mark VI

GEI-100472

g

GE Industrial Systems

SPEEDTRONICTM 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 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 purchaser’s 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

CIMPLICITY is a registered 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.

Introduction The high reliability achieved by the TMR control system is due to the integration of the triple redundant electronics and 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 successful turbine automation. The basis of this system is the three redundant control modules , , and . Each controller contains its own power supply, processor, communications, and I/O for all of the critical control, protection and monitoring of the gas turbine. Some critical functions, such as emergency overspeed protection and the phase-slip windows for backup synch check protection, are monitored by a separate triple redundant backup protection module . Most of the critical sensors for control loops and trip protection are triple redundant. Other sensors are dual or single element devices.

Backup Protection Module 3 Independent Sections

3 Control Modules

Mark VI Electronics

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Redundancy An important part of the fault tolerant control architecture is the method of reliably voting the inputs and outputs. Each control module reads its inputs and exchanges the data with the other two control modules every time the application software is executed at 40 ms. In addition, a 1ms time stamp is assigned to each contact input to provide a built-in sequence of events (SOE) monitor.

The voted value of each contact input and the median value of each analog input is calculated within each control module, and then used as the control parameter for the application software. Diagnostic algorithms monitor these inputs and initiate an alarm if any discrepancies are found between the three sets of inputs. Redundant contact inputs for trip functions are connected to three separate termination points and then individually voted. This enables the control system to survive multiple failures of contact or analog inputs without causing an erroneous trip command as long as the failures are not from the same circuit, such as lube oil pressure. An equally important part of the fault tolerance is the hardware voting of analog and contact outputs. Three coil servos on the valve actuators are separately driven from each control module, and the position feedback is provided with redundant linear variable differential transformers (LVDTs). Contact outputs to the hydraulic trip solenoids are voted with three magnetic relays on each side of the floating 125 V dc feeder to the solenoids.

I/O Interface The I/O is designed for direct interface to turbine and generator devices, such as vibration sensors, flame sensors, LVDTs, magnetic speed pickups, thermocouples, and Resistance Temperature Devices (RTDs). Direct monitoring of these sensors eliminates the need for interposing instrumentation with its associated single point failures, reduces long-term maintenance, and enables the Mark VI diagnostics to directly monitor the health of the sensors on the machinery. This data is then available to both local operator/maintenance stations and to the plant Distributed Control System via communication links. Contact Inputs are powered from the 125 V dc battery bus through the Mark VI termination boards. Each contact input is optically isolated and has a 1 ms time stamp for SOE monitoring. Contacts are open-to-alarm and open-to-trip. An inversion mask is applied to each contact input to normalize the data values and simplify understanding of the software. For example, 63QT is a low lube oil pressure trip switch that will open-to-trip. The inversion mask is applied such that whenever logic L63QT = 1 it means that there is low lube oil pressure. Conversely, if the field contact was closed-to-trip, the inversion mask would be 0 and L63QT = 1 would still mean that there is low lube oil pressure. Contact Outputs are from plug-in, magnetic relays with dry, form C contact outputs. The control provides a floating 125 V dc source and suppression for each solenoid with a 3.2 A slow-blow fuse on each side of the 125 V dc feeder.

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SPEEDTRONIC, Mark VI TMR • 3

Analog inputs can monitor 4-20 mA (250 ohms), which can be configured for selfpowered, differential inputs, or as sensors that use a +24 V dc supply from the turbine 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 (500 ohms max) or 0-200 mA output (50 ohms max). Gas turbine temperatures are monitored by type K thermocouples. Critical temperatures, such as exhaust temperature have multiple thermocouples that are divided between the three control modules for redundancy. Non-critical thermocouples, such as wheelspace and bearing temperatures, are connected to one thermocouple card in one control module, but the data is transmitted to all three main processors for monitoring and alarming. The control can interface with grounded or ungrounded thermocouples, and software linearization is provided for types E, J, K, or T. Generator temperatures are normally monitored with grounded 100 ohm platinum RTDs. The control can interface with grounded or ungrounded RTDs. Software linearization is provided for 10 ohm copper, 100/200 ohm platinum, or 120 ohm nickel RTDs. Speed Inputs include three passive, magnetic, speed sensor inputs. The median value is used for speed control and primary overspeed protection in the control modules. Three additional speed sensors are provided for emergency overspeed protection. These sensors are monitored by the three sections of the backup protection module and diagnostics are transmitted between the backup protection module and the control modules for cross-tripping and alarm management. The control monitors redundant Reuter Stokes type UV flame scanners and initiates an alarm if the light intensity diminishes below an acceptable level due to carbon buildup 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 VI for trip protection of the turbine and generator. These devices generate a small output current by passing a magnet through a fixed coil, thereby eliminating the need for excitation current. All vibration sensors are continuously monitored for faults, alarm levels, and trip levels. Protection features include: Standard vibration protection in Mark VI card rack.

4 • SPEEDTRONIC, Mark VI TMR

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A start check permissive is inhibited if three or more turbine sensors or two or more generator sensors are disabled or faulty.

•

An automatic shutdown sequence is initiated if all turbine or all generator sensors are disabled or faulty.

•

A trip is initiated if one turbine vibration sensor indicates a trip level and any other turbine sensor indicates an alarm level.

•

A trip is initiated if one turbine vibration sensor indicates a trip level and any adjacent 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 or more sensor inputs are disabled.

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An option is available for Bently Nevada Proximitors for monitoring only. The Proximitors can be supplied as either an interface to a Bently Nevada 3300 or 3500 monitor with an additional option for a Data Manager 2000 or as a direct interface to the turbine control. A Mark VI option is available for buffered outputs to BNC connectors to facilitate plug-in analysis instrumentation and direct plug connection from 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. Complete synchronizing system: auto, manual, and backup synch check protection..

The Synchronizing Interface uses a pair of single-phase potential transformers (PT), which are monitored by the control modules. It matches the turbine speed to the line frequency and match the generator and line voltages via the Unit Data Highway (UDH) to the generator excitation system. A command is issued to close the breaker based on a calculated breaker closure time. Diagnostics monitor the actual breaker closure time and self-correct each time the breaker closes. The single phase PTs are paralleled to the triple redundant backup protection module for the backup synch check protection. The synch check protection is used to backup the automatic synchronizing and the manual synchronizing which is implemented from a synchroscope screen on a Human-Machine Interface (HMI) server. Three-phase PT inputs from the generator and line, and single-phase current transformer (CT) inputs are normally monitored by the generator protection and the EX2000.

Built-in Diagnostics The Mark VI control system has extensive built-in diagnostics and includes powerup, background, and manually initiated diagnostic routines. These diagnostics are capable of identifying both control panel, sensor, and output device faults. These faults are identified down to the board level for the panel, and to the circuit level for the sensors and actuators.

System Overview The control system consists of several networks. IONET is the Ethernet-based network for communication between the three control modules, the three sections of the protection module, and any expansion modules. IONET uses asynchronous drives language (ADL) to poll the modules for data instead of using the typical collision detection techniques used in Ethernet local area networks (LAN). Ethernet networks with peerto-peer communication between turbine and generator controls.

The UDH is an Ethernet-based network that provides peer-to-peer communications between the turbine control, the generator excitation control, and the static starter. The network uses Ethernet Global Data (EGD), which is a message-based protocol with support for sharing information with multiple nodes based on the UDP/IP standard. Data can be transmitted unicast or broadcast to peer control systems on the network. 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 control megavar output. The generator protection panel (GPP) is used to provide primary protection for the generator. Additional protection features are located in the EX2000. Although the UDH is capable of communicating control data, control loops are closed internal to the turbine or generator control.

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In the case of var/power factor control for the generator or tie-line, the turbine control performs the regulation of the setpoint and transmits the command to adjust the generator field on the UDH to the excitation control. All trip commands are hardwired between control units, including any trip commands coming from remote control systems such as a Distributed Control System (DCS). An optional OSI PI- based Historian is available for long term data archiving and retrieval.

Dual servers (CIMPLICITY/Windows NT) are available to isolate the UDH from the Plant Data Highway (PDH). These servers can be used as local or remote operator and/or maintenance stations and configured in a variety of arrangements. Typically, one server is located in each Packaged Electrical and Electronic Control Compartment (PEECC) that contains a turbine control, a generator protection panel, a motor control center, and the 125 V dc batteries. The primary server can be provided with a time synchronization interface to a Global Time Source (GTS), which is normally implemented with IRIG-B. A backup time master can be provided in a backup server. Network Time Protocol (NTP) is used for internal time synchronization with ±1 ms time coherence. Plant DCS Network

Ethernet TCP-IP GSM Ethernet TCP-IP Modbus RS232/485 Modbus IRIG-B Time Synch Local Operator Station

Local Operator Station

Engineer's Station

Gas Turbine #2

Gas Turbine #1

Network Time Protocol NTP

Unit Data Highway - Ethernet

Gas Turbine Control Mark VI

Generator Excitation EX2000

Gas Turbine Control Mark VI

Steam Turbine

Generator Excitation EX2000

Static Starter

Steam Turbine Control Mark VI

Generator Excitation EX2000

Typical 207FA Control Network

The Plant Data Highway is used to communicate data to the plant distributed control system or other third party platforms. A variety of protocols are supported for communication with a plant DCS including RS-232C and RS-485 Modbus remote terminal unit (RTU) master/slave, Ethernet TCP-IP Modbus slave, and Ethernet TCP-IP with GEDS Standard Messages (GSM). The GSM protocol provides the following messages:

6 • SPEEDTRONIC, Mark VI TMR

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Administration

•

Spontaneous Event Driven (with local time tags)

•

Periodic Group Data (at rates to 1 second)

•

Common Request

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Control Functions Startup 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 turbine speed 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 and isochronous speed control with an automatic transfer to isochronous upon loss of the tie-line breaker. The FSR is determined by the control parameter calling for the least fuel.

Load Control compares the load setpoint with the MW feedback from a singlephase transducer and adjusts the speed setpoint to regulate the load. Selection of fast load 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 three control modules for redundancy. All of the temperature data is transmitted to all of the control modules that sort the data from the highest to the lowest temperature, automatically reject bad thermocouple data, average the remaining data values, and then execute the control algorithm. Three redundant transducers are supplied for monitoring the compressor discharge pressure and biasing the temperature control to correct for ambient temperature and the corresponding variations in mass flow. Inlet Guide Vane Control modulates the position of the compressor stator vanes to provide optimum compressor and unit operation. During startup, the guide vanes open as the turbine speed increases. When the unit is online, the guide vanes modulate to control turbine airflow temperature to optimize combustion system and combine cycle performance. Fuel Control consists of a reference from the governor and feedback of the fuel control 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 main processor and transmitted to the servo valve cards on the backplane of the control modules. High speed regulation of the servo loop with LVDT position feedback is performed on each servo card to obtain the maximum performance. In liquid fuel control systems, FSR establishes the called for stroke of the bypass valve. Fuel flow is proportional to the speed (fuel flow = speed X FSR). In gas fuel systems with only a gas control valve, the fuel flow is a function of pressure (fuel flow = pressure X FSR); therefore, a stop/speed ratio valve is added, which is programmed by speed. Pressure is now a function of speed and the liquid fuel control system and the gas fuel control system have the same characteristic (refer to the following diagram).

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SPEEDTRONIC, Mark VI TMR • 7

Gas Fuel

Control Module

Main Processor Constants

FPRG

Logic TNH (Speed)

VCMI Card

Termination Board

VSVO Card Software Regulator

Servo 90SR

D/A TSVO

+ -

LVDT 96SR

A/D

VAIC Card

TBAI D/A

FSROUT

Software Regulator

Gas Fuel Pressure 96FG

Gas Control Valve

VSVO Card Logic

Stop/Speed Ratio Valve

Servo 65GC

D/A TSVO

LVDT 96GC

A/D FSR2

Combustion Chamber

Logic Fuel Splitter

FSR

Stop/Speed Ratio Valve FSR1

Pulse 77FD

A/D

VSVO Card

FSROUT

Flow Divider

TSVO

TNH (Speed) Logic

Software Regulator

D/A

Servo 65FP

Liquid Fuel

Duel Fuel Control System

Generator Excitation Setpoints for volts (voltage matching during synchronization) and var/power factor control for the generator and tie-line are in the turbine control. References come from operator commands, and feedback comes from a single-phase var transducer. Power factor is calculated from watts and vars. Setpoints are transmitted from the turbine control to the generator excitation control on the UDH. Synchronizing is described in the section, I/O Interface. Emissions Control is available with diluent (water or steam) injection through a multi-nozzle quiet combustor to quench flame temperature and reduce thermal NOX formation. Lean-burning, pre-mixed flame combustors are available for lower NOX levels without the need for water or steam injection (dry low nox).

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Sequencing This automation enables operation of the gas turbine from a remote (off-site) location with the assurance that the turbine is fully protected and diagnostics will capture and record any abnormal conditions that may occur.

The turbine control includes a completely automated startup and shutdown sequence, including interface to all of the auxiliary systems in the motor control center and generator protection system. Operators can choose to have the turbine automatically sequence to intermediate hold points by selecting Crank or Fire without enabling automatic synchronization. All ramp rates and hold times are pre-programmed for optimum performance, and counters record the number of starts, shutdowns, trips and running time under various conditions in non-volatile memory. Counters and timers 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

Protection The turbine control system monitors all control and protection parameters and initiates an alarm if an abnormal condition is detected. If the condition exceeds a predefined trip level, the turbine control will drive the gas/liquid control valves to a zero flow position and de-energize the hydraulic trip solenoids. Since this action is vital to protecting the turbine, the electronics are triple redundant. All of the control, protection, and monitoring algorithms are contained in the control modules for efficiency in sharing the common data used in these calculations. Backup protection for emergency overspeed and synch check protection is performed in the protection module.

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SPEEDTRONIC, Mark VI TMR • 9

Primary Overspeed

Combustion Monitor

Loss Of Flame

Module

Rotor Vibration

Module

Fuel Control System

Fuel Control Valve

Compressor Surge

Module

Hydraulic Trip System

Fuel Stop Ratio Valve

Fuel To Turbine

TMR Applications Fire Protection System

Protection Module

High Lube Oil Header Temp.

Section

Generator Synchronization

Section

Emergency Overspeed

Section

Steam Turbine Stop Valves For Single Shaft STAG Steam Cycle Trip System

For Turbines With No Mech. Overspeed Bolt

Exhaust Overtemperature

Generator Synch Check Protection

Manual Emergency Trip

Customer Protect. Shutdown

Low Hydraulic Supply / Trip Pressure

Low Lube Oil Pressure

Manual Hydraulic Trip

Typical Protection System

Each trip solenoid is powered from the 125 V dc floating battery bus with contacts from the control module in series with the negative side of the bus and contacts from the backup protection module in series with the positive side of the bus. Since there are three control modules and three sections of the backup protection module, each trip solenoid has three relays from the control module voting on one side and three relays from the backup protection module voting on the other side.

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Diagnostics monitor a contact from each relay and also monitor the voltage directly across the trip solenoid. For added insurance, diagnostic and trip data are communicated between the control modules and the backup protection modules on the triple redundant IONets for cross-tripping. Overspeed protection consists of a primary overspeed monitoring system in the three control modules and an emergency overspeed monitoring system in the backup protection module, which replaces the mechanical overspeed bolt used on older turbines. Each control module and each section of the backup protection module monitors a separate passive magnetic speed sensor (6 total) from 2 rpm on a 60 tooth wheel. Diagnostics monitor the speed and acceleration and exchange the data between the control modules and the backup protection module on startup to verify that 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 Pump Undervoltage

Exhaust Thermocouples Open

Manual Trip

Failure to Ignite on Gas Fuel

Compressor Bleed Valve Position Trouble

Control Speed Signal Lost - HP

Load Tunnel Temperature High

Protective Speed Signal Trouble

Red. Sensor Gas Fuel Hydraulic Pressure Low

Control Speed Signal Trouble

Turbine Lube Oil Header Temperature

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 Trip Lockout Transf. Differential Trip Lockout Exhaust Pressure High Breaker Failure Trip Lockout Vibration Trip Startup Fuel Flow Excessive Loss of Protection HP Speed Inputs Customer Trip

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SPEEDTRONIC, Mark VI TMR • 11

Operator Screens The operator/maintenance interface is commonly referred to as the Human Machine Interface (HMI). It is a PC with a GE CIMPLICITY graphics screen system, a Microsoft Windows NT operating system, a Control System Toolbox with editors for the 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 to be a non-essential component of the control system. It can be reinitialized or replaced with the turbine running with no impact on the control system. The HMI communicates with the processor card in the turbine control via the Ethernet-based UDH.

Operator Interface Graphics

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Gas turbine control screens show a diagram of the turbine with the primary control parameters. The diagram is repeated on most of the screens to enable operators to maintain a visual picture of the turbine’s performance while changing screens. Some screens such as the exhaust temperature monitor and the static starter screen have unique 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 control provides fully automatic startup including all interface to auxiliary systems, an operator can initiate all of the basic commands and observe all of the primary control parameters and status conditions from this single screen. All operator commands can be given through momentary pushbutton commands on the screen. The command is sent to the Mark VI control where the application software initiates the requested action assuming that the appropriate permissives are satisfied. A response to the command can be observed within one second, if it does not involve subsequent system time delays like purging. As an example, if Ready to Start is displayed in the Startup Status field, a Start command can be given. A small pop-up window displays above the Start button for the operator to verify the start of the turbine. Upon verification, the application software checks the startup permissives and initiates a startup sequence, which displays Starting and Sequence in Progress messages on the left side of the screen. The purpose of the alarm queue is to identify any abnormal condition including any reason to inhibit a start sequence.

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If the unit was not ready to start, then the message Not Ready to Start displays and an alarm message displays in the bottom left-hand corner of the screen identifying the reason. In addition, there is a Start Check screen (under Auxiliaries), which provides a graphical representation and status of the Start Check / Ready to Start permissives. This graphic also relates to the functional organization of the application software for the Start Check/Ready to Start Permissives. Similarly, all trips displayed in the alarm field and in the Trip Diagram under Auxiliaries. If a latched trip is the reason for not being ready to start, then the operator must select the Master Reset button on the Startup screen. This references another screen to remind the operator to investigate the latched trip prior to issuing a Master Reset.

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In some cases, it is more convenient for the operator to change a setpoint, such as MW, by typing in a numerical value for the setpoint rather than issuing raise/lower commands. This capability is provided, and the application software in the Mark VI automatically compares the requested setpoint with acceptable limits and determines a suitable rate to ramp the setpoint to the new target. A Startup Trend can be selected with pre-assigned parameters for the mean exhaust temperature, speed, maximum vibration, compressor discharge pressure, inlet guide vane position, and the fuel stroke reference. More detailed information and trending are provided on supporting screens, and customized trends can be created too.

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Typical Turbine Instrumentation Redundant and Multiple Sensors Device

Parameter

Function

Device Type

26QA/T

Quantity

Redundant

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

63HL

Liquid 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 discharge temperature

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-redundant location has one sensor. The number of exhaust thermocouples (TCs) varies with the gas turbine (GT) model from 13 to 27. TCs are divided between the control modules for redundancy. Legend: S = Shared

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D = Dedicated

A = Alarm

M = Monitor

P = Protection

C = Control

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Non-Redundant Sensors (Partial Listing) Device

Parameter

Function

12HA

Mechanical overspeed bolt sensor

20FG

Gas fuel trip oil

20FL

A/P

Device Type

Quantity

Limit switch

1

C

Solenoid valve

1

Liquid fuel trip oil

C

Solenoid valve

1

26FD

Liquid fuel temperature

C

Temp switch

1

26QL/M

Lube oil temperature low / moderate

C

Temp switch

1 each

26QN

Lube oil temperature normal

P

Temp switch

1

33CS

Starting clutch

M

Limit switch

1

33HR

Ratchet position

C/A

Limit switch

1

39FC

Cooler fan vibration

A

Vibration switch

1/fan

63AD

Atomizing air differential pressure

A

Pressure switch

1

63FD

Liquid fuel pressure

A*

Pressure switch

1

63FG

Gas fuel pressure

A*

Pressure switch

1

63LF1

Liquid fuel filter pressure

A

Pressure switch

1

63LF2

Liquid fuel forwarding filter pressure

A

Pressure switch

1

63QA

Lube oil pressure

P

Pressure switch

1

63QL

Lube oil pressure

P

Pressure switch

1

63TK

Exhaust frame cooling pressure

A/P

Pressure switch

1/fan

63WC

Cooling water pressure low

A

Pressure switch

1

71QH

Lube tank high level

A

Level switch

1

71QL

Lube tank low level

A

Level switch

1

71WL

Water tank low level

A

Level switch

1

96FF-1

Gas fuel flow pressure

C

Transducer

1

96FG1

Gas fuel supply pressure

C

Transducer

1

P = Protection

C = Control

*Can be used to initiate a transfer from primary to backup fuel. Legend: S = Shared

D = Dedicated

16 • SPEEDTRONIC, Mark VI TMR

A = Alarm

M = Monitor

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Packaging Cabinet access: Front door access only Card Backplane: VME type (VERSA Module Eurocard) Cabinet: NEMA 1 convection cooled, similar to IP-20 Cable Entrance: Top and/or bottom Finish: E-coat primed, pebble gray – RAL 7032 Door, rear wall, roof: powder painted Locks: Lockable door Material: Sheet steel Terminal Blocks: (24) point, barrier type terminal blocks that can be unplugged for maintenance. Each screw can terminate (2) #12 AWG (3.0mm2), 300 V insulated wires. 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

GEI-100472

SPEEDTRONIC, Mark VI TMR • 17

Power Requirements The control cabinet is powered from the 125 V dc battery bus and short circuit protected in the motor control center. Both sides of the floating 125 V dc bus are continuously monitored with respect to ground. The 125 V dc is fuse isolated in the Mark VI power distribution module and fed to the internal power supplies for the control modules, the termination boards for the field contact inputs, and to the termination boards for the turbine solenoids. Additional 3.2 A fuse protection is provided on the termination board for each solenoid. Separate 120 V ac feeds are provided from the motor control center for the ignition transformers. Auxiliary 120/240 V ac sources can be provided for cabinet power if required. A separate UPS is 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