PEEDTRONICTM Mark VI for Gas Turbine Control Retrofits

gGE Industrial Systems

GEI-100538

SPEEDTRONICTM Mark VI forGas Turbine Control Retrofits

These instructions do not purport to cover all details or variations in equipment, norto provide for every possible contingency to be met during installation, operation,and maintenance. The information is supplied for informational purposes only, andGE makes no warranty as to the accuracy of the information included herein.Changes, modifications, and/or improvements to equipment and specifications aremade periodically and these changes may or may not be reflected herein. It isunderstood that GE may make changes, modifications, or improvements to theequipment referenced herein or to the document itself at any time. This document isintended for trained personnel familiar with the GE products referenced herein.

GE may have patents or pending patent applications covering subject matter in thisdocument. The furnishing of this document does not provide any license whatsoeverto any of these patents. All license inquiries should be directed to the address below.If further information is desired, or if particular problems arise that are not coveredsufficiently for the purchaser�s purpose, the matter should be referred to:

GE Industrial SystemsPost Sales Service1501 Roanoke Blvd.Salem, VA 24153-6492 USAPhone: + 1 888 GE4 SERV (888 434 7378, United States)

+ 1 540 378 3280 (International)Fax: + 1 540 387 8606 (All)(�+� indicates the international access code required when calling from outsidethe USA)

This document contains proprietary information of General Electric Company, USAand is furnished to its customer solely to assist that customer in the installation,testing, operation, and/or maintenance of the equipment described. This documentshall not be reproduced in whole or in part nor shall its contents be disclosed to anythird party without the written approval of GE Industrial Systems.

GE PROVIDES THE FOLLOWING DOCUMENT AND THE INFORMATIONINCLUDED THEREIN AS IS AND WITHOUT WARRANTY OF ANY KIND,EXPRESS OR IMPLIED, INCLUDING BUT NOT LIMITED TO ANY IMPLIEDSTATUTORY WARRANTY OF MERCHANTABILITY OR FITNESS FORPARTICULAR PURPOSE.

Issue date: 2002-02-25

2002 by General Electric Company, USA.All rights reserved.

Ethernet is a registered trademark of Xerox Corporation.Modbus is a registered trademark of Schneider Automation.CIMPLICITY is a registered trademark of GE Fanuc Automation North America, Inc.SPEEDTRONIC is a trademark of General Electric Company, USA.Microsoft and Windows are registered trademarks of Microsoft Corporation.Proximitor is a registered trademark of Bently Nevada.

2 •••• Mark VI for Gas Turbine Control Retrofits GEI-100538 Application Overview

Section PageIntroduction................................................................................................................. 2Acronyms and Abbreviations...................................................................................... 3Product Options .......................................................................................................... 3Architecture................................................................................................................. 5I/O Interface ................................................................................................................ 7Diagnostics.................................................................................................................. 9Communication........................................................................................................... 9Control Functions...................................................................................................... 11HMI........................................................................................................................... 15Typical Turbine Instumentation................................................................................ 17Packaging.................................................................................................................. 19Typical Power Requirements .................................................................................... 19

IntroductionMost existing transmitters,sensors, and switches arecompatible with the MarkVI I/O, and, in some cases,the I/O is totallycompatible.

The SPEEDTRONIC Mark VI is a fully programmable gas turbine controller withits own power supply, processor, communications, and I/O for turbine control andprotection. Critical functions, such as emergency overspeed, redundant exhaust over-temperature protection, and backup synchronous check protection are provided bythe backup protection module.

Application software is derived from current control and protection algorithms,originally designed for new gas turbines, and modified only where it is necessary forcompatibility with the existing site conditions. In addition, the controller has thespeed and capacity to implement many new advanced features such as Dry LowNOx technology. All Mark VI controllers are shipped with application software anddisplay software.

The following functions for control retrofit applications allow the Mark VI tocommunicate with existing systems in a power plant:

• Direct connect to a Distributed Control System (DCS) through Ethernet® orSerial Modbus� Slave from the Mark VI controller or Human-MachineInterface (HMI)

• Network support for distributed I/O systems

• Redundant Mark VI controller rack-power supplies for increased runningreliability in a simplex configuration

GEI-100538 Application Overview Mark VI for Gas Turbine Control Retrofits •••• 3

Acronyms and AbbreviationsADL Asynchronous Drives Language

DCS Distributed Control System

EGD Ethernet Global Data

FSR Fuel Stroke Reference

GSM GE Standard Messages

GUI Graphical User Interface

HMI Human-Machine Interface

LVDT Linear Variable Differential Transformer

PDH Plant Data Highway

rms root mean square

RTD Resistance Temperature Detector

TMR Triple Modular Redundant

UDH Unit Data Highway

UPS uninterruptible power supply

VME VERSAmodule Eurocard

Product OptionsThe Mark VI controller is available in two state-of-the-art types: simplex and TripleModular Redundant (TMR). These vary in cabinet size and I/O configurationbased on the turbine type, application (generator or mechanical drive), and I/Orequired at a particular site.

A simplex controller is available in two sizes:

• 36�x 36� (900 mm x 900 mm), which fits into the standard Mark I or Mark IIcontroller footprint

• 54�x 36� (1350 mm x 900 mm), which fits into the standard Mark II with ITScontroller footprint. This version also provides increased I/O capacity, as well asa redundant VME rack-power supply.

The standard size of the TMR unit is 54�x 36� (1350 mm x 900 mm), which fits intothe standard Mark IV controller footprint (refer to the following diagram).


PS

<R> Control Module

X

PS

Y

PS

<T> Control Module

Z

<S> Control Module

<P>Protection Module

Emergency OverspeedEmergency OvertempBackup Synch Check

ControlProtectionMonitoring

Communication from Control Module: Serial Modbus Slave Serial Modbus Master Ethernet TCP-IP Modbus Slave Ethernet UDP-IP (UDH)

AdditionalCommunications

(if required)

Devices on UDH:HMI, EX2000, Mark VI

P.S.CPUI/O

P.S.CPUI/O

P.S.CPUI/O

Ethernet - IONet

Ethernet - IONet

Ethernet - IONet

AdditionalCommunications

(if required)

TMR only

Controller with TMR


ArchitectureScalable hardware and software make the Mark VI architecture well-suited for gasturbine control retrofits.

A TMR system is generallyrecommended for base load,DLN, and cogenapplications.

The TMR and simplex versions of the Mark VI controller have equivalent controland turbine protection capabilities. The primary difference is running reliability.Running reliability is based on the percent of I/O used in the system, the percent ofI/O classified as critical, and the amount of redundancy.

TMR systems have the highest running reliability, represented by a longer MeanTime Between Forced Outage (MTBFO) than other types of controllers.

Select a TMR system when:

• Co-generation (cogen) plants where the gas turbine exhaust is the only source ofheat to generate steam for the production process and steam turbines

• Turbines are equipped with triplicated field devices, for maximized runningreliability

• Dry Low NOx (DLN) combustion system upgrades, where instrumentationstandards often require more replicated field devices than standard combustionsystems

• Generator drive applications that require continuous base-load operation

• Mechanical drive applications where compressors or pumps are critical to theproduction process

Select a simplex system when:

• Using non-base load applications that are not critical to other plant processes

• Customer operating experience indicates this system is adequate


Mark VI Simplex 36" by 36" Cabinet


I/O InterfaceTerminations support theexisting #12 AWG (3.0mm2)wires at site with barriertype terminal blocks forease of maintenance.

The Mark VI is designed for direct interface to turbine and generator devices such asvibration sensors, flame scanners, linear variable differential transformers (LVDT),magnetic speed pickups, thermocouples, and resistance temperature detectors(RTD). Direct monitoring of these sensors reduces the need for interposing deviceswith their associated single-point failures. Direct connection to a field device reduceslong-term maintenance, and enables diagnostics to directly monitor the health ofdevices mounted on the machinery.

Contact inputs are normally powered from the 125 V dc battery bus (optional 24 Vdc) through the Mark VI termination boards. Each contact input is optically isolatedand has a 1-ms time stamp for sequence-of-events (SOE) monitoring.

Terminations for existing contact inputs can be replaced 1-for-1 or split up forgreater alarm resolution. For example, instead of having several field contacts wiredto a single contact input for the Lube System Trouble alarm on the enunciatorwindow, they can be separated into multiple contact inputs to provide a separatealarm message for each problem in the lube oil system.

Diagnostics monitor thesecondary side of each fuse.

Contact outputs are from plug-in, magnetic relays with dry, Form-C, contactoutputs. Turbine solenoids are normally powered from the 125 V dc battery bus(optional 24 V dc) with suppression for each solenoid with a 3.2 A slow-blow fuseon each side of the feeder circuit.

Analog inputs 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 the MarkVI. Selected inputs can be configured for 0 � 1mA inputs (5,000 ohms) or ±5, 10 Vdc inputs. This interfaces to

• existing 0 � 1mA generator MW and MVAR transducers

• existing Dynesco-type gas fuel pressure and compressor discharge pressuretransducers with ±12 V dc supply and 0 � 5 V dc inputs

Most Mark II generator drive systems already have these transducers; however,Mark I systems do not. Compressor discharge pressure biases the temperaturecontrol system to improve turbine operation.

Analog outputs can be configured for 4 � 20 mA output (500 ohms maximum) or 0� 200 mA output (50 ohms maximum).

Thermocouple inputs can be grounded or ungrounded. Software linearization isprovided for type J and K thermocouples used on GE gas turbines plus types E, S, orT thermocouples. Existing control and overtemperature thermocouples are retainedand divided between the Mark VI controller and the backup protection module fortemperature control and overtemperature protection, respectively.

RTD inputs can be grounded or ungrounded. Software linearization is provided for10 ohm copper, 100/200 ohm platinum, or 120 ohm nickel RTDs. The generator orload compressor RTDs can be monitored directly by the Mark VI with all turbineand driven-load temperatures being collected in a common database with otherturbine-generator parameters.


Speed inputs. Redundant, passive, magnetic speed sensors provide an input to thecontrol module(s) for speed control and overspeed protection. Emergency overspeedprotection is provided electronically; mechanically on older turbines. A separatebackup protection module is provided with separate power supplies, processors, andI/O cards to provide enhanced machine protection. Overspeed detection by either theprimary or emergency electronic trip systems or the mechanical overspeed boltautomatically de-energizes the hydraulic solenoids.

Flame inputs. A direct interface is provided for ultra-violet flame scanners thatproduce a pulsed output. This eliminates any interposing transducers and enables thediagnostics to monitor the actual light level. An alarm is initiated if the light leveldiminishes below an acceptable level due to carbon or other deposits on the scannerwindow.

Integrating servo interface. The Mark VI provides a direct interface to the bipolarservo actuator and LVDT valve position feedback. Bi-polar integrating servo currentoutputs are provided in 10, 20, 40, 80, and 120 mA ranges for fuel valves and InletGuide Vane (IGV) control. Mark VI LVDT excitation is 7.0 Vrms at 3.2 kHz. Pulserate inputs are also provided for servo control loops using liquid fuel-flow, pulse-ratefeedback.

Vibration protection. A direct interface is provided for vibration protection sensors,which are required to trip the turbine. This includes seismic (velocity) type sensorsused on heavy-duty gas turbines and accelerometers on aircraft-derivative gasturbines. This eliminates the single-point failure of a separate monitoring system, andallows Mark VI diagnostics to monitor seismic sensors when the turbine is runningor stopped. Aircraft derivative applications primarily use accelerometers, whichproduce a velocity signal from external charge amplifiers. The Mark VI containsspeed-tracking filters to isolate the appropriate vibration frequencies of each shaft forthe display, alarm, and trip.

ProximitorR monitoring provides monitoring and protection for GE gas-turbineapplications. Mark VI provides a direct interface to the keyphasor, radial proximitor,and axial proximitor inputs, which are collected in a common database with turbineparameters. The fundamental (1X), first harmonic (2X), and composite vibrationsignals are collected by the Mark VI and displayed with both magnitude and phaseangle on the HMI. Active isolators provide buffered outputs to BNC connectors onthe Mark VI termination boards for temporary connection to portable analysisequipment.

The PTs are paralleled tothe backup protectionmodule for redundantbackup synch checkprotection.

Synchronizing interface includes one generator PT and one line PT to match thegenerator frequency (turbine speed) to the line frequency and match the generatorvoltage to the line voltage through commands to the generator excitation control.The Mark VI monitors actual breaker closure time and self-corrects each time thebreaker closes.


DiagnosticsMark VI diagnostics include power-up, background, and manually initiateddiagnostic routines capable of identifying both control panel, sensor, and outputdevice faults. These faults are identified down to the VME board and terminal boardlevel for the panel, and to the circuit level for sensors and actuators.

CommunicationThe Mark VI uses the following communication networks.

• I/O Net is an Ethernet-based network between a control module, the threesections of the backup protection module, and expansion I/O modules (ifrequired). I/O Net uses Asynchronous Drives Language (ADL) to poll themodules for data instead of using the typical collision detection techniques usedin Ethernet LANs.

• UDH is an Ethernet-based network that provides peer-to-peer communicationbetween the Mark VI and a GE generator excitation control. The network usesEthernet Global Data (EGD), a message-based protocol with support for sharinginformation with multiple nodes based on the UDP/IP standard. Data can betransmitted unicast or broadcast to peer controllers on a network with up to 10network nodes at 25 Hz.

Refer to the section, HMI,for information on the userinterface.

The Mark VI can communicate to a GE HMI or directly with a plant DCS networkor Plant Data Highway (PDH) through Ethernet serial Modbus slave/master,Ethernet TCP/IP Modbus slave, or Ethernet TCP/IP with GE Industrial SystemStandard Messages (GSM).

GSM is only available from a Mark VI HMI; its protocol provides

• Administration messages

• Spontaneous event-driven messages (with local time tags)

• Periodic group data messages at rates to one second

• Common request messages


EX2100

Unit Data Highway

Gas TurbineControlMark VI

GeneratorExcitation

Plant DCS

HMIOperatorStation

HMIOperatorStation

Ethernet TCP/IP GSMEthernet TCP/IP ModbusRS-232C/RS-485 Modbus

IRIG-BTime Sync

Ethernet TCP/IPModbus

RS-232C/RS-485Modbus

Plant Data Highway

Ethernet UDP/IP

Typical Network for Mark VI and EX2100 with Direct Connect to DCS Option


Control FunctionsThe control functions below are typical for a single-shaft generator drive application.Nozzle control for two-shaft machines and load compressor controls are alsosupported by Mark VI.

Startup control is an open-loop system that increases the fuel stroke reference as theturbine startup sequence progresses to preassigned plateaus.

Acceleration control adjusts the fuel stroke reference according to the rate ofchange of the turbine speed to reduce the thermal shock to the hot gas path parts ofthe 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. Separate shaft speed-control algorithms are provided for each shaftin multi-shaft machine applications. The Mark VI varies shaft speed to control realpower (megawatt) output in a mechanical (compressor or pump) drive application. Ina generator drive application, the Mark VI maintains a constant generator shaft speedto meet the electrical power demand and also controls the generator field through theuse of VAR/Power Factor (PF) control algorithms to generate excitation raise andlower commands.

Generator load control compares the load setpoint with the MW feedback from asingle-phase transducer and adjusts the speed setpoint to regulate the load. ASpinning Reserve selection allows the machine to start automatically and await anoperator input to synchronize to the grid. Selection of Fast Load Start or Pre-selected Load raises the output to the Pre-selected Load setpoint limit. Selection ofbase or peak raises this setpoint to the maximum limit.

Exhaust temperature control algorithms sort the input from each thermocouplefrom the highest to the lowest temperature. They automatically reject badthermocouple data, average the remaining data values, and execute the controlalgorithm based upon the average calculated temperature. Redundant transducersmonitor the compressor discharge pressure and bias the temperature control tocorrect for ambient conditions 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 is a reference from the governor and feedback of the fuel controlvalves. The Fuel Stroke Reference (FSR) is determined by the turbine parameter(speed, temperature, and so on) calling for the least fuel. FSR calculation occurs inthe main processor, then is transmitted to the servo valve cards on the backplane ofthe control module(s). Liquid fuel control establishes the FSR of the bypass valve.Fuel flow is proportional to the speed (Fuel Flow = Speed X FSR). Gas fuel controluses a Gas Control Valve (GCV), where fuel flow is a function of pressure (FuelFlow = Fuel Pressure X FSR). An added Stop/speed Ratio Valve (SRV) opens as aturbine speed function, so pressure becomes a function of speed and the liquid fuelcontrol system and the gas fuel control systems have the same characteristic.


Emissions control is available with diluent (water or steam) injection via a multi-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 called Dry Low NOx (DLN).

Load compressor control adjusts the turbine power output (speed) and providesvalve sequencing and surge control to optimize compressor operation.

Generator excitation control for voltage matching during synchronization andVAR/PF control after breaker closure can be integrated into the turbine control.When a reference or setpoint is entered, feedback from a single-phase VARtransducer regulates the setpoint in the Mark VI. Mark VI calculates PF from MWand MVAR inputs, or an external PF transducer can be connected to the Mark VI.Setpoints are transmitted from the turbine control to the generator excitation control.

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

Typical Dual Fuel Control System


SequencingTurbine control can include automated startup and shutdown sequences customizedto meet operator requirements, as well as control and monitoring of all gas turbineauxiliary and support systems. Operators can have the turbine automaticallysequence to intermediate hold points by selecting Crank, Fire, or Auto withoutenabling automatic synchronization. All ramp rates and time delays are pre-programmed for optimum performance. Timers and counters record long-termturbine operating information that can include:

• Total fired time

• Separate DLN operating mode timers

• Manually initiated starts

• Total starts

• Fast load starts

• Fired starts

• Emergency trips

This automation enables gas-turbine operation from a remote site with the assurancethat the turbine fully protected. Diagnostics capture a record of any abnormalconditions.

ProtectionTurbine control monitors all control and protection parameters and initiates an alarmif an abnormal condition is detected. If the condition exceeds a predefined trip level,the turbine control drives the gas/liquid control valves to a zero-flow position and de-energizes the fuel shut-off solenoids. All control, protection, and monitoringalgorithms are contained in the control modules for efficiency in sharing commondata. The protection module includes standard backup turbine protection that meetsOEM tripping reliability requirements for turbine overspeed, overtemperature, andsync-check protection.

In a typical installation, a trip solenoid is powered from the 125 V dc floating batterybus with:

� Contacts from the control module in series with the negative side of the bus

� Contacts from the backup protection module in series with the positive side ofthe bus

Additionally, diagnostic andtrip data is communicatedbetween the control moduleand the backup protectionmodules on the tripleredundant I/O Nets forcross-tripping.

Diagnostics monitor:

� Contact from each relay

� Voltage directly across the trip solenoid

Overspeed protection includes a primary overspeed monitoring system in the threecontrol modules and an emergency overspeed monitoring system in the backupprotection module that replaces the mechanical overspeed bolt used on olderturbines. The control module and each section of the backup protection modulemonitors magnetic speed sensors from 2.0 rpm on a 60-tooth wheel. Diagnosticsmonitor the speed and acceleration, then exchange the data between the controlmodule and the protection module on startup to verify that all sensors are active.


Typical gas turbine trip protection system

Trips Types

Pre-ignition Auxiliary check (Servos)

Seal oil dc motor undervoltage

dc lube oil pump undervoltage

Startup fuel flow excessive

Failure to ignite

Post-ignition Loss of flame

High exhaust temperature

Exhaust thermocouples open

Compressor bleed valve position trouble

Load tunnel temperature high

Gas fuel hydraulic pressure low

Turbine lube oil header temperature high

Turbine electronic overspeed

Protective Status Starting device trouble

Inlet guide vane trouble

Manual trip

Control speed signal lost

Exhaust pressure high

Protective speed signal trouble

Control speed signal trouble

Breaker failure trip lockout

Vibration trip

Loss of protection HP speed inputs

Customer trip

Control system fault

Low lube oil pressure

Fire indication

Generator lockout trip


HMIThe HMI or user interface is provided through a GE CIMPLICITY® graphicswindow with unit-specific screens, a Microsoft® Windows® operating system, and aControl Systems Toolbox with editors for application software. It can be applied as:

• Primary user interface for single or multiple units

• Gateway for communication links to other controllers

• Permanent or temporary maintenance station

• Engineering workstation

All control and protection is resident in the Mark VI controller, which allows theHMI to be a non-essential component. With the turbine running, it can bereinitialized or replaced with no impact on the controller. The HMI communicateswith the processor in the controller through the UDH.

Gas turbine control screens show a diagram of the turbine with the primary controlparameters. The diagram is repeated on most of the screens to provide a visual imageof the turbine�s performance while changing screens.

Typical Gas Turbine Screens

ControlScreens

MonitorScreens Auxiliaries Tests

Startup Bearingtemperature

Flame Overspeedtest

Motors Exhausttemperature

Water wash

FSR control Generator RTDs Start checkGenerator/exciter Wheelspace

temperatureTrip diagram

Synchronizing Seismic vibration TimersButtons on the right side ofall screens produce sub-menus of category-specificscreens.

The main screen is the Startup screen. Since the gas turbine control provides fullyautomatic startup including all interfaces to auxiliary systems, all basic commandsand all primary control parameters and status conditions start from this screen.

For example, the Start command can be sent to the Mark VI when Ready to Startdisplays in the startup status field. A pop-up window displays above the Start-upbutton for verification. Upon verification, the application software checks the startuppermissives and starts a sequence that displays Starting and Sequence in Progressmessages.

If startup permissives were not satisfied, the message Not Ready to Start displays,with a message in the alarm field that identifies the reason. Additionally, when theAux button is clicked and the Start Check screen is selected, it displays graphicalinformation for the Start Check/Ready to Start permissives.

A message reminds you toinvestigate the nature of thelatched trip prior to clickingMaster Reset.

Trip conditions that display in the alarm field and in the Trip Diagram are accessedby clicking the Aux button and selecting the Trip Diagram screen. A trip duringstartup causes the message Not Ready to Start.


Mark VI also allows you to change a numeric setpoint, such as Megawatts (MW) fora generator drive or Speed Reference (TNPREF) for a mechanical drive, by enteringa setpoint value rather than issuing continuous discrete raise/lower commands. TheMark VI application compares the requested setpoint with acceptable limits and thepresent output to determine a suitable ramp rate to the new target.

The Mark VI supports trending displays for comparing operating parameters. Astartup trend can be set with pre-assigned parameters, such as mean Exhaust GasTemperature (EGT), speed, maximum vibration, Compressor Discharge Pressure(CPD), and Fuel Stroke Reference (FSR). More detailed information and trending areprovided on supporting screens, along with the capability to create customizedtrends.

Typical Turbine Instrumentation


Typical Turbine InstumentationAnalog and digital devices found on a typical dual fuel gas turbine without emissionsuppression are provided in the following tables.

Analog Turbine Devices

Device Parameter Device Type

28FD Flame detector Flame scanner

39V-x Vibration sensor Velocity pickup

65FP Liquid fuel pump servo Torque motor

65GC Gas control valve servo Torque motor

65NZ Nozzle control servo (2-shaft only) Torque motor

77FD Liquid fuel flow Magnetic pickup

77NH High Pressure shaft speed Magnetic pickup

77NL Low Pressure shaft speed (2-shaft) Magnetic pickup

90SR Gas ratio valve servo Torque motor

90TV Inlet guide vane servo Torque motor

96FG-2 Gas fuel control pressure Transducer

96GC Gas control valve LVDT

96NC Nozzle control (2-shaft only) LVDT

96SR Gas ratio valve LVDT

96TV Inlet guide vane LVDT

CTDA Compressor discharge temperature Thermocouple

CTIF Compressor inlet temperature Thermocouple

TTWS-x GT wheelspace temperature Thermocouple

TTXD-x GT exhaust temperature Thermocouple


Digital Turbine Devices

Device Parameter Device Type

12HA Mechanical overspeed bolt sensor Limit switch

20FG Gas fuel trip oil Solenoid valve

20FL Liquid fuel trip oil Solenoid valve

26FD Liquid fuel temperature Temperature switch

26QA/T Lube oil temperature high alarm / trip Temperature switch

26QL/M Lube oil temperature low / moderate Temperature switch

26QN Lube oil temperature normal Temperature switch

33CS Starting clutch Limit switch

33FL Liquid fuel stop valve position Limit switch

33HR Ratchet position Limit switch

45F-x Fire detector Temperature switch

63AD Atomizing air differential pressure Pressure switch

63FD Liquid fuel pressure Pressure switch

63FG Gas fuel pressure Pressure switch

63HG Gas fuel trip oil pressure Pressure switch

63HL Liquid fuel trip oil pressure Pressure switch

63LF1 Liquid fuel filter pressure Pressure switch

63LF2 Liquid fuel forwarding filter pressure Pressure switch

63QA/T Lube oil header / bearing pressure Pressure switch

63QL Lube oil pressure Pressure switch

63TF Inlet filter pressure Pressure switch

71QH Lube tank high level Pressure switch

71QL Lube tank low level Level switch

71WL Water tank low level Level switch


PackagingMark VI packages can be customized to meet any site requirement. Package optionsthat fit into the Mark I, Mark II and Mark IV footprints are shown below.

Component Description

Card Backplane VME type (VERSA module Eurocard)

Cabinet NEMA 1 convection cooled, similar to IP-20

Cable Entrance Top and/or bottom

Material Sheet steel

Terminal Blocks 24-point, barrier type terminal blocks that can be unpluggedfor maintenance. Each screw can terminate two #12 AWG(3.0 mm2), 300-volt insulated wires.

Width Depth Height Weight

36" (900 mm) 36" (900 mm) 91.5"(2,324 mm)

1300 lbs(590 kg)

Dimensions- Cabinet Option #1

- Cabinet Option #254" (1350 mm) 36" (900 mm) 91.5"

(2,324 mm)1600 lbs(725 kg)

g GE Industrial Systems

General Electric Company1501 Roanoke Blvd.Salem, VA 24153-6492 USA

+1 540 387 7000www.GEindustrial.com

Typical Power RequirementsThe control cabinet is powered from a 125 V dc battery bus that is normally short-circuit protected in the motor control center. Both sides of the floating 125 V dc busare continuously monitored for grounding. A floating bus eliminates the need for thedc ground relay and dc under-voltage relay present in older controllers. The 125 V dcbus is fuse-isolated in the Mark VI power distribution module and sent to:

• VME rack power supply for each control module

• Termination boards for the field contact inputs and the turbine solenoidsA separateuninterruptible powersupply (UPS) is requiredto power the HMI andnetwork equipment.

Additional 3.2 A fuse protection is provided on the termination board for eachsolenoid. A 120 V ac feed is provided for ignition transformers. Control cabinetpower specifications are shown below.

Steady-state Voltage Frequency Load Comments

125 V dc (100 to 145 V dc) 10 A dc Ripple <= 5% (Add 0.5 A dc continuous for each dcsolenoid.)

120 V ac (105 to 132 V ac) 47 - 63 Hz 15 A rms Harmonic distortion < 7% (Add 6.0 A rms for acontinuously powered 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 acontinuously powered ignition transformer.)

Documents

PEEDTRONICTM Mark VI for Gas Turbine Control Retrofits