SPEEDTRONIC™ Mark VI TMR New Unit, Heavy Duty Gas Turbine Control These instructions do not purport to cover all details or variations in equipment, nor to provide for every possible contingency to be met during installation, operation, and maintenance. If further information is desired or if particular problems arise that are not covered sufficiently for the purchasers purpose, the matter should be referred to GE Industrial Systems. This document contains proprietary information of General Electric Company, USA, and is furnished to its customer solely to assist that customer in the installation, testing, operation, and/or maintenance of the equipment described. This document shall not be reproduced in whole or in part, nor shall its contents be disclosed to any third party without the written approval of GE Industrial Systems. Section Page Introduction..................................................................................................................2 Redundancy .................................................................................................................3 I/O Interface .................................................................................................................3 Built-in Diagnostics .....................................................................................................5 System Overview .........................................................................................................5 Control Functions ........................................................................................................7 Sequencing...................................................................................................................9 Protection .....................................................................................................................9 Operator Screens ........................................................................................................12 Typical Turbine Instrumentation ...............................................................................15 Packaging...................................................................................................................17 Power Requirements ..................................................................................................18 Acronyms and Abbreviations.....................................................................................18 g GE Industrial Systems GEI-100472 CIMPLICITY is a trademark of GE Fanuc Automation North America, Inc. Ethernet is a trademark of the Xerox Corporation. SPEEDTRONIC is a trademark of General Electric Company, USA. Windows NT is a registered trademark of Microsoft Corporation.
Transcript
SPEEDTRONIC� Mark VI TMRNew Unit, Heavy Duty Gas Turbine Control
These instructions do not purport to cover all details or variations in equipment, nor toprovide for every possible contingency to be met during installation, operation, andmaintenance. If further information is desired or if particular problems arise that are notcovered sufficiently for the purchaser�s purpose, the matter should be referred to GEIndustrial Systems.
This document contains proprietary information of General Electric Company, USA, and isfurnished to its customer solely to assist that customer in the installation, testing, operation,and/or maintenance of the equipment described. This document shall not be reproduced inwhole or in part, nor shall its contents be disclosed to any third party without the writtenapproval of GE Industrial Systems.
CIMPLICITY is a trademark of GE Fanuc Automation North America, Inc.Ethernet is a trademark of the Xerox Corporation.SPEEDTRONIC is a trademark of General Electric Company, USA.Windows NT is a registered trademark of Microsoft Corporation.
2 •••• Mark VI TMR Gas Turbine Control GEI-100472 Application Overview
IntroductionThe high reliability achievedby the TMR control system isdue to the integration of thetriple redundant electronicsand sensors into a robust,fault tolerant control system.
The SPEEDTRONIC Mark VI gas turbine control is a Triple Modular Redundant(TMR), microprocessor-based control with a heritage of over 30 years of successfulturbine automation. The basis of this system is the three redundant control modules<R>, <S>, and <T>. Each controller contains its own power supply, processor,communications, and I/O for all of the critical control, protection and monitoring ofthe gas turbine. Some critical functions, such as emergency overspeed protection andthe phase-slip windows for backup synch check protection, are monitored by aseparate triple redundant backup protection module <P>. Most of the critical sensorsfor control loops and trip protection are triple redundant. Other sensors are dual orsingle element devices.
3 Independent Sections
3 Control Modules
Backup Protection Module
Mark VI Electronics
GEI-100472 Application Overview Mark VI TMR Gas Turbine Control •••• 3
RedundancyAn important part of the fault tolerant control architecture is the method of reliablyvoting the inputs and outputs. Each control module reads its inputs and exchangesthe data with the other two control modules every time the application software isexecuted at 40 ms.
In addition, a 1ms time stampis assigned to each contactinput to provide a built-insequence of events (SOE)monitor.
The voted value of each contact input and the median value of each analog input iscalculated within each control module, and then used as the control parameter for theapplication software. Diagnostic algorithms monitor these inputs and initiate analarm if any discrepancies are found between the three sets of inputs.
Redundant contact inputs for trip functions are connected to three separatetermination points and then individually voted. This enables the control system tosurvive multiple failures of contact or analog inputs without causing an erroneoustrip command as long as the failures are not from the same circuit, such as lube oilpressure.
An equally important part of the fault tolerance is the hardware voting of analog andcontact outputs. Three coil servos on the valve actuators are separately driven fromeach control module, and the position feedback is provided with redundant linearvariable differential transformers (LVDTs). Contact outputs to the hydraulic tripsolenoids are voted with three magnetic relays on each side of the floating 125 V dcfeeder to the solenoids.
I/O InterfaceThe I/O is designed for direct interface to turbine and generator devices, such asvibration sensors, flame sensors, LVDTs, magnetic speed pickups, thermocouples,and Resistance Temperature Devices (RTDs). Direct monitoring of these sensorseliminates the need for interposing instrumentation with its associated single pointfailures, reduces long-term maintenance, and enables the Mark VI diagnostics todirectly monitor the health of the sensors on the machinery. This data is thenavailable to both local operator/maintenance stations and to the plant DistributedControl System via communication links.
Contact Inputs are powered from the 125 V dc battery bus through the Mark VItermination boards. Each contact input is optically isolated and has a 1 ms timestamp for SOE monitoring. Contacts are open-to-alarm and open-to-trip. Aninversion mask is applied to each contact input to normalize the data values andsimplify understanding of the software. For example, 63QT is a low lube oil pressuretrip switch that will open-to-trip. The inversion mask is applied such that wheneverlogic L63QT = 1 it means that there is low lube oil pressure. Conversely, if the fieldcontact was closed-to-trip, the inversion mask would be 0 and L63QT = 1 would stillmean that there is low lube oil pressure.
Contact Outputs are from plug-in, magnetic relays with dry, form C contactoutputs. The control provides a floating 125 V dc source and suppression for eachsolenoid with a 3.2 A slow-blow fuse on each side of the 125 V dc feeder.
4 •••• Mark VI TMR Gas Turbine Control GEI-100472 Application Overview
Analog inputs can monitor 4-20 mA (250 ohms), which can be configured for self-powered, differential inputs, or as sensors that use a +24 V dc supply from theturbine control. Selected inputs can be configured for 0-1mA inputs (5,000 ohms), or±5, 10 V dc inputs. Analog outputs can be configured for 4-20 mA output (500ohms max) or 0-200 mA output (50 ohms max).
Gas turbine temperatures are monitored by type K thermocouples. Criticaltemperatures, such as exhaust temperature have multiple thermocouples that aredivided between the three control modules for redundancy. Non-criticalthermocouples, such as wheelspace and bearing temperatures, are connected to onethermocouple card in one control module, but the data is transmitted to all three mainprocessors for monitoring and alarming. The control can interface with grounded orungrounded thermocouples, and software linearization is provided for types E, J, K,or T.
Generator temperatures are normally monitored with grounded 100 ohm platinumRTDs. The control can interface with grounded or ungrounded RTDs. Softwarelinearization is provided for 10 ohm copper, 100/200 ohm platinum, or 120 ohmnickel RTDs.
Speed Inputs include three passive, magnetic, speed sensor inputs. The medianvalue is used for speed control and primary overspeed protection in the controlmodules. Three additional speed sensors are provided for emergency overspeedprotection. These sensors are monitored by the three sections of the backupprotection module and diagnostics are transmitted between the backup protectionmodule and the control modules for cross-tripping and alarm management.
The control monitors redundant Reuter Stokes type UV flame scanners and initiatesan alarm if the light intensity diminishes below an acceptable level due to carbonbuildup or other contaminants on the scanner windows.
Servo valve interface is described in the section, Control Functions.
Seismic (velocity) Vibration Transducers are monitored directly by the Mark VIfor trip protection of the turbine and generator. These devices generate a small outputcurrent by passing a magnet through a fixed coil, thereby eliminating the need forexcitation current. All vibration sensors are continuously monitored for faults, alarmlevels, and trip levels. Protection features include:
Standard vibration protectionin Mark VI card rack.
• A start check permissive is inhibited if three or more turbine sensors or two ormore generator sensors are disabled or faulty.
• An automatic shutdown sequence is initiated if all turbine or all generatorsensors are disabled or faulty.
• A trip is initiated if one turbine vibration sensor indicates a trip level and anyother turbine sensor indicates an alarm level.
• A trip is initiated if one turbine vibration sensor indicates a trip level and anyadjacent pair of turbine sensors are disabled or indicates an alarm level.
• A trip is initiated if one turbine vibration sensor indicates a trip level and two ormore sensor inputs are disabled.
GEI-100472 Application Overview Mark VI TMR Gas Turbine Control •••• 5
An option is available for Bently Nevada Proximitors for monitoring only. TheProximitors can be supplied as either an interface to a Bently Nevada 3300 or 3500monitor with an additional option for a Data Manager 2000 or as a direct interface tothe turbine control. A Mark VI option is available for buffered outputs to BNCconnectors to facilitate plug-in analysis instrumentation and direct plug connectionfrom the Mark VI termination boards to 3500 monitors.
Note The mission of the turbine control is to provide alarm and trip protection,whereas the mission of the Bently Nevada is to facilitate vibration analysis.
The Synchronizing Interface uses a pair of single-phase potential transformers(PT), which are monitored by the control modules. It matches the turbine speed tothe line frequency and match the generator and line voltages via the Unit DataHighway (UDH) to the generator excitation system. A command is issued to closethe breaker based on a calculated breaker closure time. Diagnostics monitor theactual breaker closure time and self-correct each time the breaker closes. The singlephase PTs are paralleled to the triple redundant backup protection module for thebackup synch check protection. The synch check protection is used to backup theautomatic synchronizing and the manual synchronizing which is implemented from asynchroscope screen on a Human-Machine Interface (HMI) server. Three-phase PTinputs from the generator and line, and single-phase current transformer (CT) inputsare normally monitored by the generator protection and the EX2000.
Built-in DiagnosticsThe Mark VI control system has extensive built-in diagnostics and includespowerup, background, and manually initiated diagnostic routines. These diagnosticsare capable of identifying both control panel, sensor, and output device faults. Thesefaults are identified down to the board level for the panel, and to the circuit level forthe sensors and actuators.
System OverviewThe control system consists of several networks. IONET is the Ethernet -basednetwork for communication between the three control modules, the three sections ofthe protection module, and any expansion modules. IONET uses asynchronousdrives language (ADL) to poll the modules for data instead of using the typicalcollision detection techniques used in Ethernet local area networks (LAN).
Ethernet networks with peer-to-peer communicationbetween turbine andgenerator controls.
The UDH is an Ethernet-based network that provides peer-to-peer communicationsbetween the turbine control, the generator excitation control, and the static starter.The network uses Ethernet Global Data (EGD), which is a message-based protocolwith support for sharing information with multiple nodes based on the UDP/IPstandard. Data can be transmitted unicast or broadcast to peer control systems on thenetwork. Data (4K) can be shared between up to 10 nodes at 25 Hz.
The Mark VI is used to control megawatt output, and the EX2000 is used to controlmegavar output. The generator protection panel (GPP) is used to provide primaryprotection for the generator. Additional protection features are located in theEX2000. Although the UDH is capable of communicating control data, control loopsare closed internal to the turbine or generator control.
6 •••• Mark VI TMR Gas Turbine Control GEI-100472 Application Overview
In the case of var/power factor control for the generator or tie-line, the turbinecontrol performs the regulation of the setpoint and transmits the command to adjustthe generator field on the UDH to the excitation control. All trip commands are hard-wired between control units, including any trip commands coming from remotecontrol systems such as a Distributed Control System (DCS).
An optional OSI PI- basedHistorian is available forlong term data archiving andretrieval.
Dual servers (CIMPLICITY /Windows NT ) are available to isolate the UDHfrom the Plant Data Highway (PDH). These servers can be used as local or remoteoperator and/or maintenance stations and configured in a variety of arrangements.Typically, one server is located in each Packaged Electrical and Electronic ControlCompartment (PEECC) that contains a turbine control, a generator protection panel,a motor control center, and the 125 V dc batteries. The primary server can beprovided with a time synchronization interface to a Global Time Source (GTS),which is normally implemented with IRIG-B. A backup time master can be providedin a backup server. Network Time Protocol (NTP) is used for internal timesynchronization with ±1 ms time coherence.
The Plant Data Highway is used to communicate data to the plant distributed controlsystem or other third party platforms. A variety of protocols are supported forcommunication with a plant DCS including RS-232C and RS-485 Modbus remoteterminal unit (RTU) master/slave, Ethernet TCP-IP Modbus slave, and EthernetTCP-IP with GEDS Standard Messages (GSM). The GSM protocol provides thefollowing messages:
• Administration
• Spontaneous Event Driven (with local time tags)
• Periodic Group Data (at rates to 1 second)
• Common Request
GEI-100472 Application Overview Mark VI TMR Gas Turbine Control •••• 7
Control FunctionsStartup Control is an open loop system that increases the fuel stroke reference(FSR) as the turbine startup sequence progresses to preassigned plateaus.
Acceleration Control adjusts the FSR according to the rate of change of the turbinespeed to reduce the thermal shock to the hot gas path parts of the turbine.
Speed Control uses the median speed from three speed sensors for droop andisochronous speed control with an automatic transfer to isochronous upon loss of thetie-line breaker.
The FSR is determined by thecontrol parameter calling forthe least fuel.
Load Control compares the load setpoint with the MW feedback from a single-phase transducer and adjusts the speed setpoint to regulate the load. Selection of fastload start or pre-selected load will raise the setpoint to the pre-selected load limit.Selection of base or peak will raise the setpoint to the maximum limit.
Exhaust Temperature Control thermocouples are divided between the threecontrol modules for redundancy. All of the temperature data is transmitted to all ofthe control modules that sort the data from the highest to the lowest temperature,automatically reject bad thermocouple data, average the remaining data values, andthen execute the control algorithm. Three redundant transducers are supplied formonitoring the compressor discharge pressure and biasing the temperature control tocorrect for ambient temperature and the corresponding variations in mass flow.
Inlet Guide Vane Control modulates the position of the compressor stator vanes toprovide optimum compressor and unit operation. During startup, the guide vanesopen as the turbine speed increases. When the unit is online, the guide vanesmodulate to control turbine airflow temperature to optimize combustion system andcombine cycle performance.
Fuel Control consists of a reference from the governor and feedback of the fuelcontrol valves. The FSR is determined by the turbine parameter (speed, temperature,and so on.) calling for the least fuel. Calculation of the FSR is performed in the mainprocessor and transmitted to the servo valve cards on the backplane of the controlmodules. High speed regulation of the servo loop with LVDT position feedback isperformed on each servo card to obtain the maximum performance.
In liquid fuel control systems, FSR establishes the called for stroke of the bypassvalve. Fuel flow is proportional to the speed (fuel flow = speed X FSR). In gas fuelsystems with only a gas control valve, the fuel flow is a function of pressure (fuelflow = pressure X FSR); therefore, a stop/speed ratio valve is added, which isprogrammed by speed. Pressure is now a function of speed and the liquid fuel controlsystem and the gas fuel control system have the same characteristic (refer to thefollowing diagram).
8 •••• Mark VI TMR Gas Turbine Control GEI-100472 Application Overview
Gas Fuel
Servo90SR
LVDT96SR
TSVO
Stop/SpeedRatio Valve
TerminationBoardVSVO Card
A/D
VCMICard
Main Processor
FPRG
TNH (Speed)
Constants
LogicSoftwareRegulator D/A
96FG
Gas FuelPressure
TBAIVAIC CardD/A
+
-
Servo65GC
LVDT96GC
TSVO
Gas ControlValveVSVO Card
A/D
FSROUT
FSR2
LogicSoftwareRegulator D/A
CombustionChamber
Servo65FP
TSVO
Stop/SpeedRatio Valve
VSVO Card
A/D
SoftwareRegulator
FlowDivider
Liquid Fuel
Pulse77FD
D/A
FSROUT
Logic
TNH (Speed)
FSR1
FuelSplitterFSR
Logic
Control Module
Duel Fuel Control System
Generator Excitation Setpoints for volts (voltage matching duringsynchronization) and var/power factor control for the generator and tie-line are in theturbine control. References come from operator commands, and feedback comesfrom a single-phase var transducer. Power factor is calculated from watts and vars.Setpoints are transmitted from the turbine control to the generator excitation controlon the UDH.
Synchronizing is described in the section, I/O Interface.
Emissions Control is available with diluent (water or steam) injection through amulti-nozzle quiet combustor to quench flame temperature and reduce thermal NOXformation. Lean-burning, pre-mixed flame combustors are available for lower NOXlevels without the need for water or steam injection (dry low nox).
GEI-100472 Application Overview Mark VI TMR Gas Turbine Control •••• 9
SequencingThis automation enablesoperation of the gas turbinefrom a remote (off-site)location with the assurancethat the turbine is fullyprotected and diagnostics willcapture and record anyabnormal conditions that mayoccur.
The turbine control includes a completely automated startup and shutdown sequence,including interface to all of the auxiliary systems in the motor control center andgenerator protection system. Operators can choose to have the turbine automaticallysequence to intermediate hold points by selecting Crank or Fire without enablingautomatic synchronization. All ramp rates and hold times are pre-programmed foroptimum performance, and counters record the number of starts, shutdowns, tripsand running time under various conditions in non-volatile memory. Counters andtimers for a 7FA, gas fuel, and dry low Nox (DLN) turbine are as follows:
Timers Counters
Total Fired Time Manually Initiated Starts
DLN Primary Mode Total Starts
DLN Lean-lean Mode Fast Load Starts
DLN Premix Mode Fired Starts
DLN Extended Lean-Lean Mode Emergency Trips
ProtectionThe turbine control system monitors all control and protection parameters andinitiates an alarm if an abnormal condition is detected. If the condition exceeds apredefined trip level, the turbine control will drive the gas/liquid control valves to azero flow position and de-energize the hydraulic trip solenoids. Since this action isvital to protecting the turbine, the electronics are triple redundant.
All of the control, protection, and monitoring algorithms are contained in the controlmodules for efficiency in sharing the common data used in these calculations.Backup protection for emergency overspeed and synch check protection isperformed in the protection module.
10 •••• Mark VI TMR Gas Turbine Control GEI-100472 Application Overview
PrimaryOverspeed
CombustionMonitor
Loss Of Flame
Rotor Vibration
CompressorSurge
Fire ProtectionSystem
High Lube OilHeader Temp.
GeneratorSynchronization
EmergencyOverspeed
ExhaustOvertemperature
Generator SynchCheck Protection
<R>Module
<S>Module
<T>Module
<X>Section
<Y>Section
<Z>Section
<P> Protection Module
Customer Protect.Shutdown
Fuel ControlSystem
Hydraulic TripSystem
FuelStopRatioValve
FuelControlValve
Fuel ToTurbine
ManualEmergency
Trip
Steam TurbineStop Valves
Steam CycleTrip System
Low HydraulicSupply / Trip
Pressure
Low Lube OilPressure
ManualHydraulic Trip
For Single Shaft STAG
For Turbines With NoMech. Overspeed Bolt
TMR Applications
Typical Protection System
Each trip solenoid is powered from the 125 V dc floating battery bus with contactsfrom the control module in series with the negative side of the bus and contacts fromthe backup protection module in series with the positive side of the bus. Since thereare three control modules and three sections of the backup protection module, eachtrip solenoid has three relays from the control module voting on one side and threerelays from the backup protection module voting on the other side.
GEI-100472 Application Overview Mark VI TMR Gas Turbine Control •••• 11
Diagnostics monitor a contact from each relay and also monitor the voltage directlyacross the trip solenoid. For added insurance, diagnostic and trip data arecommunicated between the control modules and the backup protection modules onthe triple redundant IONets for cross-tripping.
Overspeed protection consists of a primary overspeed monitoring system in the threecontrol modules and an emergency overspeed monitoring system in the backupprotection module, which replaces the mechanical overspeed bolt used on olderturbines. Each control module and each section of the backup protection modulemonitors a separate passive magnetic speed sensor (6 total) from 2 rpm on a 60 toothwheel. Diagnostics monitor the speed and acceleration and exchange the databetween the control modules and the backup protection module on startup to verifythat all sensors are active.
The following is a list of typical trips supplied on a 7FA, gas fuel, DLN turbine.
Pre-ignition Trips Post-ignition Trips General Trips
Auxiliary Check (Servos) Loss of Flame Starting Device Trouble
Seal Oil DC Motor Undervoltage High Exhaust Temperature Inlet Guide Vane Trouble
DC Lube Oil PumpUndervoltage
Exhaust Thermocouples Open Manual Trip
Failure to Ignite on Gas Fuel Compressor Bleed Valve PositionTrouble
Control Speed Signal Lost - HP
Load Tunnel Temperature High Protective Speed Signal Trouble
Red. Sensor Gas Fuel HydraulicPressure Low
Control Speed Signal Trouble
Turbine Lube Oil HeaderTemperature
Gas CV Not Following Reference
Turbine Electronic Overspeed Secondary CV Not Following Ref.
Dry Low Nox System Trip PM3 CV Not Following Reference
Compressor Operating Limit Error Quaternary CV Not Following Ref.
Control System Fault
Low Lube Oil Pressure
Fire Indication
Generator Differential TripLockout
Transf. Differential Trip Lockout
Exhaust Pressure High
Breaker Failure Trip Lockout
Vibration Trip
Startup Fuel Flow Excessive
Loss of Protection HP SpeedInputs
Customer Trip
12 •••• Mark VI TMR Gas Turbine Control GEI-100472 Application Overview
Operator Screens
The operator/maintenance interface is commonly referred to as the Human MachineInterface (HMI). It is a PC with a GE CIMPLICITY graphics screen system, aMicrosoft Windows NT operating system, a Control System Toolbox with editors forthe application software and unit specific screens. This interface can be applied as:
• primary operator interface for one or multiple units
• backup operator interface to the plant DCS operator interface
• gateway for communication links to other control systems
• permanent or temporary maintenance station
• engineer�s workstation
All control and protection is resident in the turbine control, which allows the HMI tobe a non-essential component of the control system. It can be reinitialized orreplaced with the turbine running with no impact on the control system. The HMIcommunicates with the processor card in the turbine control via the Ethernet -basedUDH.
Operator Interface Graphics
GEI-100472 Application Overview Mark VI TMR Gas Turbine Control •••• 13
Gas turbine control screens show a diagram of the turbine with the primary controlparameters. The diagram is repeated on most of the screens to enable operators tomaintain a visual picture of the turbine�s performance while changing screens. Somescreens such as the exhaust temperature monitor and the static starter screen haveunique graphics. All screens have a menu on the right-hand side of the display,which has a hierarchy of an Overview screen (for a multiple unit site), Unit selection(such as GT1 or GT2), Control/Monitor/Auxiliaries/Tests screen category selection,and a sub-menu of specific screens for each category.
Typical Gas Turbine Screens
Control Screens Monitor Screens Auxiliaries Tests
Startup Bearing Temperature Flame Overspeed Tests
Dry Low Nox Exhaust Temperature Generator Capability
FSR Control Generator RTDs Start Check
Generator/Exciter Hydrogen Static Starter
IGV Control Seismic Vibration Timers
Motors Wheelspace Temperature Trip Diagram
Synchronizing Water Wash
The primary screen in the system is the Startup screen. Since the gas turbine controlprovides fully automatic startup including all interface to auxiliary systems, anoperator can initiate all of the basic commands and observe all of the primary controlparameters and status conditions from this single screen.
All operator commands can be given through momentary pushbutton commands onthe screen. The command is sent to the Mark VI control where the applicationsoftware initiates the requested action assuming that the appropriate permissives aresatisfied. A response to the command can be observed within one second, if it doesnot involve subsequent system time delays like purging.
As an example, if Ready to Start is displayed in the Startup Status field, a Startcommand can be given. A small pop-up window displays above the Start button forthe operator to verify the start of the turbine. Upon verification, the applicationsoftware checks the startup permissives and initiates a startup sequence, whichdisplays Starting and Sequence in Progress messages on the left side of the screen.
The purpose of the alarmqueue is to identify anyabnormal condition includingany reason to inhibit a startsequence.
If the unit was not ready to start, then the message Not Ready to Start displays andan alarm message displays in the bottom left-hand corner of the screen identifyingthe reason. In addition, there is a Start Check screen (under Auxiliaries), whichprovides a graphical representation and status of the Start Check / Ready to Startpermissives. This graphic also relates to the functional organization of theapplication software for the Start Check/Ready to Start Permissives. Similarly, alltrips displayed in the alarm field and in the Trip Diagram under Auxiliaries. If alatched trip is the reason for not being ready to start, then the operator must selectthe Master Reset button on the Startup screen. This references another screen toremind the operator to investigate the latched trip prior to issuing a Master Reset.
14 •••• Mark VI TMR Gas Turbine Control GEI-100472 Application Overview
In some cases, it is more convenient for the operator to change a setpoint, such asMW, by typing in a numerical value for the setpoint rather than issuing raise/lowercommands. This capability is provided, and the application software in the Mark VIautomatically compares the requested setpoint with acceptable limits and determinesa suitable rate to ramp the setpoint to the new target.
A Startup Trend can be selected with pre-assigned parameters for the mean exhausttemperature, speed, maximum vibration, compressor discharge pressure, inlet guidevane position, and the fuel stroke reference. More detailed information and trendingare provided on supporting screens, and customized trends can be created too.
GEI-100472 Application Overview Mark VI TMR Gas Turbine Control •••• 15
Typical Turbine InstrumentationRedundant and Multiple Sensors
Device Parameter Function Device Type Quantity Redundant
26QA/T Lube oil temp high A/P Temp switch 3 S
28FD Flame detector A/P UV scanner 4/8 S
33FL Liquid fuel stop valve M Limit switch 2 S
39VX Vibration sensor A/P Velocity pu 2 S
45FX Fire detector A/P Temp switch 2* S
63HG Gas fuel trip oil pressure A/P Press switch 3 D
63QA/T Lube oil hydraulic pressure A/P Press switch 3 S
63TF Inlet filter pressure C/P Press switch 3 D
65FP Liquid fuel pump servo C 3 coil servo 1 D
65GC Gas control valve servo C 3 coil servo 1 D
77FD Liquid fuel flow C/P Magnetic pu 3 D
77NH Speed magnetic pickup C Magnetic pu 3 D
77NT Speed magnetic pickup A/P Magnetic pu 3 D
77WN Water flow magnetic pu C Magnetic pu 4 S
90SR Gas ratio valve servo C 3 coil servo 1 D
90TV Inlet guide vane servo C 3 coil servo 1 D
96FG-2 Gas fuel control pressure C Transducer 3 D
96GC Gas control valve C LVDT 2 S
96SR Gas ratio valve C LVDT 2 S
96TV Inlet guide vane C LVDT 2 S
CTDA Compressor dischargetemperature
M TC 2 S
CTIF Compressor inlet temperature M TC 2 S
FTGI-x Fuel gas supply temperature C TC 3 D
ST-SJ-x Steam supply pressure C TC 3 D
TTWS-x GT wheelspace temperature A/P TC 2/w S
TTXD-x GT exhaust temperature C/P TC 18* D/S
* All channels/locations except one are redundant by means of two sensors per location. The non-redundantlocation has one sensor.
The number of exhaust thermocouples (TCs) varies with the gas turbine (GT) model from 13 to 27. TCs aredivided between the control modules for redundancy.
Legend: S = Shared D = Dedicated A = Alarm M = Monitor P = Protection C = Control
16 •••• Mark VI TMR Gas Turbine Control GEI-100472 Application Overview
Terminal Blocks: (24) point, barrier type terminal blocks that can be unplugged formaintenance. Each screw can terminate (2) #12 AWG (3.0mm2), 300 V insulatedwires.
Weight: 3,500 lbs. (1,587 kg.)
Type Width Depth Height
3 cabinet lineup with 1 Control Cabinet & 2 Termination Cabinets 4,200 mm 602mm 2,324mm
(Typical for 7FA) 165.4 inches 23.7 inches 91.5 inches
2 cabinet lineup with 1 Control Cabinet & 1 Termination Cabinet 2,600 mm 602mm 2,324mm
(Typical for 7EA) 102.4 inches 23.7 inches 91.5 inches
gGE Industrial Systems
General Electric Company1501 Roanoke Blvd.Salem, VA 24153-6492 USA
Issue date: 2000-07-05 2000 by General Electric Company, USA.All rights reserved.+ 1 540 387 7000www.GEindustrial.com
Power RequirementsThe control cabinet is powered from the 125 V dc battery bus and short circuitprotected in the motor control center. Both sides of the floating 125 V dc bus arecontinuously monitored with respect to ground. The 125 V dc is fuse isolated in theMark VI power distribution module and fed to the internal power supplies for thecontrol modules, the termination boards for the field contact inputs, and to thetermination boards for the turbine solenoids. Additional 3.2 A fuse protection isprovided on the termination board for each solenoid. Separate 120 V ac feeds areprovided from the motor control center for the ignition transformers. Auxiliary120/240 V ac sources can be provided for cabinet power if required. A separate UPSis required for power to the HMI and network equipment.
Control Cabinet Power
Steady-State Voltage Frequency Load Comments
125 V dc (100 to 145Vdc) 10 A dc Ripple <= 5% Add 0.5 A dc continuous for each dcsolenoid
120 V ac (105 to 132 V ac) 47 - 63Hz 15 A rms Harmonic distortion < 7% Add 6.0 A rms for a continuouslypowered ignition transformer
240 V ac (210 to 264 V ac) 47 - 63 Hz 7.5 A rms Harmonic distortion < 7 % Add 3.5 A rms for a continuouslypowered ignition transformer
Acronyms and AbbreviationsTMR Triple Modular Redundant PDH Plant Data Highway
SOE Sequence of Events PEECC Packaged Electrical and Electronic Control Compartment
LVDT Linear Variable DifferentialTransformers
GTS Global Time Source
RTD Resistance Temperature Device IRIG-B Inter-Range Instrumentation Group
UDH Unit Data Highway NTP Network Time Protocol
HMI Human-Machine Interface RTU Remote Terminal Unit
CT Current Transformer GSM GEDS Standard Messages
ADL Asynchronous Drives Language FSR Fuel Stroke Reference
