ger 4193 - mark vi

GE Power Systems

SPEEDTRONICMark VI Turbine Control System

Walter BarkerMichael CroninGE Power SystemsSchenectady, NY

GER-4193A

g

Contents

Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1Architecture. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1Triple Redundancy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2I/O Interface. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3General Purpose I/O . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3Application Specific I/O. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4Operator Interface . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7Software Maintenance Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8Communications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8

Communication Link Options. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Time Synchronization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Diagnostics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11Codes and Standards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12

Safety Standards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Printed Wire Board Assemblies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12CE Electromagnetic Compatibility (EMC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12CE Low Voltage Directive . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12

Environment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Temperature . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Humidity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12Elevation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Gas Contaminants . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Dust Contaminants . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Seismic Universal Building Code (UBC). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13

Documentation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Manuals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13Drawings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13

List of Figures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14List of Tables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14

SPEEDTRONIC Mark VI Turbine Control System

GE Power Systems GER-4193A (10/00) i


GE Power Systems GER-4193A (10/00) ii

IntroductionThe SPEEDTRONIC Mark VI turbine controlis the current state-of-the-art control for GE tur-bines that have a heritage of more than 30 yearsof successful operation. It is designed as a com-plete integrated control, protection, and moni-toring system for generator and mechanicaldrive applications of gas and steam turbines. It isalso an ideal platform for integrating all powerisland and balance-of-plant controls. Hardwareand software are designed with close coordina-tion between GEs turbine design engineeringand controls engineering to insure that your con-trol system provides the optimum turbine per-formance and you receive a true system solu-tion. With Mark VI, you receive the benefits ofGEs unmatched experience with an advancedturbine control platform. (See Figure 1.)

ArchitectureThe heart of the control system is the ControlModule, which is available in either a 13- or 21-slot standard VME card rack. Inputs arereceived by the Control Module through termi-nation boards with either barrier or box-typeterminal blocks and passive signal conditioning.

Each I/O card contains a TMS320C32 DSPprocessor to digitally filter the data before con-version to 32 bit IEEE-854 floating point format.The data is then placed in dual port memorythat is accessible by the on-board C32 DSP onone side and the VME bus on the other.

In addition to the I/O cards, the ControlModule contains an internal communicationcard, a main processor card, and sometimes aflash disk card. Each card takes one slot exceptfor the main processor that takes two slots.Cards are manufactured with surface-mountedtechnology and conformal coated per IPC-CC-830.

I/O data is transmitted on the VME backplanebetween the I/O cards and the VCMI cardlocated in slot 1. The VCMI is used for inter-nal communications between:

I/O cards that are contained within itscard rack

I/O cards that may be contained inexpansion I/O racks called InterfaceModules

I/O in backup ProtectionModules

I/O in other Control Modules used intriple redundant controlconfigurations

The main processor cardThe main processor card executes the bulk ofthe application software at 10, 20, or 40 msdepending on the requirements of the applica-tion. Since most applications require that spe-


GE Power Systems GER-4193A (10/00) 1

Figure 1. Benefits of Speedtronic Mark VI

Over 30 years experience

Complete control, protection, andmonitoring

Can be used in variety of applications

Designed by GE turbine and controlsengineering

cific parts of the control run at faster rates (i.e.servo loops, pyrometers, etc.), the distributedprocessor system between the main processorand the dedicated I/O processors is very impor-tant for optimum system performance. A QNXoperating system is used for real-time applica-tions with multi-tasking, priority-driven preemp-tive scheduling, and fast-context switching.

Communication of data between the ControlModule and other modules within the Mark VIcontrol system is performed on IONet. TheVCMI card in the Control Module is the IONetbus master communicating on an Ethernet10Base2 network to slave stations. A unique pol-ing type protocol (Asynchronous DrivesLanguage) is used to make the IONet moredeterministic than traditional Ethernet LANs.An optional Genius Bus interface can be pro-vided on the main processor card in Mark VISimplex controls for communication with theGE Fanuc family of remote I/O blocks. Theseblocks can be selected with the same softwareconfiguration tools that select Mark VI I/Ocards, and the data is resident in the same data-base.

The Control Module is used for control, pro-tection, and monitoring functions, but someapplications require backup protection. Forexample, backup emergency overspeed protec-tion is always provided for turbines that do nothave a mechanical overspeed bolt, and backupsynch check protection is commonly providedfor generator drives. In these applications, theIONet is extended to a Backup ProtectionModule that is available in Simplex and tripleredundant forms. The triple redundant versioncontains three independent sections (powersupply, processor, I/O) that can be replacedwhile the turbine is running. IONet is used toaccess diagnostic data or for cross-trippingbetween the Control Module and the

Protection Module, but it is not required fortripping.

Triple RedundancyMark VI control systems are available inSimplex and Triple Redundant forms for smallapplications and large integrated systems withcontrol ranging from a single module to manydistributed modules. The name Triple ModuleRedundant (TMR) is derived from the basicarchitecture with three completely separate andindependent Control Modules, power supplies,and IONets. Mark VI is the third generation oftriple redundant control systems that were pio-neered by GE in 1983. System throughputenables operation of up to nine, 21-slot VMEracks of I/O cards at 40 ms including voting thedata. Inputs are voted in software in a schemecalled Software Implemented Fault Tolerance(SIFT). The VCMI card in each ControlModule receives inputs from the ControlModule back-plane and other modules via itsown IONet.

Data from the VCMI cards in each of the threeControl Modules is then exchanged and votedprior to transmitting the data to the mainprocessor cards for execution of the applicationsoftware. Output voting is extended to the tur-bine with three coil servos for control valves and2 out of 3 relays for critical outputs such ashydraulic trip solenoids. Other forms of outputvoting are available, including a median selectof 4-20ma outputs for process control and 0-200ma outputs for positioners.

Sensor interface for TMR controls can be eithersingle, dual, triple redundant, or combinationsof redundancy levels. The TMR architecturesupports riding through a single point failure inthe electronics and repair of the defective cardor module while the process is running. Addingsensor redundancy increases the fault tolerance



of the overall system. Another TMR feature isthe ability to distinguish between field sensorfaults and internal electronics faults.Diagnostics continuously monitor the 3 sets ofinput electronics and alarms any discrepanciesbetween them as an internal fault versus a sen-sor fault. In addition, all three main processorscontinue to execute the correct voted inputdata. (See Figure 2.)

I/O InterfaceThere are two types of termination boards. Onetype has two 24-point, barrier-type terminalblocks that can be unplugged for field mainte-nance. These are available for Simplex andTMR controls. They can accept two 3.0 mm2

(#12AWG) wires with 300 volt insulation.Another type of termination board used onSimplex controls is mounted on a DIN rail and

has one, fixed, box-type terminal block. It canaccept one 3.0 mm2 (#12AWG) wire or two 2.0mm2 (#14AWG) wires with 300 volt insulation.

I/O devices on the equipment can be mountedup to 300 meters (984 feet) from the termina-tion boards, and the termination boards mustbe within 15 m (49.2) from their correspon-ding I/O cards. Normally, the terminationboards are mounted in vertical columns in ter-mination cabinets with pre-assigned cablelengths and routing to minimize exposure toemi-rfi for noise sensitive signals such as speedinputs and servo loops.

General Purpose I/ODiscrete I/O. A VCRC card provides 48 digitalinputs and 24 digital outputs. The I/O is divid-ed between 2 Termination Boards for the con-tact inputs and another 2 for the relay outputs.(See Table 1.)

Analog I/O. A VAIC card provides 20 analoginputs and 4 analog outputs. The I/O is dividedbetween 2 Termination Boards. A VAOC is ded-icated to 16 analog outputs and interfaces with1 barrier-type Termination Board or 2 box-typeTermination Boards. (See Table 2.)

Temperature Monitoring. A VTCC card pro-vides interface to 24 thermocouples, and aVRTD card provides interface for 16 RTDs. Theinput cards interface with 1 barrier-type



PS

Control Module

X

PS

Y

PS

Control Module

Z

Control Module

Ethernet

Protection Module

Backup Protection1. Emergency Overspeed2. Synch Check Protection

Primary Controllers 1. Control 2. Protection 3. Monitoring

CIMPLICITY R Display SystemWindows NT TM Operating System

Ethernet

Unit Data Highway

Operator / MaintenanceInterface

Communications To DCS1. RS232 Modbus Slave/Master2. Ethernet TCP-IP Modbus Slave3. Ethernet TCP-IP GSM

Redundant UnitData Highway(if required)

To Other GEControl Systems

P.S.CPUI/O

P.S.CPUI/O

P.S.CPUI/O

Ethernet - IONet

Softw

are

Votin

g

Ethernet - IONet

Ethernet - IONet

Figure 2. Mark VI TMR control configurationTB Type I/O Characteristics

TBCI Barrier 24 CI 70-145Vdc, optical isolation, 1ms SOE

2.5ma/point except last 3 input are 10ma / point

DTCI Box 24 CI 18-32Vdc, optical isolation, 1ms SOE

2.5ma/point except last 3 input are 10ma/point

TICI Barrier 24 CI 70-145Vdc, 200-250Vdc, 90-132Vrms, 190-264Vrms(47-63Hz), optical isolation 1ms SOE, 3ma / point

TRLY Barrier 12 CO Plug-in, magnetic relays, dry, form C contacts

6 circuits with fused 3.2A, suppressed solenoid outputs

Form H1B: diagnostics for coil currentForm H1C: diagnostics for contact voltage

Voltage Resistive Inductive

24Vdc 3.0A 3.0 amps L/R = 7 ms, no suppr. 3.0 amps L/R = 100 ms, with suppr

125Vdc 0.6A 0.2 amps L/R = 7 ms, no suppr.

0.6 amps L/R = 100 ms, with suppr

120/240Vac 6/3A 2.0 amps pf = 0.4

DRLY Box 12 CO Same as TRLY, but no solenoid circuits

Table 1. Discrete I/O

To Other GEControl Systems

Redundant UnitData Highway

(Required)

Control Module

Control Module

Control Module

P.S.CPUI/O

P.S.CPUI/O

P.S.CPUI/O

Protection Module

Communications to DCS1. RS232 Modbus Slave/Master2. Ethernet TCP-IP Modbus Slave3. Ethernet TCP-IPGSM

Primary Controllers1. Control2. Protection3. Monitoring

Backup Protection1. Emergency Overspeed2. Synch Check Protection

Operator MaintenanceInterface

Unit Data Highway

Ethernet

Ethernet

Ethernet - IONet

Softw

are

Votin

g

Ethernet - IONet

Ethernet - IONet

CIMPLICITY Display SystemWindows NT Operating System

Termination Board or 2 box-type TerminationBoards. Capacity for monitoring 9 additionalthermocouples is provided in the BackupProtection Module. (See Table 3.)

Application Specific I/OIn addition to general purpose I/O, the MarkVI has a large variety of cards that are designedfor direct interface to unique sensors and actu-ators. This reduces or eliminates a substantialamount of interposing instrumentation inmany applications. As a result, many potentialsingle-point failures are eliminated in the mostcritical area for improved running reliabilityand reduced long-term maintenance. Directinterface to the sensors and actuators alsoenables the diagnostics to directly interrogatethe devices on the equipment for maximumeffectiveness. This data is used to analyze deviceand system performance. A subtle benefit ofthis design is that spare-parts inventories are

reduced by eliminating peripheral instrumenta-tion. The VTUR card is designed to integrateseveral of the unique sensor interfaces used inturbine control systems on a single card. Insome applications, it works in conjunction withthe I/O interface in the Backup ProtectionModule described below.

Speed (Pulse Rate) Inputs. Four-speed inputsfrom passive magnetic sensors are monitored bythe VTUR card. Another two-speed (pulse rate)inputs can be monitored by the servo cardVSVO which can interface with either passive oractive speed sensors. Pulse rate inputs on theVSVO are commonly used for flow-divider feed-back in servo loops. The frequency range is 2-14k Hz with sufficient sensitivity at 2 Hz todetect zero speed from a 60-toothed wheel. Twoadditional passive speed sensors can be moni-tored by each of the three sections of theBackup Protection Module used for emergencyoverspeed protection on turbines that do nothave a mechanical overspeed bolt. IONet isused to communicate diagnostic and processdata between the Backup Protection Moduleand the Control Module(s) including cross-trip-ping capability; however, both modules will ini-tiate system trips independent of the IONet.(See Table 4 and Table 5.)

Synchronizing. The synchronizing system con-sists of automatic synchronizing, manual syn-chronizing, and backup synch check protec-tion. Two single-phase PT inputs are provided



Analog I/O

TB Type I/O Characteristics

TBAI Barrier 10 AI

2 AO

(8) 4-20ma (250 ohms) or +/-5,10Vdc inputs

(2) 4-20ma (250 ohms) or +/-1ma (500 ohms) inputs

Current limited +24Vdc provided per input

(2) +24V, 0.2A current limited power sources

(1) 4-20ma output (500 ohms)

(1) 4-20ma (500 ohms) or 0-200ma (50 ohms) output

TBAO Barrier 16 AO (16) 4-20ma outputs (500 ohms)

DTAI Box 10 AI

2 AO

(8) 4-20ma (250 ohms) or +/-5,10Vdc inputs

(2) 4-20ma (250 ohms) or +/-1ma (500 ohms) inputs

Current limited +24Vdc available per input(1) 4-20ma output (500 ohms)

(1) 4-20ma (500 ohms) or 0-200ma (50 ohms) output

DTAO Box 8 AO (8) 4-20ma outputs (500 ohms)

Table 2. Analog I/O

VTUR I/O Terminations from Control Module


TTUR Barrier 4 Pulse rate

2 PTs

Synch relays

2 SVM

Passive magnetic speed sensors (2-14k Hz)

Single phase PTs for synchronizing

Auto/Manual synchronizing interface

Shaft voltage / current monitor

TRPG*

TRPS*TRPL*

Barrier 3 Trip solenoids

8 Flame inputs

(-) side of interface to hydraulic trip solenoids

UV flame scanner inputs (Honeywell)

DTUR Box 4 Pulse Rate Passive magnetic speed sensors (2-14k Hz)

DRLY

DTRT

Box 12 Relays Form C contacts previously described

Transition board between VTUR & DRLY

Table 4. VTUR I/O terminations from ControlModule

Temperature Monitoring


TBTC Barrier 24 TC Types: E, J, K, T, grounded or ungrounded

H1A fanned (paralleled) inputs, H1B dedicated inputs

DTTC Box 12 TC Types: E, J, K, T, grounded or ungrounded

TRTD Barrier 16 RTD 3 points/RTD, grounded or ungrounded

10 ohm copper, 100/200 ohm platinum, 120 ohm nick

H1A fanned (paralleled) inputs, H1B dedicated inputs

DTAI Box 8 RTD RTDs, 3 points/RTD, grounded or ungrounded

10 ohm copper, 100/200 ohm platinum, 120 ohm nick

Table 3. Temperature Monitoring

on the TTUR Termination Board to monitorthe generator and line busses via the VTURcard. Turbine speed is matched to the line fre-quency, and the generator and line voltages arematched prior to giving a command to close thebreaker via the TTUR.

An external synch check relay is connected inseries with the internal K25P synch permissiverelay and the K25 auto synch relay via theTTUR. Feedback of the actual breaker closingtime is provided by a 52G/a contact from thegenerator breaker (not an auxiliary relay) toupdate the database. An internal K25A synchcheck relay is provided on the TTUR; however,the backup phase / slip calculation for this relayis performed in the Backup Protection Moduleor via an external backup synch check relay.Manual synchronizing is available from an oper-ator station on the network or from a synchro-scope.

Shaft Voltage and Current Monitor. Voltage canbuild up across the oil film of bearings until adischarge occurs. Repeated discharge and arc-ing can cause a pitted and roughened bearingsurface that will eventually fail through acceler-ated mechanical wear. The VTUR / TTUR cancontinuously monitor the shaft-to- ground volt-age and current, and alarm at excessive levels.Test circuits are provided to check the alarmfunctions and the continuity of wiring to thebrush assembly that is mounted between theturbine and the generator.

Flame Detection. The existence of flame eithercan be calculated from turbine parameters thatare already being monitored or from a directinterface to Reuter Stokes or Honeywell-typeflame detectors. These detectors monitor theflame in the combustion chamber by detectingUV radiation emitted by the flame. The ReuterStokes detectors produce a 4-20ma input. ForHoneywell flame scanners, the Mark VI suppliesthe 335Vdc excitation and the VTUR / TRPGmonitors the pulses of current being generated.This determines if carbon buildup or othercontaminates on the scanner window are caus-ing reduced light detection.

Trip System. On turbines that do not have amechanical overspeed bolt, the control canissue a trip command either from the mainprocessor card to the VTUR card in the ControlModule(s) or from the Backup ProtectionModule. Hydraulic trip solenoids are wired withthe negative side of the 24Vdc/125Vdc circuitconnected to the TRPG, which is driven fromthe VTUR in the Control Module(s) and thepositive side connected to the TREG which isdriven from the VPRO in each section of theBackup Protection Module. A typical system tripinitiated in the Control Module(s) will causethe analog control to drive the servo valve actu-ators closed, which stops fuel or steam flow andde-energizes (or energizes) the hydraulic tripsolenoids from the VTUR and TRPG. If cross-tripping is used or an overspeed condition isdetected, then the VTUR/TRPG will trip oneside of the solenoids and the VPTRO/TREGwill trip the other side of the solenoid(s).

Servo Valve Interface. A VSVO card provides 4servo channels with selectable current drivers,feedback from LVDTs, LVDRs, or ratio metricLVDTs, and pulse-rate inputs from flow dividerfeedback used on some liquid fuel systems. InTMR applications, 3 coil servos are commonly



VPRO I/O Terminations from Backup Protection Module


TPRO Barrier 9 Pulse rate

2 PTs

3 Analog inputs

9 TC inputs

Passive magnetic speed sensors (2-14k Hz)

Single phase PTs for backup synch check

(1) 4-20ma (250 ohm) or +/-5,10Vdc inputs(2) 4-20ma (250 ohm)

Thermocouples, grounded or ungrounded

TREG*

TRES*

TREL*

Barrier 3 Trip solenoids

8 Trip contact in

(+) side of interface to hydraulic trip solenoids

1 E-stop (24Vdc) & 7 Manual trips (125Vdc)

Table 5. VPRO I/O terminations from BackupProtection Module

used to extend the voting of analog outs to theservo coils. Two coil servos can also be used.One, two, or three LVDT/Rs feedback sensorscan be used per servo channel with a high select,low select, or median select made in software. Atleast 2 LVDT/Rs are recommended for TMRapplications because each sensor requires an ACexcitation source. (See Table 6 and Table 7.)

Vibration / Proximitor Inputs. The VVIB cardprovides a direct interface to seismic (velocity),Proximitor, Velomitor, and accelerometer(via charge amplifier) probes. In addition, DCposition inputs are available for axial measure-ments and Keyphasor inputs are provided.Displays show the 1X and unfiltered vibrationlevels and the 1X vibration phase angle. -24vdcis supplied from the control to each Proximitorwith current limiting per point. An optional ter-

mination board can be provided with active iso-lation amplifiers to buffer the sensor signalsfrom BNC connectors. These connectors can beused to access real-time data by remote vibra-tion analysis equipment. In addition, a directplug connection is available from the termina-tion board to a Bently Nevada 3500 monitor.The 16 vibration inputs, 8 DC position inputs,and 2 Keyphasor inputs on the VVIB are divid-ed between 2 TVIB termination boards for3,000 rpm and 3,600 rpm applications. Fastershaft speeds may require faster sampling rateson the VVIB processor, resulting in reducedvibration inputs from 16-to-8. (See Table 8.)

Three phase PT and CT monitoring. The VGENcard serves a dual role as an interface for 3phase PTs and 1 phase CTs as well as a special-ized control for Power-Load Unbalance andEarly-Valve Actuation on large reheat steam tur-bines. The I/O interface is split between theTGEN Termination Board for the PT and CTinputs and the TRLY Termination Board forrelay outputs to the fast acting solenoids. 4-20ma inputs are also provided on the TGEN formonitoring pressure transducers. If an EX2000Generator Excitation System is controlling thegenerator, then 3 phase PT and CT data is com-municated to the Mark VI on the networkrather than using the VGEN card. (See Table 9.)

Optical Pyrometer Inputs. The VPYR card moni-




TSVO Barrier 2 chnls. (2) Servo current sources

(6) LVDT/LVDR feedback

0 to 7.0 Vrms

(4) Excitation sources

7 Vrms, 3.2k Hz

(2) Pulse rate inputs (2-14k Hz) *only 2 per VSVO

DSVO Box 2 chnls. (2) Servo current sources

(6) LVDT/LVDR feedback 0 to 7.0 Vrms


7 Vrms, 3.2k Hz

(2) Pulse rate inputs (2-14k Hz)

*only 2 per VSVO


TSVO Barrier 2 chnls. (2) Servo current sources

(6) LVDT/LVDR feedback

0 to 7.0 Vrms


7 Vrms, 3.2k Hz

(2) Pulse rate inputs (2-14k Hz) *only 2 per VSVO

DSVO Box 2 chnls. (2) Servo current sources

(6) LVDT/LVDR feedback 0 to 7.0 Vrms


7 Vrms, 3.2k Hz

(2) Pulse rate inputs (2-14k Hz)

*only 2 per VSVO

Table 6. VSVO I/O terminations from Control Module

VVIB I/O Terminations from Control Module


TVIB Barrier 8 Vibr.

4 Pos.

1 KP

Seismic, Proximitor,Velomitor, accelerometercharge amplifier

DC inputs

Keyphasor

Current limited 24Vdc

provided per probe

Table 8. VVIB I/O terminations from ControlModule

Nominal Servo Valve Ratings

CoilType

NominalCurrent

CoilResistance

Mark VIControl

#1 +/- 10 ma 1,000 ohms Simplex & TMR

#2 +/- 20 ma 125 ohms Simplex


#4 +/- 40 ma 89 ohms TMR

#5 +/- 80 ma 22 ohms TMR


#7 +/- 120 ma 75 ohms TMR

Table 7. Nominal servo valve ratings

tors two LAND infrared pyrometers to create atemperature profile of rotating turbine blades.Separate, current limited +24Vdc and 24Vdcsources are provided for each Pyrometer thatreturns four 4-20ma inputs. Two Keyphasors areused for the shaft reference. The VPYR andmatching TPYR support 5,100 rpm shaft speedsand can be configured to monitor up to 92 buck-ets with 30 samples per bucket. (See Table 10.)

Operator InterfaceThe operator interface is commonly referred toas the Human Machine Interface (HMI). It is aPC with a Microsoft Windows NT operatingsystem supporting client/server capability, aCIMPLICITY graphics display system, aControl System Toolbox for maintenance, and asoftware interface for the Mark VI and othercontrol systems on the network. (See Figure 3.)It can be applied as:

The primary operator interface forone or multiple units

A backup operator interface to theplant DCS operator interface

A gateway for communication links toother control systems

A permanent or temporarymaintenance station

An engineers workstation

All control and protection is resident in theMark VI control, which allows the HMI to be anon-essential component of the control system.It can be reinitialized or replaced with theprocess running with no impact on the controlsystem. The HMI communicates with the mainprocessor card in the Control Module via theEthernet based Unit Data Highway (UDH). Allanalog and digital data in the Mark VI is acces-sible for HMI screens including the high reso-lution time tags for alarms and events.

System (process) alarms and diagnostics alarmsfor fault conditions are time tagged at framerate (10/20/40 ms) in the Mark VI control andtransmitted to the HMI alarm management sys-tem. System events are time tagged at framerate, and Sequence of Events (SOE) for contactinputs are time tagged at 1ms on the contactinput card in the Control Module. Alarms can




TGEN Barrier 2 PTs

3 CTs

4 AI

3 Phase PTs, 115Vrms

5-66 Hz, 3 wire, open delta

1 Phase CTs, 0-5A(10A over range) 5-66 Hz

4-20ma (250 ohms)

or +/-5,10Vdc inputsCurrent limited +24Vdc/input

TRLY Barrier 12 CO Plug-in magnetic relays

previously described

Table 9. VGEN I/O terminations from ControlModule

Figure 3. Operator interface graphics: 7FA Mark VI


TPYR Barrier 2 Pyrometers (8) 4-20ma (100 ohms)

(2) Current limited

+24Vdc sources(2) Current limited

-24Vdc sources

(2) Keyphasor inputs

Table 10. VPYR I/O terminations from Control Module

be sorted according to ID, Resource, Device,Time, and Priority. Operators can add com-ments to alarm messages or link specific alarmmessages to supporting graphics.

Data is displayed in either English or Metricengineering units with a one-second refreshrate and a maximum of one second to repaint atypical display graphic. Operator commandscan be issued by either incrementing / decre-menting a setpoint or entering a numericalvalue for the new setpoint. Responses to thesecommands can be observed on the screen onesecond from the time the command was issued.Security for HMI users is important to restrictaccess to certain maintenance functions such aseditors and tuning capability, and to limit cer-tain operations. A system called UserAccounts is provided to limit access or use ofparticular HMI features. This is done throughthe Windows NT User Manager administrationprogram that supports five user account levels.

Software Maintenance ToolsThe Mark VI is a fully programmable controlsystem. Application software is created from in-house software automation tools which selectproven GE control and protection algorithmsand integrate them with the I/O, sequencing,and displays for each application. A library ofsoftware is provided with general-purposeblocks, math blocks, macros, and applicationspecific blocks. It uses 32-bit floating point data(IEEE-854) in a QNX operating system withreal-time applications, multitasking, priority-driven preemptive scheduling, and fast contextswitching.

Software frame rates of 10, 20, and 40 ms aresupported. This is the elapsed time that it takesto read inputs, condition the inputs, executethe application software, and send outputs.Changes to the application software can be

made with password protection (5 levels) anddownloaded to the Control Module while theprocess is running. All application software isstored in the Control Module in non-volatileflash memory.

Application software is executed sequentiallyand represented in its dynamic state in a ladderdiagram format. Maintenance personnel canadd, delete, or change analog loops, sequenc-ing logic, tuning constants, etc. Data points canbe selected and dragged on the screen fromone block to another to simplify editing. Otherfeatures include logic forcing, analog forcing,and trending at frame rate. Application soft-ware documentation is created directly fromthe source code and printed at the site. Thisincludes the primary elementary diagram, I/Oassignments, the settings of tuning constants,etc. The software maintenance tools (ControlSystem Toolbox) are available in the HMI andas a separate software package for virtually anyWindows 95 or NT based PC. The same toolsare used for EX2000 Generator ExcitationSystems, and Static Starters. (See Figure 4 andFigure 5.)

CommunicationsCommunications are provided for internal datatransfer within a single Mark VI control; com-munications between Mark VI controls andpeer GE control systems; and external commu-nications to remote systems such as a plant dis-tributed control system (DCS).

The Unit Data Highway (UDH) is an Ethernet-based LAN with peer-to-peer communicationbetween Mark VI controls, EX2000 GeneratorExcitation Controls, Static Starters, the GEFanuc family of PLC based controls, HMIs, andHistorians. The network uses Ethernet GlobalData (EGD) which is a message-based protocolwith support for sharing information with mul-



tiple nodes based on the UDP/IP standard(RFC 768). Data can be transmitted Unicast,Multicast or Broadcast to peer control systems.Data (4K) can be shared with up to 10 nodes at25Hz (40ms). A variety of other proprietaryprotocols are used with EGD to optimize com-munication performance on the UDH.

40 ms is fast enough to close control loops onthe UDH; however, control loops are normallyclosed within each unit control. Variations ofthis exist, such as transmitting setpointsbetween turbine controls and generator con-trols for voltage matching and var/power-factor

control. All trips between units are hardwiredeven if the UDH is redundant.

The UDH communication driver is located onthe Main Processor Card in the Mark VI. This isthe same card that executes the turbine appli-cation software; therefore, there are no poten-tial communication failure points between themain turbine processor and other controls ormonitoring systems on the UDH. In TMR sys-tems, there are three separate processor cardsexecuting identical application software fromidentical databases. Two of the UDH drivers arenormally connected to one switch, and theother UDH driver is connected to the otherswitch in a star configuration. Network topolo-gies conform to Ethernet IEEE 802.3 standards.

The GE networks are a Class C PrivateInternet according to RFC 1918: AddressAllocation for Private Internets February1996. Internet Assigned Numbers Authority(IANA) has reserved the following IP addressspace 192.168.1.1: 192.168.255.255 (192.168/16 prefix).

Communication links from the Mark VI toremote computers can be implemented fromeither an optional RS232 Modbus port on themain processor card in Simplex systems, orfrom a variety of communication drivers fromthe HMI. When the HMI is used for the com-munication interface, an Ethernet card in theHMI provides an interface to the UDH, and asecond Ethernet card provides an interface tothe remote computer.

All operator commands that can be issued froman HMI can be issued from a remote computerthrough the HMI(s) to the Mark VI(s), and theremote computer can monitor any applicationsoftware data in the Mark VI(s). Approximately500 data points per control are of interest to aplant control system; however, about 1,200



Figure 4. Software maintenance tools card configuration

Relay Ladder Diagram Editorfor Boolean Functions

Figure 5. Software maintenance tools editors

points are commonly accessed through thecommunication links to support programmingscreen attributes such as changing the color ofa valve when it opens.

Communication Link Options Communication link options include:

An RS-232 port with Modbus SlaveRTU or ASCII communications fromthe Main Processor Card. (Simplex:full capability. TMR: monitor data only no commands)

An RS-232 port with Modbus Master /Slave RTU protocol is available fromthe HMI.

An RS-232/485 converter (half-duplex) can be supplied to convertthe RS-232 link for a multi-dropnetwork.

Modbus protocol can be supplied onan Ethernet physical layer with TCP-IPfor faster communication rates fromthe HMI.

Ethernet TCP-IP can be supplied witha GSM application layer to support thetransmission of the local high-resolution time tags in the control to aDCS from the HMI. This link offersspontaneous transmission of alarmsand events, and common requestmessages that can be sent to the HMIincluding control commands andalarm queue commands. Typicalcommands include momentary logicalcommands and analog setpointtarget commands. Alarm queuecommands consist of silence (plantalarm horn) and reset commands aswell as alarm dump requests that causethe entire alarm queue to betransmitted from the Mark VI to theDCS.

Additional master communicationdrivers are available from the HMI.

Time SynchronizationTime synchronization is available to synchro-nize all controls and HMIs on the UDH to aGlobal Time Source (GTS). Typical GTSs areGlobal Positioning Satellite (GPS) receiverssuch as the StarTime GPS Clock or other time-processing hardware. The preferred timesources are Universal Time Coordinated (UTC)or GPS; however, the time synchronizationoption also supports a GTS using local time asits base time reference. The GTS supplies atime-link network to one or more HMIs with atime/frequency processor board. When theHMI receives the time signal, it is sent to theMark VI(s) using Network Time Protocol(NTP) which synchronizes the units to within+/-1ms time coherence. Time sources that aresupported include IRIG-A, IRIG-B, 2137, NASA-36, and local signals.

DiagnosticsEach circuit card in the Control Module con-tains system (software) limit checking, high/low(hardware) limit checking, and comprehensivediagnostics for abnormal hardware conditions.System limit checking consists of 2 limits forevery analog input signal, which can be set inengineering units for high/high, high/low, orlow/low with the I/O Configurator. In addition,each input limit can be set for latching/non-latching and enable/disable. Logic outputsfrom system limit checking are generated perframe and are available in the database (signalspace) for use in control sequencing and alarmmessages.

High/low (hardware) limit checking is provid-ed on each analog input with typically 2 occur-rences required before initiating an alarm.These limits are not configurable, and they are



selected to be outside the normal controlrequirements range but inside the linear hard-ware operational range (before the hardwarereaches saturation). Diagnostic messages forhardware limit checks and all other hardwarediagnostics for the card can be accessed withthe software maintenance tools (Control SystemToolbox). A composite logic output is providedin the data base for each card, and anotherlogic output is provided to indicate a high/low(hardware) limit fault of any analog input orthe associated communications for that signal.

The alarm management system collects andtime stamps the diagnostic alarm messages atframe rate in the Control Module and displaysthe alarms on the HMI. Communication linksto a plant DCS can contain both the software(system) diagnostics and composite hardwarediagnostics with varying degrees of capabilitydepending on the protocols ability to transmitthe local time tags. Separate manual reset com-mands are required for hardware and system(software) diagnostic alarms assuming that thealarms were originally designated as latchingalarms, and no alarms will reset if the originalcause of the alarm is still present.

Hardware diagnostic alarms are displayed onthe yellow status LED on the card front. Eachcard front includes 3 LEDs and a reset at thetop of the card along with serial and parallelports. The LEDs include: RUN: Green; FAIL:Red; STATUS: Yellow.

Each circuit card and termination board in thesystem contains a serial number, board type,and hardware revision that can be displayed; 37pin D type connector cables are used to inter-face between the Termination Boards and theJ3 and J4 connectors on the bottom of theControl Module. Each connector comes withlatching fasteners and a unique label identify-

ing the correct termination point. One wire ineach connector is dedicated to transmitting anidentification message with a bar-code serialnumber, board type, hardware revision, and aconnection location to the corresponding I/Ocard in the Control Module.

PowerIn many applications, the control cabinet ispowered from a 125Vdc battery system andshort circuit protected external to the control.Both sides of the floating 125Vdc bus are con-tinuously monitored with respect to ground,and a diagnostic alarm is initiated if a ground isdetected on either side of the 125Vdc source.

When a 120/240vac source is used, a powerconverter isolates the source with an isolationtransformer and rectifies it to 125Vdc. A diodehigh select circuit chooses the highest of the125Vdc busses to distribute to the PowerDistribution Module. A second 120/240vacsource can be provided for redundancy.Diagnostics produce an under-voltage alarm ifeither of the AC sources drop below the under-voltage setting. For gas turbine applications, aseparate 120/240vac source is required for theignition transformers with short circuit protec-tion of 20A or less.

The resultant internal 125Vdc is fuse-isolatedin the Mark VI power distribution module andfed to the internal power supplies for theControl Modules, any expansion modules, andthe termination boards for its field contactinputs and field solenoids. Additional 3.2A fuseprotection is provided on the terminationboard TRLY for each solenoid. Separate 120Vacfeeds are provided from the motor control cen-ter for any AC solenoids and ignition trans-formers on gas turbines. (See Table 11.)



Codes and StandardsISO 9001 in accordance with Tick IT by Lloyd'sRegister Quality Assurance Limited. ISO 9000-3 Quality Management and Quality AssuranceStandards, Part 3: Guidelines for the Appli-cation of ISO 9001 to Development Supply andMaintenance of Software.

Safety Standards UL 508A Safety Standard Industrial ControlEquip.

CSA 22.2 No. 14 Industrial Control Equipment

Printed Wire Board Assemblies UL 796 Printed Circuit Boards

UL recognized PWB manufacturer,

UL file number E110691

ANSI IPC guidelines

ANSI IPC/EIA guidelines

CE - Electromagnetic Compatibility (EMC) EN 50081-2

Generic Emissions StandardsEN 50082-2:1994

Generic Immunity Industrial EnvironmentEN 55011

Radiated and Conducted EmissionsIEC 61000-4-2:1995

Electrostatic Discharge SusceptibilityIEC 6100-4-3: 1997

Radiated RF Immunity

IEC 6100-4-4: 1995Electrical Fast Transient Susceptibility

IEC 6100-4-5: 1995Surge Immunity

IEC 61000-4-6: 1995Conducted RF Immunity

IEC 61000-4-11: 1994Voltage Variation, Dips, and Interruptions

ANSI/IEEE C37.90.1Surge

CE - Low Voltage Directive EN 61010-1

Electrical Equipment, Industrial MachinesIEC 529

Intrusion Protection Codes/NEMA 1/IP 20

Reference the Mark VI Systems Manual GEH-6421, Chapter 5 for additional codes and stan-dards.

EnvironmentThe control is designed for operation in an air-conditioned equipment room with convectioncooling. Special cabinets can be provided foroperation in other types of environments.

Temperature:Operating 0 to +45C +32 to +113F

Storage -40 to +70C -40 to +158F

The control can be operated at 50C duringmaintenance periods to repair air-conditioningsystems. It is recommended that the electronicsbe operated in a controlled environment tomaximize the mean-time-between-failure(MTBF) on the components.

Purchased commercial control room equipmentsuch as PCs, monitors, and printers are typicallycapable of operating in a control room ambientof 0 to +40C with convection cooling.

Humidity5% to 95% non-condensing

Exceeds EN50178: 1994



SteadyState

Voltage

Freq. Load Comments

125Vdc(100 to144Vdc)

10.0 A dc Ripple

Elevation Exceeds EN50178: 1994

Gas Contaminants EN50178: 1994 Section A.6.1.4 Table A.2 (m)

Dust Contaminants Exceeds IEC 529: 1989-11 (IP-20)

Seismic Universal Building Code (UBC) Section 2312 Zone 4

DocumentationThe following documentation is available forMark VI Turbine Controls. A subset of this doc-umentation will be delivered with each controldepending on the functional requirements ofeach system.

Manuals System Manual for SPEEDTRONICTM

Mark VI Turbine Control (GEH-6421)

Control System Toolbox, forConfiguring a Mark VI Controller(GEH-6403)

Configuring the Trend Recorder (GEH-6408)

System Data Base for System Toolbox(GEI-100189)

System Data Base Browser (GEI-100271)

Data Historian (used for trip history)(GEI-100278)

Communications To RemoteComputers / Plant DCS

RS232 Modbus Slave From ControlModule

Modbus CommunicationsImplementation UCOC2000 - I/ODrivers, Chapter 2

Communication Links From HMI:

RS232 Modbus Master/Slave, EthernetModbus Slave, Ethernet TCP-IP GSM HMI

SPEEDTRONIC Application Manual -Chapter 7 (GEH-6126), Ethernet TCP-IPGEDS Standard

Message Format (GSM) (GEI-100165)

Operator/Maintenance Interface HMIHMI for SPEEDTRONIC TurbineControls

Application Manual (GEH-6126)

Cim Edit Operation Manual (GFK-1396)

User Manual (GFK-1180)

Cimplicity HMI For Windows NTTrending Operators

Manual (GFK-1260)

Turbine Historian System Guide(GEH-6421)

Standard Blockware Library (SBLIB) Turbine Blockware Library

(TURBLIB)

Drawings Equipment Outline Drawing AutoCAD

R14

Equipment Layout Drawing AutoCADR14

I/O Termination List (ExcelSpreadsheet)

Network one-line diagram (ifapplicable)

Application Software Diagram(printout from source code)

Data List For Communication Link ToDCS



List of FiguresFigure 1. Benefits of Speedtronic Mark VI

Figure 2. Mark VI TMR control configuration

Figure 3. Operator interface graphics: 7FA Mark VI

Figure 4. Software maintenance tools card configuration

Figure 5. Software maintenance tools editors

List of TablesTable 1. Discrete I/O

Table 2. Analog I/O

Table 3. Temperature Monitoring

Table 4. VTUR I/O terminations from Control Module

Table 5. VPRO I/O terminations from Backup Protection Module

Table 6. VSVO I/O terminations from Control Module

Table 7. Nominal servo valve ratings

Table 8. VVIB I/O terminations from Control Module

Table 9. VGEN I/O terminations from Control Module

Table 10: VPYR I/O terminations from Control Module

Table 11: Power requirements



ger 4193 - mark vi

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