TURBOTRONIC 4CONTROL SYSTEM

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Introduction

Solar's Turbotronic 4 control system is used forsequencing, control, and protection of the gasturbine package, and for providing an extensiverange of options for monitoring and plant control.

The control system is based on a commer-cially available programmable controller config-ured to Solar's requirements. It provides an opti-mum combination of control and display features,reliability and maintainability, and is configuredspecifically for the control of turbomachinery andassociated equipment.

The control system described herein is pro-vided for Power Generation products and in-cludes a number of sensors, transducers, andmonitoring devices. Data are collected and sent

to the programmable controller for computationand generation of the required control actionsand indications.

The programmable controller, in conjunctionwith the video display unit (VDU), permits a widerange of features. These include a variety of ad-vanced software and control options, as well ascondition and trend monitoring and supervisorycontrol.

The control system provides the operatorwith necessary information for operation of theequipment. It also offers a variety of communica-tions options for data exchange with the cus-tomer's supervisory system.

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ContentsIntroduction................................................................................................................................................... i

Standard Hardware.................................................................................................................................... 1

GENERAL INFORMATION ....................................................................................................................... 1ONSKID CONTROL CONSOLE................................................................................................................ 1PROGRAMMABLE CONTROLLER .......................................................................................................... 2INPUT/OUTPUT MODULES ..................................................................................................................... 3INTERNAL COMMUNICATION................................................................................................................. 4POWER SUPPLY SYSTEM...................................................................................................................... 4BACKUP SYSTEM .................................................................................................................................... 4VIBRATION MONITORING SYSTEM....................................................................................................... 5GOVERNOR.............................................................................................................................................. 5GENERATOR CONTROL AND PROTECTION........................................................................................6VOLTAGE REGULATION ......................................................................................................................... 7CONTROL AND PROTECTION................................................................................................................ 7OPERATOR INTERFACE......................................................................................................................... 9

Optional Control and Display Features................................................................................................. 15ENGINEERING UNITS............................................................................................................................15FIRE DETECTION AND SUPPRESSION SYSTEM...............................................................................15FIELD PROGRAMMING .........................................................................................................................15LANGUAGE.............................................................................................................................................15COMMUNICATIONS – TURBINE CONTROL TO SUPERVISORY SYSTEM .......................................15VIDEO DISPLAY OPTIONS....................................................................................................................18

Appendix A: Hardware ........................................................................................................................... 20PHYSICAL HARDWARE.........................................................................................................................20ELECTRICAL SPECIFICATION..............................................................................................................20ENVIRONMENTAL SPECIFICATION.....................................................................................................20RFI/EMI SUSCEPTIBILITY AND EMISSION..........................................................................................20

Appendix B: Technical Supplement ..................................................................................................... 21HARDWARE INFORMATION .................................................................................................................21HARDWARE CERTIFICATION...............................................................................................................22AREA CLASSIFICATION ........................................................................................................................22QUALITY ASSURANCE..........................................................................................................................22CONTROL CONSOLE LAYOUT.............................................................................................................22

Appendix C: Control System Information ............................................................................................ 24

TURBOTRONIC DEFINITIONS ..............................................................................................................24HUMAN MACHINE INTERFACE DESCRIPTIONS ................................................................................24SYSTEM DESCRIPTIONS......................................................................................................................24

Caterpillar is a registered trademark of Caterpillar Inc.Solar, Centaur, Titan and Turbotronic are trademarks of Solar Turbines Incorporated.Specifications subject to change without notice. Printed in U.S.A.©2002 Solar Turbines Incorporated. All rights reserved.SPTT-PG/802

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Standard HardwareGENERAL INFORMATIONThe Turbotronic 4 control system is a highly inte-grated programmable controller-based controlsystem with a video display unit (VDU) and op-erator interface panel (Figure 1).

The control system consists of several dis-tinct modules: a programmable controller, in-put/output (I/O) modules (discrete and analog),VDU, relay backup system, control and monitor-ing software, onskid control console, and thepackage sensing and control elements. The in-ternal computing capability of the control systemmay vary by product line, but each control systemhas the same basic internal components, as de-picted in Figure 2.

The control system requires a source of 24-Vdc nominal power, which is derived from asource of 120-Vdc power supplied by a batterybank with associated battery charger.

ONSKID CONTROL CONSOLEThe control system is provided in two onskid,NEMA 4 boxes. The control system is designedto operate in a nonhazardous area. The turbinecontrol panel and onskid VDU include all neces-sary switches and indicators for gas turbine op-eration. Figure 1. Typical Control Console

Figure 2. Typical Package Control System

DISPLAY

COMBINATIONGENERATOR

CONTROL MODULE

OPERATOR'SINTERFACE PROGRAMMABLE

CONTROLLER

FLEX I/OMODULES

BACKUPRELAY

SHUTDOWN

GENERATORTURBINE

CONTROLNETLINK

CONTROLNETLINK

CONTROLNET BRIDGEREDUNDANT MODULE

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All components within the control console arefactory interconnected and wired to the sensorsand transmitters. Labels are in English, but canbe provided in various other languages (see "Op-tional Control and Display Features").

PROGRAMMABLE CONTROLLERThe heart of the control system is the program-mable controller. The programmable controllerperforms the following functions in conjunctionwith the input and output signal modules:

� Sequencing of gas turbine and auxiliaries

� Control of turbine and driven equipmentduring start-up, loading, operation andshutdown

� Protection of turbine from abnormaloperating conditions

� Protection of driven equipment fromabnormal operating conditions

� Response to commands from operator

� Analog and status outputs for displayand monitoring

The programmable controller is programmedin a language called “relay ladder logic” or in“function block diagram” programming.

Ladder logic format (Figure 3) is quite fa-miliar to most operators and engineering person-nel, since it closely emulates the relay logic usedin the past. It also includes a variety of computa-tional and file transfer commands useful for datamanipulation, calculation, and communication.Using an optional programming terminal, the usercan monitor the program online and troubleshoota problem or make modifications when required(see “Programmable Controller Field Program-ming” option). In addition to viewing the ladderlogic online, a copy of the ladder files may beprinted out.

Function block diagram programming(Figure 4) allows control algorithms to be pro-grammed in a graphical format familiar to processcontrol engineers. This format can program acomplex algorithm on one page that would takemultiple pages of ladder logic to implement. Thecompact program is easier to read, troubleshoot,and understand.

Figure 3. Ladder Logic Diagram

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Figure 4. Function Block Diagram Programming

INPUT/OUTPUT MODULESIn order to perform many of its functions, the pro-grammable controller must gather physical data.This is accomplished through I/O modules thatare provided as discrete (input, output, or both) oranalog (input, output, or both). Discrete inputs aretypically used for alarms, shutdowns, or statusindications and analog inputs are used for scale-able functions.

The I/O modules are mounted to terminalbase units (Figure 5). Terminal base units havetwo primary functions. First, when they are con-nected side to side, the bases serve as a back-plane, allowing data to be transferred from the I/Omodule to the programmable controller via Con-trolNet 1.5. Second, the terminal base acts as theterminal strip to which the field devices are wired.Data are transferred to and from the I/O modulevia an adapter module. The adapter serves as acommunication hub between each of the at-tached I/O modules and the programmable con-troller, providing not only I/O data, but also indi-vidual module status and health. In addition, theadapter also serves to power the internal logic foras many as eight I/O modules.

Figure 5. Typical I/O Module Mountedon a Terminal Base Unit

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Discrete Input Modules. Discrete input modulesreceive signals from on/off devices, such as levelswitches, pressure switches, push buttons, re-lays, and protective equipment normally usedduring sequencing of the gas turbine. Discretesignals can be used for alarms, shutdowns orsimply indicators, but are not necessarily dis-played. The discrete input modules can have acapacity of up to 16 channels depending onmodule type.

Discrete Output Modules. Discrete output mod-ules are used to drive output devices such assolenoid valves, relays or motor contactors. Thediscrete output module is capable of having either8 or 16 channels of output data per module.

If “dry” contacts are required, then a set ofinterposing relays or a two-amp contact relayoutput module may be provided at additionalcost.

Analog Input Modules. Analog input modulesaccept analog signals and digitize the data fortransfer to the programmable controller. Modulescan accept either four or eight single-ended in-puts, with different channels being used for dif-ferent types of input. Each channel is individuallyconfigured for current or voltage by choosingwhere the input is connected on the terminalbase.

Temperature Modules. Temperature modulesserve to condition and transfer temperature datafrom package resistance temperature detectors(RTD), 100-ohm platinum preferred, and thermo-couples to the programmable controller. Thetemperature module has eight input channels.

Speed Modules. Speed modules perform high-speed frequency algorithms. The frequency in-puts can accept frequencies up to 32,767 Hz.The speed module has two input channels, eachof which may accept magnetic pickup signalsfrom 500 mV to 28 Vac peak. Analog Output Modules. Analog output mod-ules are used to send an analog signal, eitherrepeating one of those supplied by the purchaseror used in the basic control or display of the con-trol system. The analog output module is a four-channel output module.

INTERNAL COMMUNICATIONCommunication between the programmable con-troller and I/O modules is via ControlNet 1.5 (Fig-ure 2). ControlNet 1.5 is a high speed, determi-nistic, serial communications link. This can be

used with both non-Flex I/O and Flex I/O and canhandle communications over distances of up to1000 m (3300 ft), or more if repeaters are used,at a bus speed of 5.0 megabits per second. Thisis more than 50 times faster than the widely usedData Highway Plus (DH+) and the Remote I/Osystems.

The physical layer of ControlNet 1.5 is quadshielded RG-6U coaxial cable, with a passive tapused to make a connection.

The most significant features of ControlNet1.5 are its speed and the fact that it is both de-terministic and repeatable. Deterministic is theability to reliably predict when data will be deliv-ered, and repeatability ensures that transmittimes are constant and unaffected by devicesconnecting to, or leaving, the network. The net-work update time for a typical turbomachinerycontrol system is around five milliseconds.

POWER SUPPLY SYSTEMThe power supply system supplies power to theprogrammable controller, input/output modules,video display unit, and relay backup systems. Itconsists of independent, voltage converting, dc-to-dc isolating power supplies. The system re-ceives 120-Vdc input from the battery system andconverts it into a regulated and filtered 28-Vdcpower at a maximum of 20 amps.

BACKUP SYSTEMThe basic control system is equipped with an in-dependent relay backup system that serves toinitiate emergency shutdown of the turbomachin-ery and to control the post-lube cycle. Criticalinput signals monitored by the backup systeminclude the backup power turbine overspeedmonitor, manual emergency stop switches (lo-cated at the console and turbine skid), the pro-grammable controller fail “watchdog” timer, andthe fire system relay contacts. When activated byany of the above faults, the relay backup systeminitiates a safe shutdown of the turbine and drivenequipment. The backup control system is a com-bination of instantaneous and time delay relays.

When a failure of the programmable control-ler occurs, all discrete outputs are automaticallyswitched off. The programmable controller failrelay is re-energized on a fault condition. A faultis initiated either by the internal programmablecontroller “watchdog“ or by failure of the outputmodule. The programmable controller fail relaycontacts are used in the relay backup system toinitiate an emergency shutdown, to isolate thedriven equipment by transferring block valves orcircuit breakers to their safe position, and to se-quence operation of the post-lube oil system.

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Once a shutdown is initiated by the backupsystem, operation can only be restored manuallyby a safety key switch lockout located on theconsole front panel when all faults have beencleared. This action re-energizes the master con-trol relay and its associated relays and timers arerestored to their normal position.

VIBRATION MONITORING SYSTEMThe vibration monitoring system provides vibra-tion indication and protection for the gas turbine,gearbox, and driven equipment. Depending onthe unacceptable vibration level, either a warningis indicated or a turbine shutdown is initiated.

The gas turbine vibration monitoring instru-mentation consists of a single proximity probe perbearing or two velocity transducers per engine forthe Centaur 40 gas turbine. The gearbox is typi-cally instrumented with an accelerometer. Thegenerator is typically instrumented with a velocitytransducer per bearing. The proximity probes,accelerometers, and velocity transducers areconnected to individual transmitters that provide4-to-20 mA signals to be read by the turbinepackage control system.

All data available to the programmable con-troller are also obtainable via serial link for userremote monitoring, diagnostics and trending. Di-rect access to the raw vibration signals is avail-able via BNC connectors.

GOVERNORThe "governor system" consists of various hard-ware and systems integrated together to providethe governor function. The governor is a speed,load and temperature control system whosedominant signal depends on the mode of opera-tion of the turbine generator set: for example,starting, stopping, operating in island mode, op-erating in parallel with other units, or operating inparallel with a utility source.

The system consists of the turbine speedtransducer (magnetic pickup), the speed monitor,turbine T5 temperature thermocouples, tempera-ture input module, electronic fuel valve, and theprogrammable controller software files.

The governor system maintains generatorfrequency and/or generator load distribution(when operating in parallel) by controlling turbinefuel flow. Output current to the fuel actuator pro-vides the mechanical interface to the electronicfuel valve. The system includes provisions forselection of isochronous or speed droop modes

of operation. The transfer from droop to isochro-nous and isochronous to droop is bumpless.Speed set-point adjustment is by means of speedincrease and speed decrease momentary pushbuttons on the turbine control console.

A solid-state combination generator controlmodule (CGCM) provides load sharing betweenmultiple units and is specifically designed to in-terface with the programmable controller to pro-vide an integrated power generation control solu-tion. Each generator's load is continuously meas-ured by the respective CGCM and compared toother units on the same bus via interconnect cir-cuits, facilitating equal real and reactive loadsharing between the units.

Turbine engine temperature (T5) is also aninput to the governor control. When turbine tem-perature exceeds rated levels, fuel flow is thencontrolled based on temperature rather thanspeed or load inputs. In the case of a generatorparalleled with an infinite bus (utility), the tem-perature control limits the load-carrying contribu-tion of the unit to its rated full-load capacity forthe current ambient temperature conditions.

When the generator is not paralleled with theutility, the temperature control is set to a highertemperature to allow momentary operation in ex-cess of rated load during on-load transients.

T5 Temperature Limiter. Limits the real load(kW) on a unit operating in parallel with a largepower source, such as an electric utility or otherinfinite bus system at the maximum unit rating forany ambient temperature condition. The systemlimits the kW load by limiting T5 temperature to apredetermined factory-set level. When the pre-determined temperature level is reached, the lim-iter takes control of the throttle and prevents anyfurther increase in temperature and, thus, load.The unit continues to operate at this full site-ratedload for the current ambient temperature. Withchanges in ambient temperature (engine air inlettemperature T1), the limiter adjusts the load tomaintain a constant T5 temperature, thus, auto-matically maintaining the unit at full site-ratedload at all times.

If the application periodically requires opera-tion at a specific constant load level, rather thanfull site-rated capacity, then the optional kW con-troller should be used.

The T5 temperature limited system is a part ofthe turbine temperature control and indicationsystem and its set point can be viewed from theVDU.

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GENERATOR CONTROL AND PROTECTIONGeneral. Combining several generator controlcomponents into one powerful package, thecombination generator control module (CGCM)provides more flexibility and accessibility to spe-cific generator control options. The CGCM (Fig-ure 6) combines load share, synchronization,voltage control, reactive power control, and gen-erator protection functions into one module. TheCGCM communicates with the programmablecontroller via high speed ControlNet 1.5 (Figure7). The module performs synchronization in com-bination with the programmable controller soft-ware program and voltage regulation via the con-trol of the exciter field current. The modulesenses the three-phase voltage and the three-phase current via PTs and CTs. The module pro-vides real load-sharing and reactive load sharing.Reactive load sharing can be reactive droop orreactive differential (cross-current compensation).

Auto Synchronizing. The control system in-cludes an auto synchronizer for the closure of theunit circuit breaker. Upon sending an initiate syn-chronization discrete signal, the auto synchro-nizer brings the generator into frequency, volt-

Figure 6. Combination Generator ControlModule (CGCM)

Figure 7. Typical Generator, Exciter, and Regulator System

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age, and phase compliance and sends a signal toclose the unit circuit breaker. The error signal forthe voltage and phase comes from the CGCM.The communication is via ControlNet 1.5.

KW Control (Optional). Controls the real kilowattload on a generator operating in parallel with aninfinite bus or other large source. Three types ofkW load control are available:

1. KW Import Control – The kW importcontrol system controls the real load (kW)on a unit operating in parallel with a largesource such as a utility. The import controlmonitors the load that is being importedfrom the utility source and adjusts the tur-bine generator output to maintain a pre-set amount of minimum load. The importcontrol allows the import of unlimitedpower while maintaining the minimumpower. This control is for applicationswhere it is desired to prevent any powerfrom being exported to the utility.

2. KW Control – The kW control systemcontrols the real load (kW) on a unit oper-ating in parallel with a large source. Thecontrol monitors the load carried by theturbine generator set and adjusts turbinefuel flow to maintain a constant load underconditions of varying infinite bus fre-quency. The turbine T5 limiter system pro-vides protection against excessive kWload while in parallel with an infinitesource. The kW control system providesadditional operational flexibility by allowingunit kW load level to be set at any desiredconstant level within the capacity of theunit. In this mode, the unit may be carryingthe entire load within the plant, while theremaining unit capacity is being exportedto the utility. In addition, the kW control setpoint can be the manipulated variable inthe process control loop. For example, tomodulate steam production in a cogen-eration application, the steam productioncontrol could modulate the kW control setpoint.

3. KW Export Control – The kW exportcontrol limits the amount of power that isbeing exported to the utility or largesource. The amount of power that is beingexported is limited to a preselected value.If the selected value exceeds the turbinecapacity, then the T5 limiting control pro-tects the turbine against excessive kWload.

VOLTAGE REGULATIONSteady-State StabilitySteady-state voltage regulation is defined asconstant frequency and load. When the generatoris operating steady state at any load, the gen-erator voltage varies no more than �0.1%.

No Load to Full-Load AccuracyAt constant frequency and at rate power factor,the voltage regulation varies no more than�0.25%.

Automatic Voltage Regulator (AVR)The voltage adjustment range about the selectednominal value is �10%. The resolution of thevoltage is 0.1%. Voltage metering accuracy is�0.2%.

Field Current Regulator (FCR)The current regulation mode allows the operatorto adjust the field current manually. This gives theoperator a manual voltage regulator. During theFCR mode, the automatic voltage regulator isdisabled. It is important to note that the FCR isnot the equivalent of an independent manualvoltage regulator, since it uses some of the samecircuitry as the automatic voltage regulator.

CONTROL AND PROTECTIONReactive Voltage DroopReactive voltage droop is possible through theuse of a single externally provided current trans-former (CT). The voltage droop is adjustable for amaximum of 10% droop at 0.8-power factor andfull rated load of the generator. Reactive droop,cross-current compensation and no droop voltagecontrol are selectable via ControlNet 1.5.

Cross-Current CompensationThe cross-current compensation method of par-alleling is possible with other controllers of similartype. This uses the same CT that is used if reac-tive voltage droop is selected instead of cross-current compensation.

KVAR/Power Factor Control (Optional)This feature maintains a constant reactive load(kVAR) output or constant power factor (pf) onthe generator set when the unit is operating inparallel with a large source. Power factor andkVAR control can be enabled or disabled by theoperator from the VDU. The operator can also

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select whether to use kVAR control or powerfactor control and set the set points from theVDU.

Kilowatt Load SharingThe load-sharing circuitry provides the ability tocommunicate with another CGCM, such that twoor more generator sets may equally share loadwhen running in parallel. Also, the CGCM willload share with older controls from Solar, such asthe LSM module or Woodward 2301 governor.The load sharing between generators of unequalrating is proportional to their rating.

Over-Excitation LimitingThe over-excitation limiter senses field currentand responds in less then three cycles. Whenfield current exceeds the limits, the limiter func-tion overrides the action of the CGCM AVR, VAR,or power factor modes and limits the current tothe preset level.

Under-Excitation LimitingUnder-excitation limiting (UEL) limits the de-crease in excitation to prevent loss of synchroni-zation and excessive end-iron heating duringparallel operation.

Line Drop CompensationLine drop compensation is a function of generatoroutput current. Both the real and the reactivecomponent of the current are used. The compen-sation is based on the magnitude of the line cur-rent. It is adjustable from 0 to 10% of rated volt-age.

Voltage Input SignalThe voltage regulator sensing uses three-phasesignals.

Current Input SignalThe CGCM uses 5-amp nominal inputs. The ac-curacy is �0.2% of full scale.

ProtectionThe protection functions are designed to diag-nose and respond to the following events:

� Over-excitation voltage (59F)� Generator over voltage (59)� Generator under voltage (27)� Loss of sensing (60FL)

� Loss of PMG (27)� Loss of excitation (40Q)� Over frequency (81O)� Under frequency (81U)� Reverse power (32R)� Phase rotation error (47)� Over current (51)� Rotating diode monitor (58)� Reverse VAR (40)

Over-Excitation Voltage. The over-excitationvoltage protection has a timed over-excitationtrip. The timed over-excitation protects the con-troller and generator from long-term field forcingconditions.

Generator Over Voltage. The unit has an over-voltage monitor adjustable from 100 to 140% ofrated voltage in 1% increments.

Generator Under Voltage. The unit has an un-der-voltage monitor adjustable from 60 to 100%of rated voltage, settable in 1% increments.

Loss of Sensing. When the generator voltagefalls below 15% of the rated generator voltage, aloss of voltage sensing annunciation occurs. Theloss of sensing function is supervised by the lossof operating power function and does not becomeactive until operating power reaches its minimumthreshold.

Loss of PMG. A loss of PMG fault is issuedwithin three cycles (50 msec) if PMG power inputis lost.

Loss of Excitation. A loss of excitation protec-tion fault is issued in order to protect against areverse VAR condition in the event the excitationcurrent is lost.

Over Frequency. When generator frequencyexceeds rated frequency for a specified amountof time, an over-frequency fault is annunciated.

Under Frequency. When generator frequencyfalls below the rated frequency for a specifiedamount of time, a definite time under-frequencyfault is annunciated.

Reverse Power. The reverse power protectionpickup level is settable from 1 to 50% of ratedgenerator power in increments of 1%. This fea-ture considers real power only.

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Phase Rotation Error. When possible and en-abled, a phase rotation check is performed priorto initiation of breaker closure.

Over-Current Protection. Over-current protec-tion must be provided with a short inverse timecharacteristic, Basler Electric Time Characteristiccurve S2, 99-1595. This feature is active if exci-tation is enabled.

Rotating Diode Protection. The rotating diodemonitor is capable of detecting one or more openor shorted diodes in the rotating field. If a faileddiode is detected, a fault is issued.

Reverse VAR. When excitation current is lostand the reverse VAR level exceeds the ratedvalue for a definite amount of time, a reverseVAR fault is annunciated.

OPERATOR INTERFACEThe control system operator interface has twomajor components: the turbine control panel andthe video display unit.

Turbine Control PanelThe turbine control panel (Figure 8) provides theessential controls to start or stop the turbine, toadjust the gas generator speed, and other op-tional control functions. Some typical gas turbinecontrols and indications that appear on the con-trol panel include the following:

Operation Switches

� Off/Local/Remote (control selector withlockable positions)

Figure 8. Operator Interface

� Emergency Stop (shutdown withoutcooldown)

� Normal Stop (shutdown with normal no-load cooldown)

� Speed Control (increase and decrease)� Start� Horn Silence (audible alarm)� Acknowledge (alarms and shutdowns)� Backup System (Active/Reset)

Operation Indication Lights

� Starting� Backup Active� Stopping

Onskid Video Display UnitThe video display unit is used to present an ex-tensive selection of the turbomachinery operatingparameters. The display system consists of sev-eral screens organized by systems and functionsto allow the operator to easily locate and monitora given parameter. It also includes a password-protected screen, which allows the operator toinput or modify certain values such as processcontrol set points.

The onskid VDU makes use of Solar'sTT4000S display and monitoring system, whichperforms several key functions to facilitate opera-tion of the turbomachinery equipment through auser-friendly interface. The TT4000S systemmonitors the turbine and driven equipment pa-rameters, annunciates alarms, reports on therunning status of the equipment, and provides acomprehensive set of analysis tools.

Data storage consists of an alarm / event logcontaining the last 5000 events, five trigger logscontaining one-second tag samples surroundingthe last five shutdowns, and an hourly log con-taining snapshot data for the last 12 months.

The TT4000S display and monitoring systemuses the Embedded Windows NT operating sys-tem and offers the following industry standardfeatures:

� Complies with Transmission Control Proto-col and Internet Protocol (TCP/IP)

� Supports Object Linking and Embeddingfor Process Control (OPC)

� Supports ActiveX controls� Can be integrated as part of a local area

network for sharing of data or remote dis-play communications

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Standard Display ScreensThe display screens listed below are for a typicalpackage and are provided as standard equipmentfor all turbine packages:

� Main Menu� Operation Summary� Engine Temperature� Shaft and Bearing� Lube System� Generator Summary� Bus Summary� Generator Control Modes� Generator Set Points� Gas Fuel System� Liquid Fuel System� Enclosure� Alarm Summary� Alarm Log� Event Log� Strip Chart� Maintenance Modes� VFD Configuration

Menu Screen. (Figure 9) This screen providesthe operator the ability to view the selectable viewscreens.

Figure 9. Typical Menu Screen

Operation Summary Screen. (Figure 10) Thisscreen provides a view of the overall gas turbineand driven equipment operating parameters. Thescreen displays turbine engine temperatures,

Figure 10. Typical Operation Screen

generator data, control mode, fuel commandstatus, fuel selection, operation mode, shutdownstatus, and lube pump operation. This screenalso displays the starting and stopping se-quences.

During the package start sequence, the VDUshows the various logic and timed sequencesinvolved from initiation of start-up to running con-dition. This feature is a valuable troubleshootingresource for operations personnel to quicklyidentify the source of the starting problem and,thus, reach a faster solution.

Engine Temperature Display Screen. (Figure11) This screen displays all the turbine-relatedtemperatures monitored on the unit. The screendisplays each individual thermocouple tempera-ture, as well as the calculated averages.

Figure 11. Typical Engine TemperatureScreen

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Shaft and Bearing Screen. (Figure 12) Thisscreen shows a bar graph representation of thevibration levels of the engine and generator asdetected by the vibration monitoring system. Thescreen displays the bearing temperatures forengine and generator.

Figure 12. Typical Shaft and Bearing Screen

Typical Lube System Screen. (Figure 13) Thisscreen displays all pertinent data for the lube oil,such as pressure, temperature, and the status ofthe pumps, along with the manual “backup pump”test function.

Figure 13. Typical Lube Oil Screen

Generator Summary Screen. (Figure 14) Thisscreen is a summary of the real-time generatoroperating data provided by the control system,including operating modes, set points, along withAC calculated and monitored values.

Figure 14. Typical Generator SummaryScreen

Bus Summary Screen. (Figure 15) This screenis a summary of the real-time generator andcustomer bus operating data system provided bythe control system, including Circuit Breaker Tripand Auto Sync Initiate control.

Figure 15. Typical Bus Summary Screen

Generator Control Screen. (Figure 16) Thisscreen allows the operator to view the status ofthe various generator control modes and to selectthe control mode desired through the use of pop-up screens.

Generator Set-Point Screen. (Figure 17) Thisscreen allows the operator to change set pointsby means of a pop-up screen or the local In-crease/Decrease switch. The set point and actualvalues are viewed from this screen as well.

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Figure 16. Typical Generator ControlModes Screen

Figure 17. Typical Generator Set-PointScreen

Gas Fuel Screen. (Figure 18) This screen dis-plays all of the pertinent data for the gas fuelsystem, such as pressure, flow, actuator, andstatus of the fuel valves. For a dual fuel system,the operator can transfer fuels from this screen.

Liquid Fuel Screen. (Figure 19) This screen dis-plays all of the pertinent data for the liquid fuelsystem, such as pressure, flow, actuator, andstatus of the fuel valves. For a dual fuel system,the operator can transfer fuels from this screen.

Enclosure Screen. (Figure 20) This screen dis-plays information related to the enclosure de-vices, such as fan, temperature, and gas sensor.

Figure 18. Typical Gas Fuel Screen

Figure 19. Typical Liquid Fuel Screen

Figure 20. Enclosure Screen

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Alarms Summary Screen. (Figure 21) Thisscreen displays all alarm and shutdown annun-ciations with a time and date stamp. Alarms aretime stamped in the order in which they are re-ceived from the programmable controller.

On the display, alarms are shown in yellowand shutdowns in red. Unacknowledged alarmsare shown in reverse video. As the malfunctionsare acknowledged, they stop flashing and areshown in the corresponding colored text until theyare cleared from the system and the Reset switchis pressed. The first four malfunctions detectedare displayed at the top of all screens untilcleared.

Figure 21. Typical Alarm Summary Screen

First Out Alarms Display Screen. (Figure 22)This screen displays the order in which alarmsoccurred. The resolution of the alarm order forthis feature is the time of one programmablecontroller scan. These data are obtained byreading the controller's first out alarm buffer,starting at the first unacknowledged alarm. Thecontroller updates this buffer each scan. Onlyunacknowledged alarms appear on this screen.Up to 22 alarms can appear.

Note: If the First Out Alarms display is to be usedto diagnose a shutdown, the Acknowledge buttonon the control panel must not be pressed. Press-ing the Acknowledge button does not eliminateunacknowledged alarms from the controller'salarm buffer, but it changes an alarm index sothat the First Out Alarms display cannot accessthem. As long as the Reset button is not pressed,however, the unchanged contents of the control-ler alarm buffer can be viewed as describedabove.

Figure 22. First Out Alarm Screen

Discrete Event Log. (Figure 23) This featuremonitors and records the changes in status of alldefined discrete (switch or binary) inputs. Theseinclude operator command, alarms and shutdownannunciations, and key sequencing and statussignals. They are displayed as a chronological,time-stamped listing of events in the order inwhich they occurred. It is possible to have multi-ple events with the same time stamp due to theupdate rate of the display system. Up to 500events can be stored in the log. Events can beselected by double clicking on the column head-ing. Right clicking anywhere on the screen andselecting the Reports menu can easily createreports.

This feature provides a historical record ofsequence and status events that changed. It canbe used to audit package operation or to identifymalfunctions that have occurred and areas of theoperation that need attention.

Figure 23. Typical Discrete Event LogDisplay Screen

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Strip Chart Function. (Figure 24) This functionemulates a 10-pen strip chart recorder. Thescreen displays in real-time up to 10 variablesselected by the operator. Parameters are se-lected by assigning each pen a value; the valuescan be analog or binary data available for moni-toring. Each pen can be assigned different colors,line weights, and symbols to make each moni-tored value easily distinguished from one an-other. The bottom of the strip chart screen dis-plays the corresponding legend for each pen.

Each of the plots is scaled for the selectedvariable and displays the actual numerical valuefor each variable. The date range and scaling canbe changed by double clicking on the desired pento bring up the configuration pull-down menu. Thetime axis on the strip chart can be configured foreach pen by date, hours, minutes, or seconds.The "zoom" feature allows the user to zero in onthe particular area of interest.

Figure 24. Typical Strip Chart Screen

Maintenance Screen. (Figure 25) This screenallows users to perform routine maintenance onthe turbine and displays information such as en-gine hours and engine starts.

Figure 25. Typical Maintenance Screen

VFD Configuration Screen. (Figure 26) Thisscreen allows the operator to configure the VFDmotors and monitor the performance of the mo-tors.

Figure 26. Typical VFD Configuration Screen

15

Optional Control and Display FeaturesOther hardware and software options are avail-able that provide additional flexibility and capabil-ity to the basic programmable controller controlsystem. These software, control and display fea-tures are described in this section.

ENGINEERING UNITSThe following engineering units are available fordisplay purposes:

Type Pressure Temp. LengthEnglish psig �F inchesMetric (SI) kPa �C mmMetric bar �C mmMetric kg/cm2

�C mm

FIRE DETECTION AND SUPPRESSIONSYSTEMA fire detection system is available for installationin the enclosure. The primary fire detection sys-tem uses ultraviolet (UV) detectors. The systemincludes an automatic optical integrity feature,which provides a continuous check of the opticalsurfaces and detector sensitivity.

The secondary detection system uses rate-compensated thermal detectors. The two detec-tion systems act completely independent in de-tecting a fire.

A fire system supervisory release panel isfurnished whose primary purpose is to supervisethe fire system circuitry. An open circuit, groundfault condition, or loss of integrity in the electricalwiring results in a trouble signal.

If a fire is sensed, the detectors transmit anelectrical signal via the fire system controller andthe fire system supervisory panel to activate thefire suppression system. In receiving this signal,the explosionproof control heads activate the dis-charge valves on the primary and extended ex-tinguishing cylinders, releasing the extinguishingagent into the enclosure and pressurizing thetrips that close all vent openings. The fire sup-pression system achieves a static air conditionand then floods the enclosure with the properconcentration of suppressant to extinguish thefire.

FIELD PROGRAMMINGOne characteristic of the control is that it can bereprogrammed using optional software with criti-

cal logic and constants accessible. Limited secu-rity to prevent inadvertent programming changesis built in, but predetermined programming altera-tions are possible with appropriate software.

Programming Terminal. A computer specificallyconfigured for programming the programmablecontroller control logic and sequences is pro-vided, along with software and a programmingmanual to allow for field programming of the con-trol system logic within the control system.

Programming Kit. The field programming kit in-cludes software, programming manual, and aPMCIA Type II interface card to allow field pro-gramming of the control system and logic.

LANGUAGEThe turbomachinery package labels, control con-sole labels, and operator interface screen dis-plays are available in numerous languages. Forlanguages available, please contact a Solar Tur-bines representative.

COMMUNICATIONS – TURBINE CONTROLTO SUPERVISORY SYSTEM Communication between the gas turbine controlsystem and the user's supervisory control anddata acquisition (SCADA), distributed controlsystem (DCS), or other supervisory system isavailable. Turbotronic 4 control systems can beprovided with an interface that allows the super-visory system to communicate with the program-mable controller, obtain data, and have the con-trol capability required.

Data for TransmissionThe following information from the turbine pack-age is available to be accessed by the supervi-sory system:

1. Analog instrumentation values2. Discrete status values3. Discrete alarms and shutdowns

The following information can be sent by the su-pervisory system:

1. Discrete control commands (start, stop,acknowledge/reset, and change mode ofoperations)

2. Analog operating set points (kW control,speed, kVAR, pf, and voltage)

16

The specific addressing for the data transferis provided for each turbine package.

ProtocolThe communication language used between pro-grammable controller systems usually follows aset of rules or format called a “protocol.” Theprotocol defines the sequence and organizationof the transmitted data. The RSLogix controlleruses an internal proprietary bus protocol called“control and information protocol” (CIP). Commu-nication modules allow different communicationnetworks to interface with this internal bus. Cer-tain arrays of information inside the controller canbe configured to mimic PLC-5 data tables thatsupport the DF1 protocol. The user's supervisorysystem must be programmed to handle the CIP,DF1, or Modbus protocols. The Allen-Bradleycommunications software RSLinx provides all the

necessary drivers to communicate with all turbinepackage control networks and network devices(except Modbus) and is required for most appli-cations.

Supervisory Interface OptionsThere are many ways to interface with the gasturbine control system. The most common in-clude serial communication (RS232, RS422,RS485), Ethernet TCP/IP, ControlNet 1.5, andModbus. See Figure 27 for a typical communica-tion network layout.

Each communication network has certain ad-vantages and disadvantages that need to beconsidered when selecting a network for a par-ticular application. Below is a description of eachnetwork to help select the optimum interface forthe user’s application:

Figure 27. Typical Communication Network Layout

Con

trolN

et M

odul

e

Flex I/O (Normal Input/Output)

Con

trolL

ogix

Ethe

rnet

Mod

ule

Onskid Control Box

RedundantControlNet 1.5

Backup RelayShutdown System

ControlNet 1.5(NAP connection)

Auxiliary Video DisplayUnit with CNet1.5 PCIC

Hardwire Interconnect

RS232

Ethernet TCP/IP

VFD(s)

HeatRecoverySystem

Basic ConfigurationOptions

SCADA/DCS

Mod

bus

Mod

ule

Modbus

Line Printer

Remote VideoDisplay Unit

RS232

KFC15

Local ProgrammingTerminal (for use during

commissioning)

Ethernet

17

ControlNet 1.5This is an Allen-Bradley developed proprietaryfield bus network. Data transmission rates arehigh, the communication is deterministic, and allinterface modules can be configured for redun-dant media.

� Physical media: quad shielded RG-6Ucoaxial cable

� Protocol: CIP� Topology: Trunk line/drop line,

star with repeaters � Maximum distance (per Rockwell

specifications): 1000 m (3280 ft) with2 nodes, 250 m (820 ft) with 48 nodes

� Maximum data transmission rate: 5 Mbps� Maximum number of nodes: 48

Typical Application. This is the control networkused to connect the distributed I/O modules tothe controller for turbine control. Onsite, VDUsare typically connected directly to this I/O networkvia PCC or PCIC cards installed in the computer.Supervisory interface (RS232C) with the turbinevia ControlNet is allowed only through a seriallink connection module (KFC15) or a separateControlNet network that is not directly connectedto the turbine I/O network. The maximum dis-tance and number of nodes allowed for the net-work can be increased by adding repeatersand/or by using optical fiber media. Field pro-gramming terminals can connect to the networkvia the network access port (RJ-type) located onthe interface module or Flex I/O adapters. Cur-rent ControlNet 1.5 networks and network de-vices are not compatible with older ControlNet1.25 networks or network devices.

Ethernet TCP/IPData transmission rates are high, the communi-cation is non-deterministic, and cabling and con-nectivity is well known throughout most industries(common office computer network technology).

� Physical media: twisted pair (10BaseT)� Protocol: CIP over TCP/IP� Topology: star� Maximum distance (per Rockwell

specifications): 100 m (328 ft) to hub� Maximum data transmission rate: 10 Mbps� Maximum number of nodes: unlimited

(8 to 24 nodes per hub typical)

Typical Application. The turbine packageEthernet module is usually connected to a localhub that is connected to an Ethernet backbonefor data transfer to a remote supervisory systemover longer distances. 10BaseFL fiber lines sup-port 2000 m (6560 ft) segments.

Modbus SlaveThe Modbus protocol is an open, published andwidely implemented protocol. It is used to transferI/O and register data between Modbus controldevices.

� Physical media: shielded twistedconductors

� Protocol: Modbus RTU� Topology: point-to-point (RS232/RS422)

or multi-drop (RS485)� Maximum distance (per Rockwell

specifications): 15 m (50 ft) for RS232,1219 m (4000 ft) for RS422/RS485

� Maximum data transmission rate:115.2 kbps

� Maximum number of nodes: 32 (RS485)

Typical Application. The Modbus Interface op-tion gives the turbine package control system theability to communicate with a Modbus masterdevice through a serial interface (RS232, RS422,or RS485). The turbine package control systemacts as a Modbus slave device using a subset ofthe RTU version of the Modbus protocol. Theuser provides the Modbus master device, whichmay be a supervisory control system, a data ac-quisition system, a central or plant control sys-tem, a remote monitoring system or some othercomputer system.

Remote RS232/422/485 Serial LinkSerial link communication allows connectivity ofdevices without special communication modulesto communication networks.

� Physical media: shielded twistedconductors

� Protocol: N/A� Topology: point-to-point (RS232/RS422)

or multi-drop (RS485)� Maximum distance (per Rockwell

specifications): 15 m (50 ft) for RS232,1219 m (4000 ft) for RS422/RS485

18

� Maximum data transmission rate: 20 kbps(RS232), 100 kbps @ 4000 ft/10 Mbps@ 40 ft (RS422/RS485)

� Maximum number of nodes: 32 (RS485)

Typical Application. A remote serial link is pro-vided to allow a remote supervisory system tosend and receive data to and from the ControlNetnetwork via an external Allen-Bradley KFC15communication module (RS232). Supervisoryserial interface through the DH+ network using aremote KF2 interface module is not advised,since this device can only handle local messag-ing (communication through other remote net-works is not allowed). The application softwareon the remote supervisory system must handleeither DF1 or CIP communication protocols.

VIDEO DISPLAY OPTIONSAuxiliary Video Display UnitThe auxiliary video display unit (VDU) consists ofan industrial desktop computer and the TT4000display and monitoring system. The auxiliaryVDU has all the features of the standard skid-mounted VDU plus the following enhancements:

� Additional Historical Data– 2-Minute Log. 1 month of daily files with

data points taken every 2 minutes– 10-Second Log. Data are read at 10-

second intervals for the last 14 days. � Larger Trigger Log. The Trigger Log

function stores up to 25 triggered files,each containing 6 minutes of 1-seconddata points. (The onskid VDU stores 5triggered files.)

� Accommodates Additional Options– Gas turbine performance calculations

and display – Printer– Remote VDU

� Higher Resolution Screen� More Memory, including RAM and

Non-Volatile Storage� Incorporates Visual Basic for

Application (VBA)� DVD Reader / CD Writer

The auxiliary VDU communicates with theonskid controller through ControlNet 1.5. Thetotal ControlNet cable run must be no longer than762 m (2500 ft). Cable run lengths for the auxil-iary VDU vary from project to project dependingupon how close the motor control center is to thegas turbine. Typically, the cable run without theauxiliary VDU is less than 150 m (500 ft), leaving610 m (2000 ft) for the auxiliary VDU cable run.Note: these distances are reduced if high flexcable is used.

Remote Video Display UnitThe remote video display unit (VDU) option con-sists of an industrial desktop computer equippedwith TT4000. The remote VDU has all the fea-tures of the auxiliary VDU with the exception thatsome of the operational privileges are limited atthe remote VDU. For example, lockout shut-downs cannot be reset remotely. The auxiliaryVDU option is a prerequisite for the remote VDUoption.

The remote VDU communicates with theauxiliary VDU through Ethernet. The Ethernetinterconnect is the responsibility of the customer.Distance is limited only by the customer’s net-work. Both the remote VDU and the auxiliaryVDU come with an Ethernet port and modem.The viewing of historical data from the remoteVDU may be noticeably slower depending uponthe speed of the customer-supplied network.

A gas turbine performance map for the pre-dicted rating of a gas turbine at standard condi-tions is displayed on the VDU (Figure 28). Algo-

Figure 28. Gas Turbine Performance Map

19

rithms convert site data to standard conditionsand the operating point is displayed real time onthe map at the intersection of X and Y cursors.

Digital values for the predicted power, inletair temperature, gas turbine temperature, fuelflow, and compressor discharge pressure arealso displayed on the screen. A key performanceindicator is provided for display by calculating thedifferential value (actual minus predicted) of thedigital values. The trend of these parameters pro-vides a true indication of performance degrada-tion since the data are standardized for the actualoperating point and not just optimum.

Information gained from this feature can pointto corrective and diagnostic action required, suchas washing the compressor and borescoping thehot gas path.

Printer/Logger OptionThis option is available with the auxiliary VDU. Itincludes a printer, cable, and software and pro-vides for a variety of reports and event logging.

Features provided are:

� Alarm and Shutdown Log – Prints oneevent per line with time and date stamp.

� Reports – On demand, prints currentvalues of standard analog variables andcalculated variables. Standard totalizedvariables may be printed also.

� Print Screen – On demand, prints anyscreen that is currently being displayed.

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Appendix A: HardwarePHYSICAL HARDWARE

� Programmable Controllers Allen-Bradley ControlLogix� I/O Allen-Bradley Flex Modules� Voltage Regulator Basler Electric/Allen-Bradley

Combination Generator Control Module (CGCM)� Onskid Display Allen-Bradley 6181� Power Supply 120 Vdc to 24 Vdc� Transducers 4 to 20 mA� RTDs Platinum 100 Ohms a = 0.00385� Control Enclosure NEMA 4 or NEMA 4X� Backup Controls Backup overspeed box

Backup relay shutdown system� Internal Wiring 20 gauge, typical

22 gauge for low level shielded wire12 gauge for most power wireWire identification, branded every 152 mm (6 in.)All customer connects are to Flex I/O or terminal blocks on DIN rail

ELECTRICAL SPECIFICATION

� Input Power 120 Vdc� Internal Power 24 Vdc� Input Signals Discrete signals, 24 Vdc

Analog signals, 4 to 20 mALow level temperature RTDHigh level temperature thermocoupleSpeed signal magnetic pick-up

� Output Signals Discrete 24 Vdc, 0.5 amp max.Discrete 24 Vdc, 2 amps max.Analog signals, 4 to 20 mA

� Relay Rating 24 Vdc, 3 to 10 amps120 Vac,12 amps

ENVIRONMENTAL SPECIFICATION

� Operating Temperature 0 to 60�C� Storage Temperature -40 to 85�F� Relative Humidity 5 to 95% non-condensing� Vibration 1g peak 5 to 20 Hz� Area Classification Nonhazardous

RFI/EMI SUSCEPTIBILITY AND EMISSIONSimilar equipment has been tested to the specification list below and passed the test successfully:

� IEC 801-2 Electrostatic Discharge Level 3� IEC 801-3 Radiated Immunity Level 3� IEC 801-4 Fast Transient/Burst Level 3� IEC 801-5 Electrical Surge Immunity Level 3� IEC 801-6 Conducted Emission Level 3� CISPR/B Conducted Emission Class A� CISPR/B Radiated Emission Class A

21

Appendix B: Technical SupplementHARDWARE INFORMATIONControlLogix Processor. The Allen-Bradley Logix5555 processor has 1.5 Mbytes of user memory andcan be connected in a variety of networks for interconnection with computers, distributed processing, anddistributed I/O:

General Specifications� Processor for Logix5555 1756-L55M13 � Environmental Conditions

– Operational Temperature 0 to 70�C (32 to 158�F)– Storage Temperature -40 to 85�C (-40 to 185�F)– Relative Humidity 5 to 95% (without condensation)

� Vibration – Operating 10 to 500 Hz, 2.0 g maximum peak acceleration

Electrical Specifications� Operating Voltage 19.2 to 32 Vdc (24 Vdc nominal)� Integrated Battery Each Logix5555 processor is shipped with a battery installed for

memory backup (part number 1756-BA1).

ControlLogix Power Supply. Used with the 1756 chassis to provide power directly to the chassis back-plane:

� Model 1756-PB72� Input Voltage 24 Vdc� Input Power 97 W� Backplane Output Current 1.50 A @ 1.2 Vdc

4.00 A @ 3.3 Vdc10.0 A @ 5.0 Vdc2.80 A @ 24 Vdc

Discrete Input Modules. These modules receive input from on/off devices such as level switches, pres-sure switches, push buttons, relays and protective equipment:

� Model 1794-IB16� Channels 16� Signal 10 to 32 Vdc

Discrete Output Module. This module drives devices such as solenoid valves and motor contactors.

Current RatingModel Channels Signal Per Channel Per Module

1794-OB16P 16 10 to 32 Vdc 0.5 81794-OB8EP 8 19 to 32 Vdc 2 10

Analog Input Modules. Some modules accept signals from high-level output devices, such as currenttransmitters; others accept low-level signals, such as from RTDs.

Model 1794-IE8 Series B� Channels 8� Signal Rating 4 to 20 mA, 0 to 20 mA,

� 10 V, 0 to 10 V

22

Model 1794-IJ2� Channels 2� Inputs per Channel 2 (frequency and gate)� Frequency 32,767 Hz max.� Usage Fast, high resolution speed measurements

Model 1794-IRT8� Channels 8� Inputs Ranges -40 to +100 for thermocouples

0 to 325 mVdc for RTDs0 to 500 ohm for resistance range

� Usage High-speed module used for temperature measurements. Separatescaling and cold junction compensation is required.

Analog Output Modules. These modules are used for drive-positioning devices such as the fuel throttlevalve and to provide analog signals to other instrumentation.

Model 1794-IE8 Series B� Channels 4� Output Current 4 to 20 mA, 0 to 20 mA� Output Voltage � 10 V, 0 to 10 V,

� 5 V, 5 V

HARDWARE CERTIFICATIONIn general, Allen-Bradley components are SA and ATEX certified for Class I, Division 2, Zone 2, GroupsA, B, C, and D.

AREA CLASSIFICATIONNonhazardous.

QUALITY ASSURANCEComplete control systems are put through three test phases at Solar: static test, pre-test, and final test.Further tests are made during installation and commissioning.

1. Static Test. Verifies the correct console wiring and software was installed, including the standardoptions and nonstandard features required for the project.

2. Pre-Test. The controller is mated with the unit it is shipped with and is used to verify correct skidwiring and certain statically tested functions.

3. Final Test. The unit is operated with its control system, where final package and control tests aremade. The software used for this test is the “as-shipped” software (excluding Titan gas turbines).

4. Commissioning. During commissioning tests onsite, any further software changes that are foundto be necessary are included in the “as installed” software.

CONTROL CONSOLE LAYOUTThe basic arrangement for the programmable controller is to have one seven-slot 1756 I/O chassis andpower supply similar to the one seen in Figure 29. The programmable controller module is in the left-most slot and all other applicable modules occupy the six remaining slots. This assembly is mounted on apanel (Figure 30) attached to the back wall of the console.

23

Figure 29. ControlLogix Chassis Configuration

Figure 30. Generator Control Panel and Turbine Control Panel Internal Configuration

24

Appendix C: Control System InformationTURBOTRONIC DEFINITIONSControl Processor. The central controlling de-vice. Turbotronic 4 uses the Allen-Bradley Con-trolLogix processor, which replaces the pro-grammable logic controller (PLC5) used on ear-lier systems.

HMI. Human Machine Interface – the generallyaccepted industry term for display and monitoringsystems, such as Solar’s TT4000 product.

Onskid. Located on and permanently attachedto the turbomachinery package skid.

Remote. Located someplace other than the tur-bomachinery area and control room, usually atsome distance away in an unclassified area.Remote HMI implies a secondary HMI system inaddition to the primary HMI.

TT4000. A Windows 2000 based display andmonitoring system that is available with the Tur-botronic 4 system.

Turbotronic 4. Solar Turbines new package andcontrol system.

VDU. Video Display Unit – a generic term for acomputerized display device.

HUMAN MACHINE INTERFACEDESCRIPTIONSTT4000. Solar’s fully featured display and moni-toring system consisting of a desktop PC (A-B6155) configured with the Windows 2000 operat-ing system, the TT4000 application software, andthe specific project software files. It provides ex-tensive data storage capabilities in addition todisplay, communications, and control capabilities.It is designed for operation in a nonhazardousarea such as a control room.

TT4000S. A version of Solar’s TT4000 software,which is installed in an onskid VDU (A-B 6183)and makes use of the Windows Embedded NToperating system. It provides display, communi-cations, and basic control capabilities at the

package skid. It provides only limited data stor-age capability.

TT4000 Remote. This is the version of TT4000installed on a “remote” PC (A-B 6155). It mirrorsthe functionality of the primary TT4000 system.

Important NoteTT4000 is provided only as a complete systeminstalled, configured, and tested on computerhardware supplied by Solar. This hardware mustbe dedicated to the TT4000 system and no othersoftware may be loaded. This is necessary toprotect the integrity of the system and avoid anypotential interaction with other software.

SYSTEM DESCRIPTIONSFigure 31 shows the various components thatmake up the Turbotronic 4 control system.

Auxiliary Desktop PCThe TT4000 display and monitoring system in-stalled in a desktop PC. This PC must be locatedno more than 762 cable m (2500 cable feet) fromthe package skid.

Onskid Control SystemThe control system is mounted in one or morepanels attached to the package skid. The panelscontain the key elements of the system, includingthe control processor, the I/O modules, the vibra-tion monitoring system, and the TT4000S displaysystem. Packages with onskid controls may onlybe installed in a nonhazardous area.

Remote Desktop PCA secondary TT4000 display and monitoringsystem installed in a desktop PC, providing re-mote monitoring and control of the turbomachin-ery package. This PC must be linked to the pri-mary TT4000 system via a network connection.The distance between this PC and the primaryTT4000 system is limited only by the capability ofthe network.

25

Figure 31. Turbotronic 4 Control System Outline

TT4000REMOTECONTROL

PROCESSORAND I/O

CONTROLNETETHERNETOR OTHER

TT4000S

TT4000DESKTOP

FOR MORE INFORMATIONTelephone: (+1) 619-544-5352Telefax: (+1) 858-694-6715Internet: www.solarturbines.com

Solar Turbines IncorporatedP.O. Box 85376San Diego, CA 92186-5376 U.S.A.

SPTT-PG/802