Page 201: Configuration Alarms
Parameter Range Default Notes Although a relay controller is capable of fast responses, it is recommended to set the Period time to be similar to the response of the system. The Minimum ON time must be long enough to ensure that the AVR can detect the shortest pulse that the controller sends to it.
Page 202: Avr Output Selection Failure
The alarm remains active until either: • The deleted output is added to the Input/output configuration • The correct manual output is selected under Configure > Parameters > Regulators > GOV general configuration > Regulator output > Output type The alarm is always enabled. You cannot see or change the alarm parameters. 6.7.4 AVR output selection failure The controller activates the alarm if an output, either relay or analogue, was selected as the regulation output, but the selected output is then removed from the Input/output configuration.
Page 203: Regulation Alarms
◦ Two regulation digital outputs (AVR increase and AVR decrease). ◦ One regulation analogue output (AO or PWM, AVR output [%]). • If an analogue AVR regulation output is used, the slope of the output curve must be positive. ◦ That is, there must be a lower AVR output % for a lower voltage or current, and a higher AVR output % for a higher voltage or current.
Page 204: Avr Regulation Error
Alarm deviation examples 1. The controller is trying to control the genset to run at 50 Hz, and the measured frequency is 49.5 Hz. • The deviation from the set point is |(49.5 Hz - 50 Hz)| / 50 Hz =0.01 = 1 %. •...
Page 205: P Load Sharing Failure
• The deviation is less than the alarm set point, and the alarm is not activated. 3. The controller is running fixed cos phi regulation with a set point of 0.9 I, and the measured value is 0.95 C. • The deviation from the set point is |(0.95 C - 0.9 I)| / 0.9 I ×...
Page 206 Parameter Range Default Enable Not enabled, Enabled Not enabled Alarm action Warning DESIGNER'S HANDBOOK 4189340911K UK Page 206 of 521...
Page 207: Power Management Principles
7. Power management 7.1 Power management principles 7.1.1 Introduction Power management ensures that the required power is available, the system runs as efficiently as possible, and the system responds appropriately to changes. This requires the controllers to share information and work together. Power management scope The power management system performs the following functions: •...
Page 208 Power availability The controllers share information across the DEIF network, so that each controller can calculate the available power for the section. The PMS power available calculation is used to determine when to start and stop gensets, and to respond appropriately to requests from heavy consumers.
Page 209: Power Management Functions
How it works: 1. The controllers each communicate their genset status, genset nominal power, and the genset power that the controller measures, using the DEIF network. 2. Each controller does the power management calculations. 3. If the controllers calculate that the load-dependent start limit (P available limit) is exceeded, then the controller for the next genset in the priority order starts that genset.
Page 210 • Active power (kW) load sharing (GOV) • Reactive power (kvar) sharing (AVR) • Load sharing between gensets ◦ Over the DEIF network • Load sharing options for each busbar section Load sharing ◦ Equal load sharing (symmetrical) ◦ Asymmetric P load sharing for gensets ◦...
Page 211: Busbar Sections
7.1.3 Busbar sections The power management system manages the power for the busbar sections, according to a set of power management rules. If bus tie breakers are present, then the busbar sections are dynamic. That is, the sections change whenever bus tie breakers are opened or closed.
Page 212: Ring Busbar Connection
Figure 7.3 Example of busbar sections created by closing a bus tie breaker and an externally controlled bus tie breaker Bus tie Bus tie Externally controlled breaker 1 breaker 2 bus tie breaker 1 Section 1-2-3 Section 1-2-3 Busbar A Busbar B Busbar A Busbar B...
Page 213: Local Power Management
Figure 7.4 Example of a ring busbar Bus tie Bus tie Bus tie breaker 1 breaker 2 breaker 3 Section 1 Section 2 Busbar A Busbar B Busbar A Busbar B Busbar A Busbar B BUS TIE BUS TIE BUS TIE breaker breaker breaker...
Page 214: Section Power Management
7.1.6 Section power management For each controller, you can configure parameters for the section power management rules. You can use up to eight sets of power management rules. By default, all controllers use Power management rules 1. When the power management rules are changed for one controller, then all the controllers in the section automatically use the same power management rules.
Page 215 Splitting a section example If the Power management rules # > Number of gensets connected > Maximum is 2 before the split, then PMS will ensure that there are no more than 2 gensets connected to each section during the split. Power management rules when joining two sections The PMS uses the least restrictive section's power management rules when joining two sections.
Page 216: System Power Management
• GENSET controllers C and D use Power management rules 3. More information See CustomLogic, Advanced examples in the PICUS manual for detailed information on how to configure this. Power management rules and BUS TIE breaker controllers You can configure power management rules in a BUS TIE breaker controller. If the bus tie breaker is closed, the power management rules for the BUS TIE breaker controller are treated in the same way as the power management rules for any other controller in the section.
Page 217: Managing Missing Controllers
When harbour operation is active, the emergency genset is always first in the priority order. The power management system sends a start command to the emergency genset, if it is not running when harbour operation starts. The other gensets may be stopped, but the emergency genset keeps running to supply the busbar.
Page 218 The power is included in the PMS power calculations as follows: • GENSET controller : ◦ The controller is in AUTO mode. ◦ The genset is running. ◦ The generator breaker is closed (that is, the genset is connected). • EMERGENCY genset controller : ◦...
Page 219 Available power The available power (also called P avail.) is the difference between the nominal power and the consumed power. For PMS power, the available power calculation uses the connected consumed power, and NOT the PMS consumed power. The PMS available power thus shows whether the PMS generators can meet the section's power needs. If a generator in SEMI mode or under switchboard control is supplying the section, the PMS available power can be negative.
Page 220: Power Reservation
INFO This parameter delays the communication of the new available power to the display unit, CustomLogic, Modbus and other external components. The controllers in the system immediately know how much power is available and can perform load sharing immediately once a new genset connects. Configure the parameter under Configure >...
Page 221: Power Analogue Outputs
You can configure these parameters under Configure > Parameters > Power management rules > Configuration # > Power reservation > Reserved power, where # is 1 to 8. Parameter Range Default Notes Not enabled: The PMS ignores the reserved power set point. Available power = Nominal power - Consumed power Enable Not enabled, Enabled Not enabled...
Page 222: Genset Priority
Applications An analogue output with a power value may be wired to a switchboard instrument, to help with troubleshooting. For example, use Section | PMS P avail. [kW] to troubleshoot load-dependent start and stop. 7.3 Genset priority 7.3.1 Genset start and stop priority order Each genset has a priority that the power management system (PMS) can use to determine which genset to start (or stop) when a genset start (or stop) is needed.
Page 223: Priority Selection Method
Similarly, if a tie breaker closes to join two sections, then the genset priority order for the new section consists of all the GENSET controllers in the new section. Priority in a section example The system has six GENSET controllers. Gensets A, B and C are in section 1. Gensets D, E and F are in section 2. The tie breaker between sections 1 and 2 is open.
Page 224: Dynamic Genset Priority
A new genset priority order should be carefully considered, since it may cause genset starts and stops. You can select Delayed priority shift before changing the priority, to prevent genset starts and stops while changing the priority. Alternatively, if all the GENSET controllers are in SEMI mode while you set the genset priority, then this prevents unwanted automatic genset starts and/or stops.
Page 225: Running Hours For Genset Priority
Manual genset priority inputs also change the dynamic genset priority. There are no parameters specific to Dynamic priority. Rules for dynamic genset priority selection • Each genset's priority is according to the order in which it connects to the busbar. This applies to both AUTO and SEMI mode. The first genset to connect gets priority 1, the second genset gets priority 2, and so on.
Page 226: Genset Priority Digital Outputs
Trip You can use Trip to avoid a situation where gensets with significantly different running times are over- or under-used. For example, if Total is used, then an older genset might not run at all until the newer gensets get up to the same number of running hours. Example Swap timer for the Total and Trip methods There are three gensets (A, B, C) in the system.
Page 227: Genset Start And Stop
Table 7.5 Genset priority functions Function Type Details Power management > Is first Activated when the GENSET controller has the first priority in the Digital output Continuous priority section. Activated when the GENSET controller controls the first genset in Power management > Is first Digital output Continuous the section that the power management system would attempt to standby...
Page 228: Load-Dependent Start Configuration
7.4.2 Load-dependent start configuration This configuration defines when the power management system (PMS) automatically starts gensets. The PMS starts gensets when the section load increases, for example, if the operator starts some equipment. These parameters only apply to GENSET controllers in AUTO mode. INFO If the PMS available power is negative, the PMS starts another genset immediately, and does not wait for the load- dependent start timer.
Page 229 Parameter Range Default Notes If Calculation in S is selected, this limit is based on the percentage of apparent power. If the load exceeds the limit for the whole of the delay period, then the PMS starts Delay 5 s to 1 h 30 s the next genset in the priority order.
Page 230: Load-Dependent Start Flowchart
Two sets of load-dependent start parameters You can use both sets of load-dependent start parameters: • Configure one parameter set for low available power, with a long timer setting. ◦ The timer period helps to ensure that the genset start really is needed. •...
Page 231: Load-Dependent Stop Configuration
7.4.4 Load-dependent stop configuration This configuration defines when the power management system (PMS) automatically stops gensets. The PMS stops gensets when the section load decreases. These parameters only apply to GENSET controllers in AUTO mode. Hardware Assign the hardware digital input under Configure > Input/output. Select a hardware module, then select a digital input to configure.
Page 232 Parameter Range Default Notes stopped. If the load percentage is lower than this limit for the Delay period, then the PMS automatically disconnects and stops a genset. If Calculation in P is selected, then this limit is based on the percentage of active power.
Page 233 Example 1: Gensets A, B and C are running. For the load percentage calculation, the total nominal power connected if genset C was stopped is Genset A nominal power + Genset B nominal power = 1500 kW. The load percentage is 700 kW / 1500 kW = 0.47 = 47 %. If the load percentage remains below the Load limit for the Delay time, the PMS stops genset C.
Page 234: Load-Dependent Stop Flowchart
7.4.5 Load-dependent stop flowchart PMS control, GENSET in AUTO Available power > Load- dependent stop limit Load-dependent 1. The load-dependent stop timer starts when the PMS available power is more than stop timer starts (the load-dependent stop limit + the nominal power of the lowest priority running genset).
Page 235: Power Method And Hysteresis
Load-dependent stop The PMS calculates what the PMS available power would be if the connected genset that is last in the priority order is stopped. If this is higher than the Load-dependent stop limit for the specified time, that genset will be stopped. Example The system consists of two gensets, each with a nominal power of 1500 kW.
Page 236: Percent Method For Load-Dependent Start And Stop
The following graph of PMS available power shows an example of the hysteresis between the stop and start for the power method. The section consists of two equally sized gensets. The start and stop delays are 0 seconds. At the beginning of the period shown on the graph, the section is unpowered.
Page 237: Percent Method And Hysteresis
Load-dependent stop The PMS calculates what the genset load percentage would be if the connected genset that is last in the priority order is stopped. If this is lower than the Load-dependent stop limit, that genset will be stopped. Example The following graph shows how the genset load percentage start and stop function works.
Page 238: Non-Connected Genset
INFO For the percent method, the load-dependent stop limit must be LOWER than the load-dependent start limit. Equally sized gensets example The section has three 1000 kW gensets. The priority order is A, B, C. Start 1 > Load limit is 90 %, and Stop 1 > Load limit is 70 %.
Page 239: Precautionary Genset Start
How the non-connected genset function works Non-connected genset running in AUTO The timer starts ..GENSET controller ... the timer expires. The power management system stops the genset. GENSET controller 7.4.11 Precautionary genset start During critical operations, you may want to have a genset running and ready to connect. You can therefore configure an input with the Precautionary genset start function.
Page 240 INFO Precautionary genset start does not start the emergency genset. Precautionary genset start based on an input If needed, assign the input under Configure > Input/output. Select the hardware module, then select the input to configure. Table 7.6 Optional input Function Type Details...
Page 241: Number Of Gensets Connected
INFO The precautionary genset start is based on the busbar voltage and frequency alarms. You cannot disable the precautionary genset start based on an alarm. However, you can change the busbar voltage and frequency alarm parameters. 7.4.12 Number of gensets connected These parameters determine the minimum and maximum number of connected gensets required for the section.
Page 242: Blackout
Parameter Range Default Notes The system is limited to a maximum of 12 controllers. If you have 12 GENSET controllers, and you set this parameter to 12 or higher, all the gensets in AUTO mode are always connected. 7.5 Blackout 7.5.1 Blackout and blackout recovery conditions Blackout recovery is the power management system's attempt to recover from a blackout by connecting to another power source, or starting one or more gensets automatically, when a dead busbar is detected.
Page 243: Blackout Recovery Configuration
7.5.2 Blackout recovery configuration When a blackout is detected, all the GENSET controllers in SEMI mode are changed to AUTO mode. Input Assign the input under Configure > Input/output. Table 7.10 Optional input Function Type Details Power management > Block blackout Blackout recovery is prevented in any section where this Digital input Continuous start...
Page 244 Parameter Range Default Notes The first step of the blackout recovery sequence is to try to restore power by closing the bus tie breaker. Configure this parameter under Configure > Parameters > Local power management > Return modes > After blackout. This parameter is only visible in GENSET controllers.
Page 245: Blackout Recovery Flowchart
More information See Alarms, Alarm parameters, Action suppressed for information about suppressing alarm actions during blackout recovery. 7.5.3 Blackout recovery flowchart Blackout detected Blackout continues Blackout recovery possible Shaft Shore Genset Voltage generator connection ready, on other OK & auto OK &...
Page 246: Load Sharing
To efficiently control the gensets' operation, the power management system must perform load sharing for the gensets. The load sharing is achieved by using the DEIF network load sharing (for DEIF controllers connected together via Ethernet cabling).
Page 247: Equal Load Sharing
Load sharing over the DEIF network occurs automatically when the controllers are under PMS control, provided all the necessary I/O settings and parameters are configured. INFO Only DEIF controllers can be used for load sharing over the DEIF network. No other vendors' controllers can be used for load sharing over the DEIF network. 7.6.3 Equal load sharing For equal load sharing, the gensets each run at the same percentage of nominal load.
Page 248 Name Details DEIF network The DEIF network is used for asymmetric P load sharing. GOV control The controller must control the genset governor for active power load sharing. Control types For controllers under power management system control (that is, in AUTO or SEMI mode), if enabled, the power management system uses asymmetric P load sharing to share the load between the connected equipment.
Page 249 Parameter Range Default Notes • Parameter: The controller uses the Set point parameter as the set point for asymmetric P load sharing. • External: The controller uses the analogue input with Local power management > Asymmetric load sharing > P set point [%] as the set point for asymmetric P load sharing.
Page 250 Load-dependent start and stop The load-dependent starts and stops are based on either power (P, in kW) or apparent power (S, in kVA). The load-dependent start and stop parameters are independent of the asymmetric P load sharing parameters. The load-dependent start and stop parameters determine how many gensets are connected. The asymmetric P load sharing parameters determine the load distribution among the connected gensets.
Page 251 INFO To make the effect of asymmetric P load sharing clearer, the asymmetric P load sharing Minimum in this example is higher than the default (5 %). Example: Increasing load, equal P load sharing Load [kW] Parameters s1 = Load-dependent start s2 = Asymmetric P load sharing Minimum Points on graph 1.
Page 252 Example: Increasing load, asymmetric P load sharing Load [kW] Parameters s1 = Asymmetric P load sharing Set point Points on graph 1. Genset A and Genset B share the load equally. Asymmetric P load sharing would required Genset B to run below the minimum. Power 2.
Page 253 Example: Increasing load, equal P load sharing to avoid exceeding maximum Load [kW] Parameters s1 = Asymmetric P load sharing Maximum s2 = Load-dependent start s3= Asymmetric P load sharing Set point Points on graph 1. Genset A runs at its asymmetric P load sharing set point, and the load Power on Genset B varies.
Page 254: Asymmetric Q Load Sharing
Asymmetric Q load sharing can also be configured so that, as far as possible, a particular genset supplies a base reactive power load. Asymmetric Q load sharing is done by the power management system over the DEIF network. Hardware The following hardware is required for asymmetric Q load sharing.
Page 255 Input If required, assign input functions under Configure > Input/output. Select the hardware module, then select the input to configure. Table 7.13 Optional hardware Function Type Details When this input is configured, and Configure > Parameters > Local % of genset Local power management >...
Page 256 Parameter Range Default Notes analogue input and uses the Set point parameter as the set point for asymmetric Q load sharing. The asymmetric Q load sharing set point for the genset. Whenever possible, the 1 to 100 % of power management system adjusts the load of lower priority gensets, and gensets Set point nominal reactive 80 %...
Page 257: Shaft Generator Base Load
If asymmetric Q load sharing is enabled, but equal P load sharing is enabled, there can then be a difference between the power factors of the generators that supply the highest and lowest reactive power. Power factor example for asymmetric Q load sharing with equal P load sharing Three 100 kW gensets use equal P load sharing to supply 180 kW.
Page 258 Parameter Range Default Notes If the system load is lower than this set point, the power management system deloads the gensets to the Minimum limit so that the shaft generator can run as close to this set point as possible. If the system load is higher than this set point, the power management system transfers the load to the gensets so that the shaft generator runs at the Set point.
Page 259: Shore Connection Base Load
Load [kW] Maximum 1500 Total 1250 Base load Shaft 1000 generator Minimum Genset 7.6.7 SHORE connection base load INFO A SHORE connection controller can only be assigned a base load. The power management system distributes the load to keep the shore connection at the base load set point. The GENSET controllers share the rest of the load.
Page 260: Deif Network Load Sharing Failure
7.6.8 DEIF network load sharing failure The P load sharing failure and Q load sharing failure alarms alert the operator to the failure of the DEIF network load sharing. Other alarms are also activated if communication is lost in the DEIF network.
Page 261: Configuring Heavy Consumers
7.7.2 Configuring heavy consumers Single line diagram To add a heavy consumer to the single-line diagram: 1. In PICUS, under Configure > Single-line, drag the HC icon to the right place on the single-line diagram. 2. Select the heavy consumer on the single-line diagram, and, if necessary, change its System ID, Feedback type, Controller ID and Label.
Page 262 Function Type Details power management system (PMS) reserves 100 % of the power required for the heavy consumer at the busbar. Required if Variable is selected for Feedback type. For example, this can be connected to a power transducer with a 4 to 20 mA output, and configured so that 4 to 20 mA corresponds to 0 to Heavy consumers >...
Page 263 Table 7.18 Heavy consumer acknowledge Parameter Range Default Comment Pulse width 1 to 10 s 1 s The heavy consumer acknowledge digital output is activated for this period. The time the controller waits before activating the heavy consumer acknowledge digital output. Delay 0 to 30 s 0 s If the acknowledge signal is delayed, the generators have time to stabilise the load on the...
Page 264: Heavy Consumer Sequence
7.7.3 Heavy consumer sequence Fixed heavy consumer sequence Figure 7.7 Sequence diagram for the fixed heavy consumer function with a pulse request signal Request Extra power available Acknowledge Feedback t1 = Time required to start extra genset(s) for the heavy consumer t2 = Pulse width (Configure >...
Page 265 t3 = Pulse width (Configure > Parameters > Heavy consumers > [Heavy consumer #] > Acknowledge, where # is 1 to 4 and [Heavy consumer #] can be replaced by the heavy consumer Controller label) 1. Request: Heavy consumers > [Heavy consumer #] > Request (digital input). An operator or an external signal activates this input.
Page 266: Heavy Consumer Flowcharts And Example
7.7.4 Heavy consumer flowcharts and example Heavy consumer request flowchart Heavy consumer request on 1. When a heavy consumer needs to start, a request is sent to the controller by activating the Heavy consumers > [Heavy consumer #] > Request Start reservation digital input.
Page 267 Heavy consumer acknowledge and feedback flowchart Activate heavy consumer acknowledge request Sequence ends (continuous) 1. When enough power is available, the controller activates the Heavy consumers > [Heavy consumer #] > Acknowledge output for the Pulse width. The Feedback timeout > Delay timer starts running. 2.
Page 268: Fast Load-Reduction
Variable load example The following graph shows the effect of a heavy consumer with a variable load. Figure 7.10 Example of heavy consumer with variable load Power Nominal power Available power Required power Nominal power Available Required power power Consumed power Consumed power Heavy...
Page 269: Protections
The externally controlled bus tie breaker function allows an externally controlled bus tie breaker to be present. This breaker is opened or closed by the operator. The DEIF controllers only receive position feedback from the breaker, and do not control it.
Page 270 Each external bus tie breaker creates a new section on the single-line diagram. Additional equipment You should install a check sync relay or a paralleling relay in the switchboard to check the synchronisation before closing, for example, the DEIF CSQ-3 or HAS. Wiring example More information See Wiring for controller functions, Breaker wiring in the Installation instructions for an example of external breaker wiring.
Page 271: Externally Controlled Shore Connection
The externally controlled shore connection function allows an externally controlled shore connection to be present. This breaker is opened or closed by the operator. The DEIF controllers only receive position feedback from the breaker, and do not control it. Single-line diagram To add an externally controlled shore connection to the single-line diagram: 1.
Page 272 Table 7.25 Optional hardware Function Type Details Breakers > Breaker feedback # > State > Breaker # feedback is Activated when the breaker is Digital output Continuous open* open. Breakers > Breaker feedback # > State > Breaker # feedback is Activated when the breaker is Digital output Continuous open* is closed*...
Page 273: Power Management Alarms
7.9 Power management alarms 7.9.1 Breaker # feedback position failure Breaker open feedback This alarm is for an externally controlled breaker or redundant breaker feedback position failure. Breaker The alarm is based on the externally controlled breaker feedback signals, which are digital closed feedback inputs to the controller.
Page 274: Blackout Detection Mismatch
7.9.2 Blackout detection mismatch This alarm communicates that not all controllers in the section detected the blackout. The alarm is based on the blackout detection for all the controllers in the section. The alarm is activated when one or more controllers detect a blackout, while one or more controllers in the same section do not detect a blackout, and this continues for longer than the delay time.
Page 275: Heavy Consumer Feedback Timeout
Table 7.28 Default parameters Parameter Range Default Delay 1 s to 1 h 2 min Action Warning, Latch enabled 7.9.4 Heavy consumer feedback timeout This alarm communicates that the requested heavy consumer did not give feedback within the configured time after the request was acknowledged. The timer starts when the controller activates the Heavy Request consumers >...
Page 276: Missing Controller Id
Table 7.30 Default parameters Parameter Range Default Action Warning 7.9.6 Missing controller ID # This alarm communicates a communication failure with one or more controllers in the single-line diagram. The alarm is activated when a controller is present on the single-line diagram, but the controller displaying the alarm cannot communicate with it.
Page 277: Forced To Switchboard Control
When the alarm is activated, the power management system changes the mode of the remaining controllers in the section according to the parameters in Configure > Parameters > System > Monitoring > Mode while controller missing and PMS mode while controller missing.
Page 278: Deif Network Redundancy Broken
7.9.12 DEIF network redundancy broken This alarm applies to the DEIF network connection between the controller PCM modules. The alarm is activated when there is no redundant communication between the controllers. This alarm is based on the single-line diagram and the application communication.
Page 279: Different Power Management Rules Activated
The alarm can for example activate when a controller with a newer software version than the other controllers is added to the network. This includes different DEIF products in the same system, for example, PPU 300 controllers and PPM 300 controllers.
Page 280: Genset Controller Overview
Each GENSET controller can control up to four heavy consumers (HC) and connect up to three non-essential load groups (NEL). Figure 8.1 Example of a GENSET controller application, with optional heavy consumers and non-essential loads Display DEIF network GENSET controller Genset 1 8.1.3 GENSET controller functions...
Page 281 Functions • Generator breaker blackout close • PID regulators for analogue outputs • P regulators for relay outputs ◦ Relay period time and Minimum ON time configurable • Set point selection ◦ Select mode or external set point, using digital input, Modbus, and/or CustomLogic •...
Page 282: Genset Controller Principles
Functions • Display unit push-buttons ◦ Change control mode (AUTO & SEMI) ◦ Push-button functions also possible using inputs, PICUS, and/or Modbus ◦ Intuitive, one-touch sequences using the display unit for genset start & stop, and breaker open & close in SEMI mode 8.2 GENSET controller principles 8.2.1 Configuring a GENSET controller Configure each GENSET controller in the single-line diagram, using PICUS.
Page 283: Run Coil Or Stop Coil
Table 8.2 Nominal setting calculation method Calculation method Options Default Q nominal calculated Reactive power (Q) nominal Q nominal = P nominal Q nominal calculated Q nominal = S nominal No calculation P or S nominal P nominal calculated No calculation S nominal calculated More information See AC configuration and nominal settings, Nominal settings, Nominal power calculations for more information.
Page 284: Running Detection
See the Data sheet for the measurement range. The voltage must also be at least 10 % of nominal for the controller to use the frequency for running detection. For safety, DEIF recommends that you install at least one other running detection input.
Page 285 Parameter Range Default Comment Number of magnetic pickup The controller uses the number of teeth to calculate the engine speed from 1 to 10000 1 teeth the MPU/W/NPN/PNP measurement signal. Configure these parameters under Configure > Parameters > Engine > Running detection > Feedback type. Parameter Range Default...
Page 286 Example: Running detection ON The following sequence diagram is an example of how Running detection changes during an engine start. Running detection changes from OFF to ON when one running feedback detects that the engine is running. Figure 8.2 Running detection ON sequence diagram Set point Frequency Set point...
Page 287: Regulation
Risks when using only frequency for running detection It is possible to only use frequency for running detection. However, using only frequency for running detection increases the risk of not detecting that the genset is running. The software only uses the frequency measurements when the voltage is at least 10 % of the nominal voltage. This could cause trouble, since the voltage does not necessarily increase linearly with speed (this depends on the AVR).
Page 288: Load Sharing
8.2.7 Load sharing When a GENSET controller is under PMS control, it shares the load with other DEIF controllers using the DEIF network. More information See Power management, Load sharing for more information. 8.2.8 Ready for operation The genset associated with a GENSET controller is ready for operation when the following conditions are met: •...
Page 289 Inputs and outputs The tables below describes the inputs and outputs for the engine start function. Assign the engine start inputs and outputs under Configure > Input/output. Select the hardware module, then select the input/ output to configure. Table 8.6 Required engine start output Function Type...
Page 290 Table 8.9 Crank parameters Parameter Range Default Comment For the Crank on part of the start sequence, the controller activates the Crank Crank on 1 s to 3 min output for this period. If there is no running detection during Crank on, then the controller deactivates the Crank off 1 s to 3 min Crank output for this period.
Page 291: Engine Start Flowchart
Table 8.11 Run coil parameters Parameter Range Default Comment Run coil before Optional. The controller activates the Run coil output for this time before the 0 s to 3 min crank Crank output is activated. Follow crank: If the start attempt fails, the controller deactivates the Crank output and the Run coil.
Page 292: Engine Start Sequence
Table 8.13 Engine start flowchart* 1. Command and mode match: The controller checks that the command source and the controller mode match: Genset • In AUTO mode, the power management system must send the start command command to start the genset. The controller ignores all other external commands.
Page 293 Figure 8.4 Successful engine start sequence for a stop coil system Start attempts Crank Running detection t1 = Crank on (Parameters > Engine > Start sequence > Crank > Crank on) 1. Start attempts: The engine starts during the first start attempt. 2.
Page 294 Engine start sequence for a run coil system In this example, the Engine > Start sequence > Run coil > During start attempts parameter is set to Follow crank. The engine speed (RPM measurement) and/or the Remove start (release crank relay) digital input do not disengage the crank before there is Running detection.
Page 295: Interruption Of The Start Sequence
Table 8.15 Successful engine start sequence with start prepare t1 = Start prepare (Parameters > Engine > Start sequence > Start Start prepare > Start prepare) attempts t2 = Extended start prepare (Parameters > Engine > Start sequence > Start prepare > Extended start prepare) 1.
Page 296 The controller software includes pre-programmed genset stop sequences. For the engine's stop function, you must configure these inputs and outputs, and parameters. Parameters that need a hardware function are not visible until the function is assigned to an input or output. More information See GENSET controller alarms for more information on how the engine stop alarms work, and how to configure them.
Page 297: Engine Stop Flowchart
8.4.2 Engine stop flowchart The following flowchart shows how the controller normally stops a genset. An engine shutdown is described later. This flowchart does not apply to switchboard control. When the controller is under switchboard control, it will not stop the genset. If, for example, the operator presses the push-button Stop on the display unit, the controller ignores this command, and the controller display unit shows an info message.
Page 298 Figure 8.7 Engine stop sequence for a stop coil system Stop Cooldown Stop coil Running detection Figure 8.8 Engine stop sequence for a run coil system Stop Cooldown Run coil Running detection Cooldown (Configure > Parameters > Engine > Stop sequence > Cooldown > Normal) Extended stop (Configure >...
Page 299: Engine Shutdown Flowchart
Configure an analogue input with the Engine > Cooldown > Coolant water [C] function and Configure > Parameters > Engine > Stop sequence > Cooldown > Temperature threshold. INFO You must configure the analogue input function to see the parameters. 8.4.4 Engine shutdown flowchart The engine is shut down for the following alarm action: •...
Page 300: Generator Breaker Close Flowchart
General breaker information More information See the Breakers, synchronisation and de-loading chapter for more information on synchronisation and breakers. This includes the inputs and output functions and the parameters to configure. [Breaker] refers to Generator breaker. The breaker abbreviation ([*B]) is GB. 8.5.2 Generator breaker close flowchart The following flowchart shows the sequence that the controller normally uses to close the generator breaker.
Page 301: Generator Breaker Blackout Close
1. Command and mode match: The controller checks that the command GB close source and the controller mode match: command • In AUTO mode, the power management system must send the command to close the generator breaker. The controller ignores all other external commands.
Page 302: Generator Breaker Open Flowchart
Manual blackout close not possible During a blackout, the GENSET controller is forced into AUTO mode. Since the GENSET controller is not in SEMI mode, the operator cannot close the breaker by pushing the push button Close breaker on the display unit. 8.5.4 Generator breaker open flowchart The following flowchart shows the sequence that the controller normally uses to open the generator breaker.
Page 303: Generator Breaker Trip Flowchart
1. Command and mode match: The controller checks that the command source and the controller mode match: GB open command • In AUTO mode, the power management system must send the command to open the generator breaker. The controller ignores all other external Command commands.
Page 304: Other Genset Controller Functions
Table 8.19 Generator breaker trip flowchart Generator breaker trip Open GB 1. Open GB: When a trip is required, the controller activates the Breakers > Generator breaker > Control > GB Open output to open the breaker. 2. GB opened: The controller checks whether the breaker has opened: •...
Page 305: Temperature-Dependent Power Derating
Parameter Range Default Comment Not enabled: The controller does not activate the Priming output. Enabled: After the engine stops, the controller activates the Priming output for Enable Not enabled, Enabled Not enabled the period configured under ON timer. The controller then deactivates the output for the period configured under OFF timer.
Page 306: Engine Operating Values As Analogue Outputs
Temperature-dependent power derating example There are two 1000 kW gensets in the system. For genset A, the power derate curve is 100 % until 80 °C, then linearly down to 70 % at 100 °C. Genset B does not have power derating. The genset A temperature is 90 °C.
Page 307: Counters
Table 8.21 Engine state functions Function Type Details Engine > State > Running Digital output Continuous Activated if there is running detection for the engine. Engine > State > Not running Digital output Continuous Activated if there is no running detection for the engine. Activated if there is any condition that would block the controller Engine >...
Page 308: Trip Avr
Trip AVR (or similar) alarm action are not active. Trip 8.7 GENSET controller alarms 8.7.1 GENSET controller alarms INFO These alarms are in addition to the AC protections and general alarms for PPM 300 controllers. DESIGNER'S HANDBOOK 4189340911K UK Page 308 of 521...
Page 309 Table 8.26 Alarms for the GENSET controller Alarms Emergency stop Overspeed (2 alarms) Under-speed (2 alarms) Governor regulation error Power ramp up error Power ramp down error Crank failure Primary running feedback failure Engine Start failure Stop failure EIM3.1 # relay 4 wire break (where # is 1 to 3) Engine stop (external) Engine start (external) Start enable removed during start...
Page 310: Alarm Actions
Alarms • Up to 3 non-essential loads per controller • Can connect each controller to the same 3 non-essential load breakers NEL # over-current (1 alarm for each non-essential load) Non-essential load (NEL) NEL # under-frequency (1 alarm for each non-essential load) NEL # overload 1 and 2 (2 alarms for each non-essential load) NEL # reactive overload (1 alarm for each non-essential load) P load sharing failure (low frequency)
Page 311: Breaker Alarms
Inhibit Disables the alarm when ... No generator frequency The generator frequency is below 10 % of the nominal frequency. Controller under SWBD The Local > Mode > Switchboard control digital input is activated, OR a system problem forced the control controller under switchboard control.
Page 312 Table 8.29 Generator AC alarm names for the GENSET controller Controller alarm Configure > Parameters > General name Generator over-voltage 1 or 2 Generator > Voltage protections > Over-voltage 1 or 2 Over-voltage Generator under-voltage 1 or 2 Generator > Voltage protections > Under-voltage 1 or 2 Under-voltage Generator voltage unbalance Generator >...
Page 313: Emergency Stop
8.7.6 Emergency stop Digital input delay You can configure one of the controller's digital inputs as the emergency stop. high When this input is present, the alarm is always enabled. The alarm parameters are not visible. The alarm action is Trip generator breaker and shutdown engine, latch enabled. time Assign the Emergency stop input under Configure >...
Page 314: Underspeed
8.7.8 Underspeed Value Delay This alarm alerts the operator that a genset is running too slowly. point The alarm response is based on the engine speed as a percentage of the nominal speed. If the engine speed drops below the set point for the delay time, then the alarm is activated. time Configure these parameters under Configure >...
Page 315: Primary Running Feedback Failure
8.7.10 Primary running feedback failure This alarm is for genset running feedback failure. This alarm is only Start available if more than one running feedback is present. The alarm is attempt activated if running is detected on any of the secondary running feedbacks but not on the primary running feedback.
Page 316: Start Enable Removed During Start
Table 8.36 Default parameters Parameter Range Default Enable Not enabled, Enabled Enabled Latch Not enabled, Enabled Enabled Action Block 8.7.12 Start enable removed during start The alarm response is based on the engine start-up sequence. This alarm is activated if the engine start-up procedure is interrupted by the loss of the Start enable input before the engine has started.
Page 317: Engine Stopped (External)
Configure the parameters under Configure > Parameters > Engine > Start sequence > Engine started (external). Table 8.39 Default parameters Parameter Range Default Enable Not enabled, Enabled Enabled Action Warning 8.7.15 Engine stopped (external) Running detection Delay This alarm alerts the operator to an externally-initiated engine stop. The alarm is activated if the controller did not initiate an engine stop, but Running detection shows that the engine has stopped.
Page 318: Trip Running Hours Notification
8.7.17 Trip running hours notification Value This alarm notifies the operator when the trip running hours exceeds the set point. point The alarm response is based on the Trip running hours counter. time Configure these parameters under Configure > Parameters > Engine > Maintenance > Running hours trip. Table 8.42 Default parameters Parameter...
Page 319: Dg-Sg Max. Parallel Time
8.7.19 DG-SG max. parallel time This alarm limits the time that a genset may run in parallel to a shaft generator. The timer starts when the genset or emergency genset are synchronised with the shaft generator. Controller types: If a SHAFT generator controller is present in the system, these alarms are present in GENSET and EMERGENCY genset controllers.
Page 320 More information See Hardware characteristics and configuration for more information. DESIGNER'S HANDBOOK 4189340911K UK Page 320 of 521...
Page 321: Emergency Genset Controller Overview
9.1.2 Applications The system can have 0 or 1 EMERGENCY genset controllers. Each EMERGENCY genset controller can connect up to three non- essential load groups (NEL). Figure 9.1 Example of an EMERGENCY genset controller application DEIF network Display EMERGENCY genset...
Page 322 Functions • Tie breaker close sequence (with synchronisation) • Load transfer between emergency and main busbar without synchronisation ◦ Uses short blackout, with configurable delay ◦ Tie breaker close sequence and generator breaker close sequence • Test sequence • Harbour mode start and stop sequences •...
Page 323: Emergency Genset Controller Principles
Functions ◦ Power export (active and reactive) • Priming Other • Temperature-controlled start/stop • Power management system (PMS) control ◦ AUTO mode ◦ SEMI mode • Switchboard control Control types ◦ Operator controls the system from the switchboard ◦ Only the controller protections are active •...
Page 324: Emergency Genset Controller Nominal Settings
9.2.2 EMERGENCY genset controller nominal settings The controller nominal settings are used in a number of key functions. For example, many protection settings are based on a percentage of the nominal settings. Generator nominal settings Configure these nominal settings under Configure > Parameters > Generator > Nominal settings. Table 9.1 Controller nominal settings Nominal setting...
Page 325: Running Detection
More information See Power management for more information. 9.2.6 Load sharing During Harbour mode, the EMERGENCY genset controller shares the load with other DEIF controllers using the DEIF network. More information See Power management, Load sharing for more information. 9.2.7 AC configuration More information The AC configuration and nominal settings chapter describes the AC configuration in general.
Page 326: Engine Stop
More information See GENSET controller, Engine start for more information. More information See EMERGENCY genset controller, EMERGENCY genset controller protections for more information. 9.4 Engine stop 9.4.1 Engine stop function The controller software includes pre-programmed emergency genset stop sequences. More information See GENSET controller, Engine stop for more information.
Page 327: Generator Breaker Close Flowchart
Parameter Range Default Comment Not enabled: The tie breaker and the generator breaker can never be closed at the same time. The controller uses a short blackout to do a quick change from one supply to the other. The operator may hear "click-clack" as the one breaker opens and then the other breaker closes.
Page 328: Generator Breaker Open Flowchart
1. GB open: After getting the GB close signal, the controller GB close checks whether the generator breaker is open. If the generator signal breaker is already closed, the sequence stops. 2. Genset started: The controller checks whether the emergency genset started successfully.
Page 329: Generator Breaker Trip Flowchart
9.5.5 Generator breaker trip flowchart The trip sequence of the generator breaker for the emergency genset is the same as for a standard genset generator breaker. More information See GENSET controller, Generator breaker, Generator breaker trip flowchart for more information. 9.5.6 Tie breaker close flowchart The tie breaker close sequence is determined by the configuration of the EMERGENCY genset controller, and by the EMERGENCY genset controller breaker parameters.
Page 330: Tie Breaker Open Flowchart
1. TB closed: After getting the TB close signal, TB close the controller checks whether the tie breaker signal is closed. If the tie breaker is already closed, the sequence stops. 2. GB closed: The controller checks whether Voltage direct closing is okay (no voltage on the main TB closed on main busbar, no voltage on the emergency busbar,...
Page 331: Tie Breaker Trip Flowchart
TB open signal TB closed TB opened Voltage on Blackout main busbar response TB sync. Engine Info message GB closed enabled running Info message Open TB Open TB TB opened TB opened Alarm Close GB TB opened 1. TB closed: After getting the emergency busbar tie breaker open signal, the controller checks whether the tie breaker is open. •...
Page 332: Emergency Genset Test Functions
• Trip tie breaker The controller does not require the tie breaker open conditions to be met for a breaker trip. Similarly, the tie breaker is not de-loaded for a trip. Table 9.5 Tie breaker trip flowchart Tie breaker trip Open TB 1.
Page 333: Engine Test
Parameter Range Default Comment Test delay > Test 10 s to 1 h 30 s The time the test runs from the moment the generator is started. time Test base load > 10.0 to 100.0 % of 50 % The load the genset will ramp up to during the parallel test. Base load nominal power Engine test: Starts, runs and stops the emegergency genset.
Page 334: Parallel Test
Test activated Emergency Engine start load sequence Start sequence Alarm 1. The controller starts the emergency genset when the TEST function is activated. Test timer 2. The test timer starts when the emergency genset has started. starts 3. The emergency genset runs at its nominal frequency (without synchronising or closing the genset breaker) until the test timer runs out.
Page 335: Load Take-Over Test
Test activated Test timer expired Emergency load Engine start sequence Open generator breaker Start Alarm sequence GB opened Alarm 1. The controller starts the emergency genset when the TEST function is activated. Close generator 2. The controller synchronises and breaker closes the genset breaker.
Page 336: Emergency Genset Configurations
Test activated Test timer Emergency expired Engine start load sequence Close tie breaker Start sequence Alarm 1. The controller starts the emergency Tie breaker Alarm genset when the TEST function is closed Close generator activated. breaker 2. The controller synchronises and closes the genset breaker.
Page 337: Emergency Genset As Part Of The System
9.7.3 Stand-alone emergency genset For some applications, the emergency genset must be a stand-alone genset. For a stand-alone genset, the EMERGENCY genset controller is not connected to the DEIF network. Single-line diagram For a stand-alone emergency genset, the emergency genset must be the only component shown in the EMERGENCY genset controller single-line diagram.
Page 338 Figure 9.3 Example of a stand-alone emergency genset application DEIF network DEIF network BUS TIE SHAFT EMERGENCY GENSET GENSET breaker generator genset controller controller controller controller controller Emergency load Emergency genset Genset Genset Shaft generator Figure 9.4 Stand-alone emergency genset...
Page 339: Main Busbar Is Ok
INFO A stand-alone EMERGENCY genset controller does NOT regard itself as the last power source. In AUTO mode, the controller can therefore open the generator breaker and stop the engine when there is power on the main busbar. SEMI mode You can connect stand-alone emergency genset to the main busbar in SEMI mode if Tie breaker sync.
Page 340 The EMERGENCY genset controller does NOT start the blackout response if: • The EMERGENCY genset controller is under switchboard control. • Harbour operation is active. • The EDG not ready for blackout alarm is active. • The Extended stop timer is running. •...
Page 341 Blackout response flowchart 1. Blackout delay timer: If the main busbar fails, and the blackout Main busbar response is possible, then the Blackout delay timer starts. failure 2. TEST running: The controller checks whether a Test is running. If a test is running the controller stops the test and changes to Blackout delay AUTO mode.
Page 342: Harbour Operation
You must get class approval for the ship to use harbour operation. Harbour operation is only available for the EMERGENCY genset controller, and only when it is connected to the DEIF network. Harbour operation allows the emergency genset to supply the main busbar with power for an extended period. This is typically used while the ship is docked in harbour, since the emergency genset is typically much smaller than the other gensets, and can therefore run more efficiently at lower loads.
Page 343 While harbour operation is activated, either by a digital input or a signal from CustomLogic, the operation overrides the EDG max. parallel time. During harbour operation the emergency genset is treated as an ordinary genset with the first priority and all normal GENSET controller protections.
Page 344 Harbour operation The harbour operation activation sequence is described below. 1. Harbour operation activated: The Harbour operation digital input is activated. Harbour • If the parameter Operator confirms harbour operation is Enabled, then the operation activated controller requires confirmation to start harbour operation. 2.
Page 345: Parallel Timers
1. Harbour operation deactivated: After the Harbour operation digital input is Harbour deactivated (or the Reject harbour operation digital input is activated), then the operation controller checks whether the connected gensets can take the load. deactivated • If the connected gensets cannot take the entire load, the next available genset is started.
Page 346: Temperature-Dependent Start/Stop
9.8.6 Temperature-dependent start/stop More information See GENSET controller, Other GENSET controller functions, Temperature-dependent start/stop for a description of this function. 9.8.7 Engine states as digital outputs You can configure a digital output with a function for an engine state. The controller activates the digital output if the engine state is present.
Page 347: Emergency Genset Controller Protections
Trip 9.9 EMERGENCY genset controller protections 9.9.1 EMERGENCY genset controller alarms INFO These alarms are in addition to the AC protections and other alarms for PPM 300 controllers. INFO During a blackout, the suppressed alarms are shown as Warnings. Alarms...
Page 348: Alarm Actions
Alarms Voltage or frequency not OK Generator AVR regulation error Maximum parallel time EDG max. parallel time P load sharing failure Load sharing Q load sharing failure GOV output selection failure GOV output setup failure GOV relay setup incomplete Regulator configuration AVR output selection failure AVR output setup failure AVR relay setup incomplete...
Page 349: Breaker Alarms
Table 9.10 EMERGENCY genset controller inhibits Inhibit Disables the alarm when ... Engine running Running detection is ON. Engine not running Running detection is OFF. Generator breaker closed The Generator breaker > Feedback > Closed digital input is activated. Generator breaker open The Generator breaker >...
Page 350: Ac Alarms
EMERGENCY genset alarm Configure > Parameters > General name TB de-load failure Breakers > Tie breaker monitoring > De-load failure Breaker de-load failure Vector mismatch Breakers > Tie breaker monitoring > Vector mismatch Vector mismatch TB opening failure Breakers > Tie breaker monitoring > Opening failure Breaker opening failure TB closing failure Breakers >...
Page 351: Non-Essential Loads
Table 9.13 Busbar AC alarm names for the EMERGENCY genset controller EMERGENCY genset alarm Configure > Parameters > General name Busbar over-voltage 1 or 2 Busbar > Voltage protections > Over-voltage 1 or 2 Busbar over-voltage Busbar under-voltage 1 or 2 Busbar >...
Page 352: Emergency-Main Busbar Maximum Parallel Time
9.9.8 Emergency-main busbar maximum parallel time Emergency This alarm is for the maximum time that the emergency genset may run in parallel to the main busbar. load The timer starts when the emergency genset is synchronised with the main busbar. The alarm action is Trip tie breaker and the alarm is latched.
Page 353: Shaft Generator Controller Overview
GENSET controllers to ensure effective power management. 10.1.2 Applications There is no restriction on the number of SHAFT generator controllers. Figure 10.1 Example of a SHAFT generator controller application with optional heavy consumers and non-essential loads DEIF network Display SHAFT generator...
Page 354: Shaft Generator Controller Principles
Functions ◦ Genset(s) drive the ship's shaft ◦ Another shaft generator drives the ship's shaft • Power requirement to drive the ship's shaft treated as a load • Propeller zero pitch digital input • Shaft generator fixed speed digital input •...
Page 355: Nominal Settings
10.2.2 Nominal settings Generator nominal settings These nominal settings are under Configure > Parameters > Generator > Nominal settings > Nominal settings #, where # is 1 to 4. Table 10.1 Controller nominal settings Nominal setting Range Default Notes Voltage (V) 10 V to 160 kV 400 V The phase-to-phase nominal voltage for the shaft generator.
Page 356: Ac Configuration
More information See GENSET controller, Genset controller principles, Running detection for more information. 10.2.5 AC configuration More information The AC configuration and nominal settings chapter describes the AC configuration in general. The following table shows how the general AC configuration description applies to the SHAFT generator controller. Table 10.3 AC configuration for the SHAFT generator controller SHAFT generator...
Page 357 Table 10.4 Shaft generator breaker (SGB) close flowchart 1. SGB close command: The shaft generator breaker SGB close (SGB) close command can come from the following: command • The operator can press the push-button Close breaker on the display unit. •...
Page 358: Shaft Generator Breaker Open Flowchart
Connected shaft generator or shore connection Activating the Close breaker command if a shaft generator is already connected to the busbar and Power take home is not activated will start a load transfer from the connected shaft generator to gensets under PMS control. After the load is transferred, the controller will follow the procedure described in the table above to close the shaft generator breaker.
Page 359: Shaft Generator Breaker Blackout Close Flowchart
Table 10.5 Shaft generator breaker (SGB) open flowchart 1. SGB open command: The shaft generator breaker (SGB) SGB open open command can come from the following: command • The operator can press the push-button Open breaker on the display unit. Open •...
Page 360: Shaft Generator Breaker Trip Flowchart
Table 10.6 Shaft generator breaker (SGB) blackout close flowchart 1. SGB blackout close: The shaft generator breaker (SGB) blackout close SGB blackout command comes from the blackout close sequence. close 2. Blackout present: The controller checks that the blackout close conditions are present: •...
Page 361: Other Shaft Generator Controller Functions
Table 10.7 Shaft generator breaker trip flowchart 1. Open SGB: When a trip is required, the controller activates the Breakers > Shaft Shaft generator generator breaker > Control > SGB open output to open the breaker. breaker trip 2. SGB opened: The controller checks whether the breaker has opened: •...
Page 362 Parameter Range Default Notes Not enabled: The SGB may open at any load. Open point enabled Not enabled, Enabled Not enabled Enabled: The SGB will not open if the load on the breaker is more than Open when power below. 2 to 100 % of nominal Open when power below power...
Page 363 Figure 10.2 Power from diesel gensets used for PTH Busbar Genset 1 Genset 2 Genset 3 Shaft generator If two shaft generators are present, the power from one shaft generator can be used for PTH by the other SHAFT generator controller, as shown in the following drawing.
Page 364 Table 10.8 Shaft generator breaker close sequence for starting PTH The following conditions must be met to successfully start SGB close PTH: signal 1. Power take home input: The Power take home input must be activated and the shaft generator breaker must be open.
Page 365: Shaft Generator Base Load
Table 10.9 Shaft generator breaker open sequence for PTH 1. Open point enabled: The controller checks the Open point enabled SGB open parameter: signal • Enabled: Is the PTH power less than Open when power below? ◦ Yes: The controller continues the sequence. ◦...
Page 366: Shaft Generator Load Transfer Without Parallel
• SG-DG max. parallel time (in the SHAFT generator controller) • DG-SG max. parallel time (in the GENSET controllers) More information See Power management, Load sharing, SHAFT generator base load for more information. 10.4.3 Shaft generator load transfer without parallel If two power sources cannot be synchronised, then you cannot transfer the load directly from the one to the other without interrupting the supply.
Page 367: Temperature-Dependent Power Derating
Parameter Range Default Notes 90 to 100 % of the nominal The function starts the first priority genset if the shaft generator Low frequency limit 91 % frequency frequency is below this set point for the Delay time. 100 to 110 % of the nominal The function starts the first priority genset if the shaft generator High frequency limit 109 %...
Page 368: Engine States As Digital Outputs
Table 10.10 Hardware required in addition to the minimum standard controller wiring Function Type Details If this digital input function is configured, then this digital input Breakers > Shaft generator breaker > Digital input Continuous must be activated in order to close the shaft generator breaker. Command >...
Page 369 How it works When Regulation ON is activated, the SHAFT generator controller can receive regulation set points from other controllers on the DEIF network. The SHAFT generator controller can send regulation signals to adjust the frequency and/or voltage of the shaft generator.
Page 370: Counters
SG1 is running and is connected to the busbar. To transfer the load from SG1 to SG2: 1. If it is not already running, start SG2. 2. Activate Regulation ON on SG1. 3. Select the External set point (Network) regulation mode on SG1. 4.
Page 371: Trip Avr
Trip 10.5 SHAFT generator controller protections 10.5.1 SHAFT generator controller alarms INFO These alarms are in addition to the AC protections and other alarms for PPM 300 controllers. Alarms Overspeed (2 alarms on the speed measurement) Under-speed (2 alarms) Primary running feedback failure...
Page 372: Alarm Actions
Alarms SG-DG maximum parallel time Maximum parallel time SG-SG maximum parallel time Heavy consumer feedback timeout (1 alarm for each heavy consumer) Power management Heavy consumer reservation not possible (1 alarm for each heavy consumer) • GOV regulation error • GOV regulation mode not selected •...
Page 373: Breaker Alarms
Inhibit Disables the alarm when ... Shaft breaker closed The Breakers > Shaft generator breaker > Feedback > SGB closed digital input is activated. Shaft breaker open The Breakers > Shaft generator breaker > Feedback > SGB open digital input is activated. Generator voltage present The shaft generator voltage is above 10 % of the nominal voltage.
Page 374: Ac Alarms
10.5.5 AC alarms More information The AC configuration and nominal settings chapter describes AC alarms in general. The following tables show where to configure these alarms for the SHAFT generator controller. Table 10.18 Generator AC alarm names for the SHAFT generator controller SHAFT generator alarm Configure >...
Page 375: Sg-Dg Max. Parallel Time
10.5.6 SG-DG max. parallel time This alarm limits the time that a shaft generator may run in parallel to a genset. The timer starts when the genset or emergency genset is connected to the same busbar as the shaft generator. Controller type: SHAFT generator controller only.
Page 376: Overspeed
10.5.8 Overspeed Value These two alarms are for overspeed protection. Delay point The alarm response is based on the shaft generator speed, as measured by the MPU/W/NPN/PNP input. time Configure these parameters under Configure > Parameters > Engine > Protections > Overspeed #, where # is 1 or 2. Table 10.21 Default parameters Parameter...
Page 377: Shore Connection Controller Overview
11.1.2 Applications There is no restriction on the number of SHORE connection controllers. Figure 11.1 Example of a SHORE connection controller application with optional heavy consumers and non-essential loads DEIF network SHORE Display connection...
Page 378: Shore Connection Controller Principles
Functions ◦ Power export (active and reactive) (to the shore connection) ◦ Power import (active and reactive) (to the ship busbar) • Power management system (PMS) control ◦ Display unit push-buttons for breaker operations ◦ Synchronisation, de-loading, and breaker control Control types ◦...
Page 379: Power Management
More information See AC configuration and nominal settings, Nominal settings, Nominal power calculations for more information. Ship busbar nominal settings These settings are under Configure > Parameters > Busbar > Nominal settings > Nominal settings #, where # is 1 to 4. Table 11.2 Controller nominal settings Nominal setting Range...
Page 380: Shore Connection Breaker
Table 11.4 Breaker commands (optional) Function Type Details This input starts the breaker de-load and opening procedure. Breakers > Shore This input can also be used to confirm the selection, when Operator select is connection breaker > Digital Pulse selected under Breaker action. Command >...
Page 381: Shore Connection Breaker Close Flowchart
More information See the Breakers, synchronisation and de-loading chapter for more information on synchronisation and breakers. This includes the inputs and output functions and the parameters to configure. For the SHORE connection controller, the breaker abbreviation ([*B]) is SCB. [Breaker] refers to Shore connection breaker. 11.3.2 Shore connection breaker close flowchart The following flowchart shows the sequence that the controller normally uses to close the shore connection breaker.
Page 382 Table 11.6 Shore connection breaker (SCB) close flowchart 1. SCB close command: The shore connection breaker (SCB) close command can come from the following: • The operator can press the push-button Close breaker on the display unit. • The operator can use PICUS to send a close breaker SCB close command.
Page 383: Shore Connection Breaker Open Flowchart
If the GENSET controllers are in SEMI mode, after the shore connection is connected, the GENSET controllers will not disconnect the gensets. However, the parallel timer starts when the shore controller is connected. For the default configuration, the GENSET controller trips the genset breaker when the timer expires. Connected shore connection or shaft generator Activating the Close breaker command if a shore connection is already connected to the busbar and Multiple shore connections allowed is not activated will start a load transfer from the connected shore connection to gensets under PMS control.
Page 384 Table 11.7 Shore connection breaker (SCB) open flowchart SCB action SCB open SCB action open command command open without de-loading command Breaker action Open Open without de-loading Operator select Operator selection Open Open without de-loading Cancel Open Open Info message Info message conditions conditions...
Page 385: Shore Connection Breaker Blackout Close Flowchart
• The command SCB action open without de-loading is activated by digital input or from an external source. The PMS opens the SCB without de-loading. • The command can come from an external source. 2. Open conditions OK: The power management system (PMS) checks that the open conditions are present: •...
Page 386: Shore Connection Breaker Trip Flowchart
Table 11.8 Shore connection breaker (SCB) blackout close flowchart 1. SCB blackout close: The shore connection breaker (SCB) blackout close SCB blackout command comes from the blackout close sequence. close 2. Blackout present: The controller checks that the blackout close conditions are present: •...
Page 387: Other Shore Connection Controller Functions
Table 11.9 Shore connection breaker trip flowchart 1. Open SCB: When a trip is required, the controller activates the Breakers > Shore Shore connection connection breaker > Control > SCB open output to open the breaker. breaker trip 2. SCB opened: The controller checks whether the breaker has opened: •...
Page 388 On the receiving ship, the connection acts like a shore connection (and does not use the ship-to-ship function). This shore connection can be manually controlled, controlled by a PPM 300, or controlled by any other controller. The SHORE connection controller on the supplying ship uses the AC measurements to detect the conditions on the receiving ship.
Page 389 Flowchart for the shore connection breaker close for ship-to-ship 1. SCB close command: The shore connection breaker (SCB) close command can come from the following: SCB close • The operator can press the push-button Close breaker command on the display unit. •...
Page 390: Shore Connection Base Load
11.4.2 Shore connection base load The SHORE connection controller lets the ship use power from a land-based source, while topping up the power requirement by running one or more generators in parallel. Enable this function under Parameters > Local power management > Shore connection base load.
Page 391 Parameter Range Default Notes SHORE connection controllers to connect all the required shore connections. One close command connects all SCs: When there is a close command for an SCB, the PMS closes ALL the SCBs in the section, starting with the SHORE connection controller that was given the close command.
Page 392: Sensitive Shore Connection (Overlap)
Blackout close You can enable blackout auto close (Configure > Parameters > Local power management > Blackout > Blackout close) for multiple SHORE connection controllers. The response to a blackout then follows the Multiple shore connections allowed parameter. Table 11.11 Effect of parameter on blackout close Selected parameter Effect...
Page 393: Shore Connection Load Transfer Without Parallel
How it works In the description below, the connecting equipment can either be a genset that connects to a busbar powered by one or more shore connections, or a shore connection that connects to a busbar powered by one or more gensets. The connecting equipment controller controls Breaker 1, while the connected equipment controller controls Breaker 2.
Page 394: Counters
However, the power management system includes a pre-programmed sequence to automatically transfer load. It does this by using gensets in AUTO mode to supply the load during the transition (if they can supply the load). The sequence starts when the operator presses Close on the non-connected SHAFT generator or SHORE connection controller display unit.
Page 395: Shore Connection Controller Protections
With the example setup the controller sends a 1 second pulse to the external counter for each 100 kWh the controller logs. 11.5 SHORE connection controller protections 11.5.1 SHORE connection controller alarms INFO These alarms are in addition to the AC protections and general alarms for PPM 300 controllers. Alarms SC-DG maximum parallel time Maximum parallel time...
Page 396: Alarm Actions
Alarms • Up to 3 non-essential loads per controller • Can connect each controller to the same 3 non-essential load breakers NEL # over-current (1 alarm for each non-essential load) Non-essential load (NEL) NEL # under-frequency (1 alarm for each non-essential load) NEL # overload 1 and 2 (2 alarms for each non-essential load) NEL # reactive overload (1 alarm for each non-essential load) 11.5.2 Alarm actions...
Page 397: Ac Alarms
The following table shows where to configure these alarms for the SHORE connection controller, as well as which general alarm corresponds to each SHORE connection controller alarm. Table 11.19 Breaker alarm names for the SHORE connection controller SHORE connection alarm Configure >...
Page 398: Sc-Dg Max. Parallel Time
SHORE connection alarm Configure > Parameters > General name Shore connection > Power protections > Reverse power 1 or Reverse power 1 or 2 Reverse power Shore connection > Reactive power protections > Reactive Reactive power export 1 or 2 Reactive power export power export 1 or 2 Shore connection >...
Page 399: Sc-Sc Max. Parallel Time
This alarm sets the maximum time that a shore connection may be connected in parallel to a shaft generator. The power management system normally prevents a shore connection and a shaft generator from connecting in the same section. This alarm is a safety feature, since it is possible to for an operator to manually connect a shore connection and a shaft generator.
Page 400: Bus Tie Breaker Controller Overview
12.1.2 Applications There is no restriction on the number of BUS TIE breaker controllers. There can be a ring busbar connection. Figure 12.1 Example of a BUS TIE breaker controller application DEIF network BUS TIE SHAFT GENSET GENSET...
Page 401: Bus Tie Breaker Controller Principles
Functions • Bus tie breaker close sequence (with synchronisation), to connect the busbar sections • Busbar split and connection (configurable) • Busbar section management ◦ For example, independent busbars for dynamic positioning (DP) vessels ◦ A busbar section can be under switchboard control without affecting other busbar sections Busbar section •...
Page 402: Nominal Settings
Each BUS TIE breaker controller and each externally controlled breaker creates a new busbar section. More information See Power management, Power management principles, Busbar sections for more information about busbar sections. 12.2.2 Nominal settings The controller nominal settings are used in a number of key functions. For example, many protection settings are based on a percentage of the nominal settings.
Page 403: Ac Configuration
Table 12.3 Controller nominal settings Nominal setting Range Default Notes The phase-to-phase nominal voltage for busbar B. If there is no transformer between Voltage (V) 10 V to 160 kV 400 V busbar A and busbar B, the nominal voltage for busbar B is the same as the nominal voltage for busbar A.
Page 404: Connecting Busbar Sections
• There are enough gensets available under PMS control to supply the required power to each busbar section. ◦ If the required GENSET controllers are in SEMI mode, then their gensets must be connected. ◦ GENSET controllers in AUTO mode need not be connected. The power management system can start and connect them as necessary.
Page 405 • The operator can press the push-button Close breaker on the BUS TIE breaker controller display unit. • The operator can use PICUS to send an close breaker command. • A digital input with the Breakers > Bus tie breaker > Command > BTB close function. •...
Page 406: Bus Tie Breaker Blackout Close
Parameters Configure this parameter under Configure > Parameters > Local power management > Bus tie breaker > Supply mode after BTB close. Parameter Range Default Comment • Stay on DG supply: After the bus tie breaker is closed, the power management system automatically de-loads any shaft generator or shore connection supply.
Page 407: Bus Tie Breaker Trip Flowchart
Manual blackout close During a blackout, the operator can manually close the bus tie breaker by pushing the push button Close breaker on the display unit. 12.3.4 Bus tie breaker trip flowchart The controller automatically trips the bus tie breaker (BTB) for this alarm action: •...
Page 408 Table 12.9 Active energy export counter parameters Parameter Range Default Comment Pulse every 1 kWh to 10 MWh 10 kWh The value when a digital output sends a pulse. The length of the pulse that is sent. This value should be long enough so the pulse Pulse length 0.1 s to 1 h can be registered by the external counter.
Page 409: Bus Tie Breaker Controller Protections
12.5 BUS TIE breaker controller protections 12.5.1 BUS TIE breaker controller alarms INFO These alarms are in addition to the AC protections and general alarms for PPM 300 controllers. Alarms Heavy consumer feedback timeout (1 alarm for each heavy consumer)
Page 410: Breaker Alarms
Table 12.16 BUS TIE breaker controller inhibits Inhibit Disables the alarm when ... Bus tie breaker closed The Breakers > Bus tie breaker > Feedback > BTB Closed digital input is activated. Bus tie breaker open The Breakers > Bus tie breaker > Feedback > BTB Open digital input is activated. Controller under SWBD The Mode >...
Page 411 Table 12.18 Busbar A AC alarm names for the BUS TIE breaker controller BUS TIE breaker alarm Configure > Parameters > General name Busbar A over-voltage 1 or 2 Busbar A > Voltage protections > Over-voltage 1 or 2 Over-voltage Busbar A under-voltage 1 or 2 Busbar A >...
Page 412: Overview
13. Hardware characteristics and configuration 13.1 Overview 13.1.1 Introduction This chapter provides details on the hardware characteristics for each hardware module, and for each set of terminals. General characteristics Some terminal types are common to a number of different hardware modules. To minimise repetition, the general terminal types are described under General characteristics.
Page 413: Power Supply Characteristics
Reverse polarity The power supply is protected against reverse polarity. That is, if the power supply terminals are switched, the DEIF equipment will not be damaged. However, the DEIF equipment will not be able to operate until the power supply has been connected correctly.
Page 414: Relay Output Characteristics And Configuration
Figure 13.1 Example of a voltage decrease over a diode Supply 2 24 V DC Supply 1 24 V DC ∆V = 0.7 V 23.3 V 0 V DC 0 V DC Heat emission For the heat emission from the equipment, use the maximum power consumption for the power supply (or power supplies). 13.2.3 Relay output characteristics and configuration Symbol Hardware modules...
Page 415 To see certain digital output functions, you must include the corresponding equipment in the single-line diagram. Relay state The relay state (whether it is open or closed) depends on the relay hardware, the coil state and the function (or alarm) state. The following table shows how these combine to give the relay state.
Page 416 Table 13.2 Relay, normally de-energised coil Function 1. Function: The digital output function assigned to the terminals. The controller software activates the function. For example: Breakers > [Breaker] > Command Coil > [*B] Close. 2. Coil: The controller energises the relay coil when the function is activated. 3.
Page 417: Digital Input Characteristics And Configuration
Table 13.4 Changeover relay, normally de-energised coil Function Coil 1. Function: The digital output function assigned to the terminals. The controller software activates the function. For example: Breakers > [Breaker] > Command > [*B] Close. 2. Coil: The controller energises the relay coil when the function is activated. NO circuit 3.
Page 418: Analogue Input Characteristics And Configuration
Polarity The digital input is a bi-directional input. The wiring to the input and common terminals may be changed around without affecting its operation. Each group of digital inputs (that is, each group of digital inputs that share a common terminal) must share the same reference polarity (high or low).
Page 419 INFO If you choose a Pt100 pre-configured curve, for the sensor output you must select Pt100 ohm. Similarly, if you choose a Pt1000 pre-configured curve, for the sensor output you must select Pt1000 ohm. Sensor failure You can configure customised alarms for sensor failure. The Below range alarm is activated when the analogue input is below the specified value.
Page 420 Supervised Emergency stop example The designer creates the following wiring for an Emergency stop digital input: Emergency 300 Ω stop 100 Ω When the Emergency stop is closed, the circuit has a resistance of around 75 Ω (the combined resistance of the 100 Ω and 300 Ω...
Page 421: Analogue Output Characteristics And Configuration
Analogue input alarms You must complete the Sensor setup before configuring any analogue input alarms. You can configure any number of alarms for an analogue input. However, you cannot exceed the maximum number of customised alarms for the controller. 13.2.6 Analogue output characteristics and configuration Symbol Hardware modules GAM3.1 (PWM)
Page 422 Output for a switchboard instrument Output Generator power example The customer has a 1 MW genset, and wants to display the power from the genset on the switchboard. He uses a DEIF DQ-96x with a scale from -100 to 1500 kW.
Page 423: Power Supply Module Psm3.1
Relay output 1 × Status OK (fixed), and 2 × configurable ‐ Internal communication DEIF internal communication connections (to connect to (RJ45) extension unit) (The LEDs are on the front of the hardware module. The connections are at the bottom of the hardware module.) Table 13.7...
Page 424: Psm3.1 Terminal Overview
Other connections: Terminals: Standard 45° plug, 2.5 mm Wiring: 0.5 to 2.5 mm (22 to 12 AWG), multi-stranded Communication DEIF internal communication: RJ45. Use an Ethernet cable that meets or exceeds the SF/UTP connections CAT5e specifications. Module faceplate screws: 0.5 N·m (4.4 lb-in) Torques and terminals Connection of wiring to terminals: 0.5 N·m (4.4 lb-in)
Page 425: Frame Ground Characteristics
INFO Internal communication connections must only be used for internal communication. 13.3.3 Frame ground characteristics More information See Hardware characteristics and configuration, General characteristics, Frame ground characteristics. 13.3.4 Power supply characteristics More information See Hardware characteristics and configuration, General characteristics, Power supply characteristics. 13.3.5 PSM3.1 1 supply voltage low alarm Value Delay...
Page 426: Power Supply Voltage As An Analogue Output
PSM3.1 and PSM3.2). This is type of communication is referred to as Internal communication. For communication redundancy, the extension units can be connected in a ring. If there is a disruption or failure, the DEIF proprietary ring protocol changes the communication path within 100 milliseconds.
Page 427: Power Supply Module Psm3.2
When a new extension rack is connected, the controller always activates a Fieldbus conflict alarm. The extension rack hardware configuration must be confirmed in PICUS. Topology examples More information See Wiring the communication, DEIF internal communication, Topology examples in the Installation instructions for more information. 13.4 Power supply module PSM3.2 13.4.1 Power supply module PSM3.2 The power supply module provides power to all the hardware modules in the extension unit and communicates with the main controller through the internal communication ports.
Page 428: Psm3.2 Terminal Overview
Other connections: Terminals: Standard 45° plug, 2.5 mm Wiring: 0.5 to 2.5 mm (22 to 12 AWG), multi-stranded Communication DEIF internal communication: RJ45. Use an Ethernet cable that meets or exceeds the SF/UTP connections CAT5e specifications. Module faceplate screws: 0.5 N·m (4.4 lb-in) Torques and terminals Connection of wiring to terminals: 0.5 N·m (4.4 lb-in)
Page 429: Frame Ground Characteristics
Terminal Symbol Name Type Normally open Common Normally open Relay output (30 V DC and 1 A) Common Normally open Common Table 13.14 PSM3.2 Internal communication connections Connection Symbol Name Type Internal communication input connection to connect to the main Bottom of rack, front Internal communication input controller.
Page 430: Psm3.2 1 Supply Voltage High Alarm
13.4.6 PSM3.2 1 supply voltage high alarm Value This default alarm is for power supply voltage protection. Delay point The alarm is based on the power supply voltage measured by the PSM. The alarm is activated when the power supply voltage exceeds the set point for the delay time. time Configure the parameters under Configure >...
Page 431: Alternating Current Module Acm3.1
For communication redundancy, the extension units can be connected in a ring. If there is a disruption or failure, the DEIF proprietary ring protocol changes the communication path within 100 milliseconds. The order that the extension units are wired, determines in which order they appear in the software. The controller the extension units are connected to is always the first unit in the order.
Page 432 Table 13.18 ACM3.1 terminals Module Count Symbol Type Name 2 × (L1, L2, L3 and N) L1/L2/L3/N Voltage 3-phase voltage measurements ACM3.1 1 × (L1, L2, L3 and 4th) Current 3-phase current measurement 4th current measurement Table 13.19 ACM3.1 technical specifications Category Specification Nominal value: 100 to 690 V AC phase-to-phase...
Page 433: Acm3.1 Terminal Overview
Category Specification Example: The accuracy for Power (P) at 70 °C (158 °F) is 0.5 % + 4 x 0.2 % = 1.3 %. Module faceplate screws: 0.5 N·m (4.4 lb-in) Secure the current measurement terminal block to the module faceplate: 0.25 N·m (2.2 lb-in) Torques and terminals Connection of wiring to terminals: 0.5 N·m (4.4 lb-in) UL/cUL Listed: Wiring must be minimum 90 °C (194 °F) copper conductors only.
Page 434: Voltage Measurement Characteristics
CAUTION * Only wire the neutral terminal if it is available on both the [Busbar] and [Source]. If neutral is only wired on one side of the equipment it causes a difference in the reference of a star connection. The difference causes an error during synchronisation.
Page 435 Table 13.20 ACM3.2 terminals Module Count Symbol Type Name 1 × (L1, L2 and L3) Current 3-phase current measurement - Consumer side ACM3.2 1 × (L1, L2 and L3) Current 3-phase current measurement - Neutral side Table 13.21 ACM3.2 technical specifications Category Specification Current:...
Page 436: Acm3.2 Terminal Overview
Category Specification Accuracy: Frequency measurement • Within operating range; > 0.1 A: ±0.1 % of actual frequency Current measurement accuracy temperature coefficient: Temperature ±0.25 %, or ±2.5 mA per 10 °C (18 °F) outside reference range (whichever is greater) Module faceplate screws: 0.5 N·m (4.4 lb-in) Secure the current measurement terminal block to the module faceplate: 0.25 N·m (2.2 lb-in) Torques and terminals Connection of wiring to terminals:...
Page 437: Current Measurement Characteristics
CAUTION To prevent the current measurements from being swapped around, DEIF recommends that the current measurement terminals are fitted with encoding pins. Check that the wiring to the terminals has not been swapped around during installation if encoding pins are used.
Page 438: Iom3.1 Terminal Overview
Category Specification ON: -36 to -8 V DC, and 8 to 36 V DC OFF: -2 to 2 V DC Minimum pulse length: 50 ms Impedance: 4.7 kΩ Voltage withstand: ±36 V DC Relay outputs: Terminals: Standard 45° plug, 2.5 mm Wiring: 0.5 to 2.5 mm (22 to 12 AWG), multi-stranded Terminal connections...
Page 439: Changeover Relay Output Characteristics
Terminal Symbol Name Type Bi-directional input Bi-directional input Bi-directional input Bi-directional input Bi-directional input Digital input (OFF: 0 to 2 V DC, ON: 8 to 36 V DC, Impedance: 4.7 kΩ) Bi-directional input Bi-directional input Bi-directional input Bi-directional input Bi-directional input Common Common for digital input terminals 13 to 22 13.7.3 Changeover relay output characteristics...
Page 440 Table 13.24 IOM3.4 terminals Module Count Symbol Type Name Transistor output Configurable IOM3.4 Digital input Configurable Table 13.25 IOM3.4 technical specifications Category Specification Transistor type: PNP Supply voltage: 12 or 24 V DC nominal, maximum 36 V DC (relative to common) Maximum current (per output): <...
Page 441: Iom3.4 Terminal Overview
Category Specification Galvanic isolation Between groups: 600 V, 50 Hz for 60 s Unmounted: No protection rating Protection Mounted in rack: IP20 according to IEC/EN 60529 Size L 28 mm × H 162 mm × D 150 mm (1.1 in × 6.4 in × 5.9 in) Weight 175 g (0.4 lb) 13.8.2 IOM3.4 terminal overview...
Page 442: Transistor Output Characteristics And Configuration
Terminal Symbol Name Type Bi-directional input Bi-directional input Bi-directional input Bi-directional input Digital input (OFF: 0 to 2 V DC, ON: 8 to 36 V DC, Impedance: 4.7 kΩ) Bi-directional input Bi-directional input Bi-directional input Bi-directional input Common Common for digital input terminals 24 to 31 13.8.3 Transistor output characteristics and configuration Symbol Hardware modules...
Page 443: Digital Input Characteristics
Configured state You can configure the normal transistor state in software in the display unit or PICUS. Under Configure > Input/output, select the terminals, then select Normally de-energised (the default) or Normally energised for the Coil state. Table 13.27 Transistor, configured in software as normally de-energised Normally de-energised 1.
Page 444 Table 13.29 EIM3.1 terminals Module Count Symbol Type Name Ground Frame ground EIM3.1 12 or 24 V DC Power supply Relay output Configurable Relay output (with wire break detection) Configurable Digital input Configurable MPU input (with wire break detection)* Magnetic pickup Generator tacho output or NPN/PNP W input (no wire break detection)* sensor...
Page 445 Category Specification Voltage withstand: ±36 V DC Voltage: 3 to 70 V AC peak Frequency: 2 to 20,000 Hz Magnetic pickup Accuracy: 2 to 99 Hz: 0.5 Hz; 100 to 20,000 Hz: ±0.5 % of measurement Cable supervision: Resistance maximum 100 kΩ Includes wire break detection Voltage withstand: 70 V AC Voltage: 8 to 36 V DC...
Page 446: Eim3.1 Terminal Overview
Category Specification Between analogue inputs and other I/Os: 600 V, 50 Hz for 60 s Unmounted: No protection rating Ingress protection Mounted in rack: IP20 according to IEC/EN 60529 Size L 28 mm × H 162 mm × D 150 mm (1.1 in × 6.4 in × 5.9 in) Weight 250 g (0.5 lb) 13.9.2 EIM3.1 terminal overview...
Page 447: Power Supply Characteristics
13.9.4 Power supply characteristics If the EIM power supply fails or is not connected, the PSM will supply power to the EIM. If the PSM power supply fails, the EIM will run on its independent power supply. However, the EIM will not supply power to the PSM. INFO Class societies require an independent power supply for the EIM.
Page 448: Auxiliary Power Supply Voltage As An Analogue Output
Parameter Range EIM3.1 1 supply voltage high Enable Not enabled, Enabled Enabled Alarm action Warning 13.9.7 Auxiliary power supply voltage as an analogue output You can configure an analogue output with a function for the auxiliary power supply voltage. The controller then adjusts the analogue output to reflect the operating value.
Page 449: W Input Characteristics
MPU. Notes on an MPU input The MPU input terminal connections on the DEIF equipment can be changed around without any problem. If an MPU is used, a wire break can be detected and activate an alarm.
Page 450: Magnetic Pickup Wire Break
13.9.11 Magnetic pickup wire break [RPM] This alarm is for magnetic pickup wire break. If the engine is running but there is no pulse for 2 seconds, then the controller monitors the cable. If there is no change during the alarm delay time, then the controller activates the alarm. 10 s time Configure the parameters under Configure >...
Page 451: Relay Output Characteristics
INFO Note that there is no software compensation for the wire length to the resistance input. Create a custom curve for the analogue input to adjust for errors due to wire length. INFO If you use a resistance input as a supervised binary input, then the maximum circuit resistance is 330 Ω. 13.9.13 Relay output characteristics EIM3.1 has three ordinary relay outputs (terminals 3,4, terminals 5,6;...
Page 452: Governor And Avr Module Gam3.1
13.10 Governor and AVR module GAM3.1 13.10.1 Governor and AVR module GAM3.1 This governor and AVR module has four relay outputs, two analogue outputs and a pulse width modulation output, and two analogue inputs. These I/Os are configurable. GAM3.1 also has terminals for analogue load sharing (future use). Table 13.36 GAM3.1 terminals Module...
Page 453 Category Specification Voltage output (DC) -10 to 10 V, 0 to 10 V, 0 to 5 V, -5 to 5 V, 0 to 3 V, -3 to 3 V, or 0 to 1 V, or any custom range between -10 and 10 V Accuracy: 1 % of the selected range (minimum range: 1 V) 16-bit resolution over the range -10 to 10 V...
Page 454: Gam3.1 Terminal Overview
13.10.2 GAM3.1 terminal overview Terminal Symbol Name Type Normally open Common Normally open Common Relay output (250 V AC and 8 A, or 30 V DC and 5 A) Normally open Common Normally open Common Active (P) load Load sharing for future use to perform analogue load sharing. (Voltage output: -5 to 5 V DC, Common Impedance: 23.5 kΩ) Reactive (Q)
Page 455: Analogue Input (Ai) Characteristics
The PWM output (0 to 100 %) is configured as a curve, in the same way as the other analogue outputs. More information See Hardware characteristics and configuration, General characteristics, Analogue output characteristics and configuration. Duty cycles The PWM uses duty cycles for its output. The PWM frequency determines the cycle length. One cycle is therefore 1/500 Hz = 0.002 seconds long, ±10 %.
Page 456: Relay Output Characteristics
If you need two analogue inputs in series, you can use an analogue input on another hardware module in series with an analogue input on GAM3.1 (since the hardware modules are galvanically isolated from each other). Current input The current input may be either active or passive, and a combination of active and passive inputs may be used. More information See the Installation instructions for more information about the current input wiring.
Page 457 Table 13.39 GAM3.2 terminals Module Count Symbol Type Name Ground Frame ground GAM3.2 12 or 24 V Power supply Analogue current or voltage output GOV/AVR/configurable Pulse width modulation (PWM) output PWM output Digital input Configurable Relay output GAM3.2 status Relay output Configurable Table 13.40 GAM3.2 technical specifications...
Page 458 Category Specification 16-bit resolution Minimum load: 600 Ω. Voltage output internal resistance: < 1 Ω. Voltage withstand: ±36 V DC Controller power off: Internal resistance > 10 MΩ Frequency: 500 Hz ±50 Hz Resolution: 43,200 levels Voltage: Low level: < 0.5 V. High level: > 5.5 V. Maximum: 6.85 V. Pulse width Output impedance: 100 Ω...
Page 459: Gam3.2 Terminal Overview
Category Specification Between relay groups and other I/Os: 2210 V, 50 Hz for 60 s Unmounted: No protection rating Ingress protection Mounted in rack: IP20 according to IEC/EN 60529 Size L 28 mm × H 162 mm × D 150 mm (1.1 in × 6.4 in × 5.9 in) Weight 246 g (0.5 lb) 13.11.2 GAM3.2 terminal overview...
Page 460: Power Supply Characteristics
13.11.4 Power supply characteristics More information See Hardware characteristics and configuration, General characteristics, Power supply characteristics. 13.11.5 GAM3.2 1 supply voltage low or missing Value Delay This default alarm is for auxiliary power supply voltage protection. point The alarm is based on the power supply voltage measured by the GAM. The alarm is activated when the power supply voltage is less than the set point for the delay time.
Page 461: Pulse Width Modulation (Pwm) Output Characteristics
Using a configured or selected output curve, the controller converts the regulation output or operating data to the corresponding current (-25 to 25 mA) or voltage (-10 to 10 V). More information See Hardware characteristics and configuration, General characteristics, Analogue output characteristics and configuration.
Page 462: Digital Input Characteristics
Table 13.43 Relationship between duty cycles and the PWM output Duty cycle Graph Voltage Cycle 6.85 100 % 0.002 0.004 time [s] Voltage Cycle 6.85 50 % 0.002 0.004 time [s] Voltage Cycle 6.85 12.5 % 0.002 0.004 0.006 time [s] 13.11.9 Digital input characteristics More information See Hardware characteristics and configuration, General characteristics, Digital input characteristics and...
Page 463: Processor And Communication Module Pcm3.1
PCM3.1 terminals Module Count Symbol Type Name Network and DEIF network (The LEDs are on the front of the hardware module. Two of the PCM3.1 Ethernet (RJ45) connections are at the top of the hardware module, one on the front, and two at the bottom.)
Page 464: Pcm3.1 Terminal Overview
Category Specification DEIF network: RJ45. Use an Ethernet cable that meets or exceeds the SF/UTP CAT5e specifications. 100BASE-TX. Module faceplate screws: 0.5 N·m (4.4 lb-in) Torques and terminals Connection of wiring to terminals: 0.5 N·m (4.4 lb-in) UL/cUL Listed: Wiring must be minimum 90 °C (194 °F) copper conductors only.
Page 465: Pcm3.1 Clock Battery
Impact of temperature on lifetime The expected minimum lifetime for the controller is 10 years, for constant operation at ambient temperatures up to 40 °C. This lifetime is halved for each additional 10 °C rise in ambient temperature. 13.12.4 PCM3.1 clock battery PCM3.1 includes an internal battery for timekeeping during a power supply failure.
Page 466 Table 13.47 DU 300 terminals Count Symbol Type Name Ground Frame ground 12 or 24 V DC Power supply Relay output For future use Relay output Display status OK Ethernet (RJ45) DEIF network DESIGNER'S HANDBOOK 4189340911K UK Page 466 of 521...
Page 467 Figure 13.6 Display unit with dimensions in mm (followed by approximate dimensions in inches), first-angle projection 238.0 (9.4) 52.4 (2.1) 233.4 (9.2) 43.3 (1.7) 8.0 (0.3) 218.2 (8.6) Table 13.48 DU 300 technical specifications Category Specification From the front: IP65 according to IEC/EN 60529 Ingress protection From the back: IP20 according to IEC/EN 60529 UL/cUL Listed...
Page 468 Other connections: Terminals: Standard plug, 2.5 mm Wiring: 0.5 to 2.5 mm (22 to 12 AWG), multi-stranded Communication DEIF network: RJ45. Use an Ethernet cable that meets or exceeds the SF/UTP CAT5e connections specifications. 100BASE-TX. Display unit fixing screw clamps: 0.15 N·m (1.3 lb-in) Torques and terminals Connection of wiring to terminals: 0.5 N·m (4.4 lb-in)
Page 469: Display Unit Terminal Overview
13.13.2 Display unit terminal overview Figure 13.7 Back of display unit DU 300, with the terminal positions Table 13.49 Display unit electrical terminals Terminal Symbol Type Name Ground Frame ground 12 or 24 V DC (nominal) Power supply (+) 0 V DC Power supply (-) Relay output (30 V DC and 1 A) Future use...
Page 470: Frame Ground Characteristics
Ethernet for additional display units CAUTION The display unit must be paired to a controller in the DEIF network. During commissioning, or the first time a display unit is powered, the display unit prompts for a controller confirmation. More information See the Commissioning guidelines for more information regarding the first pair selection.
Page 471: Communication Information
Power management communication, including load-dependent start/stop, and de-loading • Load sharing communication • Power management inputs and outputs may be connected to any controller • Authentication (non-DEIF equipment cannot disrupt communication) Functions • Connects the controller(s) to: ◦ Controller display unit ◦...
Page 472: Restrictions
PSM3.1 and PSM3.2). This is type of communication is referred to as Internal communication. For communication redundancy, the extension units can be connected in a ring. If there is a disruption or failure, the DEIF proprietary ring protocol changes the communication path within 100 milliseconds.
Page 473: Fieldbus Conflict
PICUS. Topology examples More information See Wiring the communication, DEIF internal communication, Topology examples in the Installation instructions for more information. 13.15.2 Fieldbus conflict This alarm is for the internal communication between the controller and its extension units. If there is a hardware change or hardware failure, this alarm communicates that the hardware configuration does not match the previous hardware configuration.
Page 474: Overview
14. PICUS 14.1 Overview 14.1.1 Using PICUS PICUS is PC software that provides an interface to the controllers. More information See the PICUS manual for a full description of how to use PICUS. 14.1.2 Configuration update delayed The controller activates this alarm if an operator and/or external equipment is changing the controller configuration too quickly. For example, a programming error on a PLC can create a storm of Modbus changes.
Page 475: Overview
15. CustomLogic 15.1 Overview 15.1.1 Using CustomLogic CustomLogic is used in PICUS to create and configure customised logical operations for use in the system. These functions are built using ladder logic elements and can include interaction with external equipment, or more advanced logic interfaces. More information See CustomLogic in the PICUS manual for more information about CustomLogic and logic project examples.
Page 476: Activating Controller Outputs
Table 15.3 Stored flags Parameter Range Default Comment Not enabled: CustomLogic reads the value of the parameter as Not enabled, Signal #, where # is 1 to 20 Not enabled Enabled Enabled: CustomLogic reads the value of the parameter as 1. 15.1.4 Activating controller outputs CustomLogic cannot directly activate controller outputs that are configured for controller functions.
Page 477: Overview
16. Emulation 16.1 Overview 16.1.1 Using emulation With emulation you can run your controller(s) in a virtual operation mode. During emulation you can simulate various real-world actions, such as starting or stopping of the genset without actually having the genset connected. You can also test and configure your controller, and mimic inputs or outputs that are configured.
Page 478: Modbus In The Controller
Modbus in general and the Modbus TCP/IP protocol, refer to the documentation freely available at http:// www.modbus.org. Refer to the Modbus tables, available for download at www.deif.com, to see how the controller data is mapped to the Modbus addresses. INFO All values in this chapter are decimal values, unless specifically stated that a value is hexadecimal.
Page 479: Controller Identifier
Each controller can process up to 10 communication requests at a single time. 17.2.3 Controller identifier The Modbus TCP protocol will always use the controller IPv4 address to identify the controller that the master wants to communicate with. However, some Modbus communication tools will still require/automatically add a Modbus Slave ID, also known as a unit identifier, for the unit that the server is communicating with.
Page 480: Modbus Tables
Alarm parameter: Enable 17.3 Modbus tables 17.3.1 Download Modbus tables To download the Modbus tables, follow these steps: 1. Visit the DEIF website at: www.deif.com. 2. Use the search option to open the search box: • 3. Enter the product name.
Page 481: Specific Modbus Function Groups
17.4 Specific Modbus function groups 17.4.1 CustomLogic: Modbus signal You can find the function group CustomLogic: Modbus signal in the Discrete output coil (01; 05; 15) and the Discrete input contact (02) sheets of the Modbus table. The function group allows you to interact with the CustomLogic of the controller using Modbus. When you read a value from these addresses, the controller will return a value to show if the flag for the signal is active (true, 1) or not active (false, 0).
Page 482 Example of how breaker priority works Figure 17.1 Breaker priority example system Busbar A Busbar B Emergency load SHORE Genset 1 Genset 2 connection Genset 3 In the example diagram, it is assumed that the single line diagram in the controller was built by placing the components in the diagram in the following order: 1.
Page 483 If a component is removed from the single line diagram, the Modbus address becomes free and can be reassigned. The breaker priorities are automatically reassigned for all the remaining components in the single line diagram. For example if we remove Genset 1 and the emergency genset from the example above the table will look as follows: Table 17.4 Updated breaker priority values and Modbus addresses after removing components...
Page 484: Setting Up Modbus
The device interfacing with the controller must be connected to one of the following: ◦ An Ethernet connection on the controller communication module (that is, PCM3.1). ◦ Another controller in the DEIF network. • The controller must have a unique IPv4 address which is active. •...
Page 485: Date And Time
When a new controller is added to the network, it fetches the time from the time master in the network. If two Ethernet networks with DEIF controllers are joined, then the time from the network with the controller that has been powered on for the longest is used.
Page 486: Setting The Time Manually
Setting Range Default Notes Daylight savings is not applied to the controller when you select the Etc/UTC time zone. INFO If a setting is changed on any controller in the network, the new setting is synchronised to all controllers in the network. Table 18.2 Network time protocol settings Setting Range...
Page 487: Permissions
The permissions structure allows the creation and maintenance of users and groups within each controller configuration. These are stored locally on each controller, and therefore each controller can store its own set of user permissions and groups. Figure 18.1 User profiles on controllers DEIF network Controller Controller...
Page 488 Figure 18.2 Broadcast user profiles to all controllers DEIF network Controller Controller Controller Broadcast User 1 User 1 User 1 permissions User 2 User 2 User 2 INFO Create the same permissions on all the connected controllers. If a controller must have different permission settings, do not broadcast these settings.
Page 489: Group Settings
INFO In order to benefit fully from the permissions structure, you need to set up your users and groups with careful consideration. CAUTION You can only access the user permissions option if you are a member of a group that has access to that function. 18.2.2 Group settings For Groups, the permissions consists of three parts: •...
Page 490: User Settings
Software area Tasks • Alarm shelved • Translations • Report • Backup • Restore • Communication Tools • Regulator status • Advanced ◦ Firmware ◦ Change controller ◦ Permissions • Date and time • Single-line creator • Emulation Configure • Input/output configuration •...
Page 491: Default Users
18.2.4 Default users CAUTION Ensure that all default passwords are changed to reduce any security risk to the operation. Additionally, it is recommended to adjust or edit the group and user permissions according to your own operational needs. Default users The controller is supplied with a number of default users, groups, and passwords.
Page 492 Permission Read Read write No access Mixed access Date and time ● Single-line creator ● Emulation ● Input/output ● configuration Parameters ● Counters ● CustomLogic ● Table 18.9 Service engineers group Permission Read Read write No access Mixed access Live data ●...
Page 493 Permission Read Read write No access Mixed access Counters ● CustomLogic ● Table 18.10 Designers group Permission Read Read write No access Mixed access Live data ● Live data ● Supervision ● Single-line supervision ● Alarms ● Alarm acknowledge ● Alarm reset latch ●...
Page 494 Table 18.11 Administrators group Permission Read Read write No access Mixed access Live data ● Live data ● Supervision ● Single-line supervision ● Alarms ● Alarm acknowledge ● Alarm reset latch ● Alarm out of service ● Alarm shelved ● Logs ●...
Page 495: Overview
Permission Read Read write No access Mixed access Supervision ● Single-line supervision ● Alarms ● Alarm acknowledge ● Alarm reset latch ● Alarm out of service ● Alarm shelved ● Logs ● ● Tools ● Translations ● Report ● Backup ●...
Page 496: Miscellaneous
18.4 Miscellaneous 18.4.1 Lamp test The lamp test lights all the LEDs on the display unit. The test cycles through the LED colours for the time configured in the lamp test parameters. During the lamp test a message box is shown on the display unit. Inputs The table below describes optional inputs for the lamp test.
Page 497: Alive
Parameter Range Default Comment Alternatively, you can start the lamp test from the display unit (Tools > Advanced > Lamp test) or a digital input (see above). Duration 1 s to 1 h 18 s The time for the lamp test. The time that each colour is lit.
Page 498: Restrictions
CAUTION Changing the controller type MUST only be carried out if it is safe for commissioning and meets the prerequisites stated in the restrictions. CAUTION Changing the controller type resets the default I/O configuration. The I/O configuration must checked and reconfigured as necessary after changing the controller type.
Page 499 Figure 18.4 Example Change controller type screen More information See Tools, Controller type in the Operator's manual for more information on how to change the type of controller. DESIGNER'S HANDBOOK 4189340911K UK Page 499 of 521...
Page 500: Terms And Abbreviations
Third party equipment used to monitor the controller system's alarms, for example, by system using Modbus TCP/IP communication. Alternating current Alternating current A replaceable PCB with voltage and current measurement inputs. Used in the DEIF ACM3.1 module 3.1 controller. American National...
Page 501 A generator is connected to the system if it is running, synchronised with the busbar, Connected and its breaker is closed. DEIF equipment that measures system conditions and then uses outputs to make the Controller system respond appropriately. A transformer for a current measurement, so that the current at the controller is within Current transformer the controller's specifications.
Page 502 Term Abbreviation Explanation Engine interface A replaceable PCB, with its own power supply. This module includes 4 relay outputs, 4 EIM3.1 module 3.1 digital inputs, an MPU and W input, and 3 analogue inputs. Standards issued by the European Committee for Standardisation (also known as European Norm Comité...
Page 503 PSM3.1 is a hardware module that supplies power to the rest of the rack. Multi-line 300 ML 300 A DEIF product platform. PPM 300 is part of ML 300. All controllers perform all the power management calculations, based on shared Multi-master system information.
Page 504 Power factor The 3-phase power factor. Power in Control Utility PICUS The DEIF utility software, used to design, configure, troubleshoot and monitor a system. Software Power management The controllers share information and work together to ensure enough power to supply system the load.
Page 505 Term Abbreviation Explanation Pulse width Terminals with an output that uses variable pulse widths, and behaves as an analogue modulation output. A type of transistor. An aluminium box with a rack system that houses the hardware modules. Each Rack controller consists of a rack and a number of hardware modules. Rapid spanning tree RSTP A protocol used to compute the topology of a local area network.
Page 506: Units
The gensets, the other power sources, all breakers, the busbars, and all their System controllers. Within the system, the DEIF controllers work together to supply the power required safely and efficiently. Equipment other than the DEIF controller. For example: The genset, the genset engine Third-party equipment control system, the wiring, the busbars, and the switchboard.
Page 507: Symbols
Table 19.1 Units used in the documentation Unit Name Measures US unit US name Conversion Alternative units ampere Current 1 bar = 0.980665 atmosphere (atm) pounds per square Pressure 1 bar = 14.5 psi inch 1 bar = 100,000 Pascal (Pa) T[ºC] = (T[ºF] - 32 º) ×...
Page 508: Controller And Component Symbols
CAUTION This highlights potentially dangerous situations. If the guidelines are not followed, these situations could result in personal injury or damaged equipment. General notes INFO This highlights general information. More information This highlights where to find more information. Example heading This highlights examples.
Page 509 Table 19.2 Electrical symbols Symbol Symbol name 3-phase breaker Capacitor Contactor Contactor with RC snubber Connector dot Current transformer (S1 and · show "current in"; S2 shows "current out") Diode Fuse Ω Ohmmeter Relay Relay with freewheeling diode Resistor (IEC-60617) Single-line diagram closed breaker Single-line diagram open breaker Temporary connection dot (for example, connection to a meter)
Page 510 Symbol Symbol name Genset Heavy consumer Laptop Non-essential load Part of a module faceplate, to show examples of terminal wiring Rack R7 Server or desktop PC Shaft generator Shore connection SHORE connection DESIGNER'S HANDBOOK 4189340911K UK Page 510 of 521...
Page 511: Flowchart Symbols
19.3.5 Flowchart symbols Symbol Symbol name Decision Process Start or end 19.3.6 Module faceplate symbols Table 19.4 Terminals Symbol Symbol name Frame ground Power supply L1, L2, L3 and N Three-phase voltage measurements Current transformer Common Digital input Relay output (normally open) Relay with wire break detection (normally open) Relay output (changeover relay, with normally open and normally closed terminals) Analogue current or voltage input...
Page 512 LEDs Symbol Symbol name CAN-A CAN bus A (PCM) CAN-B CAN bus B (PCM) Network and DEIF network (PCM) Internal communication in (PSM) Internal communication out (PSM) Internal communication status (PSM) Power supply status (PSM) System status (PCM) Table 19.6...
Page 513: Overview
20. Appendix: Pre-configured curves 20.1 Overview 20.1.1 Introduction This section contains the data for the analogue input and output curves that are pre-configured in the controller. The display unit and PICUS only show the curves for the selected analogue input or output type. INFO The controller's analogue input cannot necessarily measure the curve's whole range.
Page 514: Datcon 7
20.3.2 Datcon 7 Table 20.4 Datcon 7 analogue input curve (resistance to pressure) Sensor value (Ω) Function input [bar] 1530 2400 2500 20.3.3 Datcon 10 Table 20.5 Datcon 10 analogue input curve (resistance to pressure) Sensor value (Ω) Function input [bar] 1530 2400 2500...
Page 515: Vdo Pressure Cu
20.3.6 VDO pressure CU Table 20.8 VDO pressure CU analogue input curve (resistance to pressure) Sensor value (Ω) Function input [bar] 1190 1520 1800 20.4 Analogue input temperature curves 20.4.1 Datcon low Table 20.9 Datcon low analogue input curve (resistance to temperature) Sensor value (Ω) Function input [°C] 1130...
Page 516: Pt100
20.4.3 Pt100 Table 20.11 Pt100 analogue input curve (resistance to temperature) Sensor value (Ω) Function input [°C] 80.307 84.271 88.222 92.160 96.086 100.000 103.903 107.794 111.673 115.541 119.398 123.243 127.076 130.898 134.709 138.508 142.295 146.071 149.835 153.588 157.330 161.060 164.778 168.485 172.180 175.864...
Page 517: Pt1000
Sensor value (Ω) Function input [°C] 264.220 281.028 297.548 313.780 329.725 345.382 360.751 375.832 390.626 405.132 419.350 433.280 1000 20.4.4 Pt1000 Table 20.12 Pt1000 analogue input curve (resistance to temperature) Sensor value (Ω) Function input [°C] 803.068 842.710 882.218 921.600 960.859 1000.000 1039.025...
Page 518: Vdo 40-120
Sensor value (Ω) Function input [°C] 1684.848 1721.801 1758.640 1795.363 1831.972 1868.465 1904.843 1941.106 1977.254 2013.287 2049.205 2120.695 2297.406 2471.240 20.4.5 VDO 40-120 Table 20.13 VDO 40-120 analogue input curve (resistance to temperature) Sensor value (Ω) Function input [°C] 1350 1950 2500 44.2...
Page 519: Vdo Temperature Cu
Sensor value (Ω) Function input [°C] 1500 2260 2500 57.6 20.4.7 VDO temperature CU Table 20.15 VDO temperature CU analogue input curve (resistance to temperature) Sensor value (Ω) Function input [°C] 1350 1950 2500 44.2 20.5 Analogue output (-100 to 100 %) curves 20.5.1 (-100 to 100 %) to (-25 to 25 mA) Table 20.16 Percentage to current analogue output curve...
Page 520: To 100 %) To (-10 To 10 V)
20.5.4 (-100 to 100 %) to (-10 to 10 V) Table 20.19 Percentage to voltage analogue output curve Function input [%] Output (V) -100 20.5.5 (-100 to 100 %) to (0 to 10 V) Table 20.20 Percentage to voltage analogue output curve Function input [%] Output (V) -100...
Page 521 20.6.4 (0 to 100 %) to (-10 to 10 V) Table 20.25 Percentage to voltage analogue output curve Function input [%] Output (V) 20.6.5 (0 to 100 %) to (0 to 10 V) Table 20.26 Percentage to voltage analogue output curve Function input [%] Output (V) 20.6.6 (0 to 100 %) to (0 to 100 %)

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