Mark VI for Gas Turbine Control Retrofits Application Overview

GE Energy

Mark VI for Gas Turbine Control Retrofits Application Overview

This document is distributed for informational purposes only. It is not to be construed as creating or becoming part of any General Electric Company contractual or warranty obligation unless expressly stated in a written sales contract.

2002 - 2005 by General Electric Company, USA. All rights reserved.

GEI-100538A

Section Page Introduction .................................................................................................................3 Acronyms and Abbreviations ......................................................................................3 Product Options ...........................................................................................................4 Architecture .................................................................................................................6 I/O Interface.................................................................................................................8 Diagnostics ................................................................................................................10 Communication .........................................................................................................10 Control Functions ......................................................................................................12 HMI ...........................................................................................................................16 Typical Turbine Instrumentation ...............................................................................18 Packaging ..................................................................................................................19 Typical Power Requirements.....................................................................................20

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

Introduction Most existing transmitters, sensors, and switches are compatible with the Mark VI I/O, and, in some cases, the I/O is totally compatible.

The Mark VI is a fully programmable gas turbine controller with its own power supply, processor, communications, and I/O for turbine control, and protection. Critical functions, such as emergency overspeed, redundant exhaust over-temperature protection, and backup synchronous check protection are provided by the 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 for compatibility with the existing site conditions. In addition, the controller has the speed and capacity to implement many new advanced features such as Dry Low NOx technology. All Mark VI controllers are shipped with application software and display software.

Acronyms and Abbreviations ADL 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 VERSA module Eurocard

GEI-100538A Mark VI for Gas Turbine Control Retrofits 3

Product Options The Mark VI controller is available in two state-of-the-art types: simplex and Triple Modular Redundant (TMR). These vary in cabinet size and I/O configuration based on the turbine type, application (generator or mechanical drive), and I/O required at a particular site.

A simplex controller is available in two sizes:

36x 36 (900 mm x 900 mm), which fits into the standard Mark I or Mark II controller footprint

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

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

4 Mark VI for Gas Turbine Control Retrofits GEI-100538A Application Overview

PS

Control Module

X

PS

Y

PS

Control Module

Z

Control Module

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

System Architecture

GEI-100538A Mark VI for Gas Turbine Control Retrofits 5

Architecture Scalable hardware and software make the Mark VI architecture well-suited for gas turbine control retrofits.

A TMR system is generally recommended for base load, DLN, and cogen applications.

The TMR and simplex versions of the Mark VI controller have equivalent control and 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 of I/O classified as critical, and the amount of redundancy.

TMR systems have the highest running reliability, represented by a longer Mean Time 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 of heat to generate steam for the production process and steam turbines

Turbines are equipped with triplicated field devices, for maximized running reliability

Dry Low NOx (DLN) combustion system upgrades, where instrumentation standards often require more replicated field devices than standard combustion systems

Generator drive applications that require continuous base-load operation Mechanical drive applications where compressors or pumps are critical to the

production 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

6 Mark VI for Gas Turbine Control Retrofits GEI-100538A Application Overview

s=.

Mark VI Simplex 36" by 36" Cabinet

GEI-100538A Mark VI for Gas Turbine Control Retrofits 7

I/O Interface Terminations support the existing #12 AWG (3.0 mm2) wires at site with barrier type terminal blocks for ease of maintenance.

The Mark VI is designed for direct interface to turbine and generator devices such as vibration 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 devices with their associated single-point failures. Direct connection to a field device reduces long-term maintenance, and enables diagnostics to directly monitor the health of devices mounted on the machinery.

Contact inputs are normally powered from the 125 V dc battery bus (optional 24 and 48 V dc) through the Mark VI termination boards. Each contact input is optically isolated and has a 1ms time stamp for Sequence of Events (SOE) monitoring.

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

Diagnostics monitor the secondary side of each fuse.

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

Analog inputs monitor 4 20 mA (250 ), which can be configured for self-powered, differential inputs, or as sensors that use a +24 V dc supply from the Mark VI. Selected inputs can be configured for 0 1mA inputs (5,000 ) or 5, 10 V dc inputs. This interfaces to

existing 0 1mA generator MW and MVAR transducers existing Dynesco-type gas fuel pressure and compressor discharge pressure

transducers 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 temperature control system to improve turbine operation.

Analog outputs can be configured for 4 20 mA output (500 maximum) or 0 200 mA output (50 maximum). Thermocouple inputs can be grounded or ungrounded. Software linearization is provided for type J and K thermocouples used on GE gas turbines plus types E, S, or T thermocouples. Existing control and overtemperature thermocouples are retained and divided between the Mark VI controller and the backup protection module for temperature control and overtemperature protection, respectively.

RTD inputs can be grounded or ungrounded. Software linearization is provided for 10 copper, 100/200 platinum, or 120 nickel RTDs. The generator or load compressor RTDs can be monitored directly by the Mark VI with all turbine and driven-load temperatures being collected in a common database with other turbine-generator parameters.

8 Mark VI for Gas Turbine Control Retrofits GEI-100538A Application Overview

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

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

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

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

Proximitor monitoring provides monitoring and protection for GE gas-turbine applications. Mark VI provides a direct interface to the keyphasor, radial proximitor, and axial proximitor inputs, which are collected in a common database with turbine parameters. The fundamental (1X), first harmonic (2X), and composite vibration signals are collected by the Mark VI and displayed with both magnitude and phase angle on the Human-Machine Interface (HMI). Active isolators provide buffered outputs to BNC connectors on the Mark VI termination boards for temporary connection to portable analysis equipment.

The PTs are paralleled to the backup protection module for redundant backup synch check protection.

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

GEI-100538A Mark VI for Gas Turbine Control Retrofits 9

Diagnostics Mark VI diagnostics include power-up, background, and manually initiated diagnostic routines capable of identifying both control panel, sensor, and output device faults. These faults are identified down to the VME board and terminal board level for the panel, and to the circuit level for sensors and actuators.

Communication The Mark VI uses the following communication networks.

I/O Net is an Ethernet-based network between a control module, the three sections of the backup protection module, and expansion I/O modules (if required). I/O Net uses Asynchronous Drives Language (ADL) to poll the modules for data instead of using the typical collision detection techniques used in Ethernet LANs.

Unit Data Highwat (UDH) is an Ethernet-based network that provides peer-to-peer communication between the Mark VI and a GE generator excitation control. The network uses Ethernet Global Data (EGD), 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 controllers on a network with up to 10 network nodes at 25 Hz.

Refer to the section, HMI, for information on the user interface.

The Mark VI can communicate to a GE HMI or directly with a plant Distributed Control System (DCS) network or Plant Data Highway (PDH) through Ethernet serial Modbus slave/master, Ethernet TCP/IP Modbus slave, or Ethernet TCP/IP with GE Energy Standard 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

10 Mark VI for Gas Turbine Control Retrofits GEI-100538A Application Overview

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

GEI-100538A Mark VI for Gas Turbine Control Retrofits 11

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

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

Acceleration control adjusts the fuel stroke reference 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. Separate shaft speed-control algorithms are provided for each shaft in multi-shaft machine applications. The Mark VI varies shaft speed to control real power (megawatt) output in a mechanical (compressor or pump) drive application. In a generator drive application, the Mark VI maintains a constant generator shaft speed to meet the electrical power demand and also controls the generator field through the use of VAR/Power Factor (PF) control algorithms to generate excitation raise and lower commands.

Generator load control compares the load setpoint with the MW feedback from a single-phase transducer and adjusts the speed setpoint to regulate the load. A Spinning Reserve selection allows the machine to start automatically and await an operator 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 of base or peak raises this setpoint to the maximum limit.

Exhaust temperature control algorithms sort the input from each thermocouple from the highest to the lowest temperature. They automatically reject bad thermocouple data, average the remaining data values, and execute the control algorithm based upon the average calculated temperature. Redundant transducers monitor the compressor discharge pressure and bias the temperature control to correct for ambient conditions 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 is a reference from the governor and feedback of the fuel control valves. The Fuel Stroke Reference (FSR) is determined by the turbine parameter (speed, temperature, and so on) calling for the least fuel. FSR calculation occurs in the main processor, then is transmitted to the servo valve cards on the backplane of the 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 control uses a Gas Control Valve (GCV), where fuel flow is a function of pressure (Fuel Flow = Fuel Pressure X FSR). An added Stop/speed Ratio Valve (SRV) opens as a turbine speed function, so pressure becomes a function of speed and the liquid fuel control system and the gas fuel control systems have the same characteristic.

12 Mark VI for Gas Turbine Control Retrofits GEI-100538A Application Overview

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 called Dry Low NOx (DLN).

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

Generator excitation control for voltage matching during synchronization and VAR/PF control after breaker closure can be integrated into the turbine control. When a reference or setpoint is entered, feedback from a single-phase VAR transducer regulates the setpoint in the Mark VI. Mark VI calculates PF from MW and 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

GEI-100538A Mark VI for Gas Turbine Control Retrofits 13

Sequencing Turbine control can include automated startup and shutdown sequences customized to meet operator requirements, as well as control and monitoring of all gas turbine auxiliary and support systems. Operators can have the turbine automatically sequence to intermediate hold points by selecting Crank, Fire, or Auto without enabling automatic synchronization. All ramp rates and time delays are pre-programmed for optimum performance. Timers and counters record long-term turbine 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 assurance that the turbine fully protected. Diagnostics capture a record of any abnormal conditions.

Protection Turbine control 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 drives the gas/liquid control valves to a zero-flow position and de-energizes the fuel shut-off solenoids. All control, protection, and monitoring algorithms are contained in the control modules for efficiency in sharing common data. The protection module includes standard backup turbine protection that meets OEM tripping reliability requirements for turbine overspeed, overtemperature, and sync-check protection.

In a typical installation, a 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 Contacts from the backup protection module in series with the positive side of

the bus Additionally, diagnostic and trip data is communicated between the control module and the backup protection modules on the triple redundant I/O Nets for cross-tripping.

Diagnostics monitor:

Contact from each relay Voltage directly across the trip solenoid Overspeed protection includes a primary overspeed monitoring system in the three control modules and an emergency overspeed monitoring system in the backup protection module that replaces the mechanical overspeed bolt used on older turbines. The control module and each section of the backup protection module monitors magnetic speed sensors from 2.0 rpm on a 60-tooth wheel. Diagnostics monitor the speed and acceleration, then exchange the data between the control module and the protection module on startup to verify that all sensors are active.

14 Mark VI for Gas Turbine Control Retrofits GEI-100538A Application Overview

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

GEI-100538A Mark VI for Gas Turbine Control Retrofits 15

HMI The HMI or user interface is provided through a GE CIMPLICITY graphics window with unit-specific screens, a Microsoft Windows operating system, and a Control 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 the HMI to be a non-essential component. With the turbine running, it can be reinitialized or replaced with no impact on the controller. The HMI communicates with the processor in the controller through the UDH.

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 provide a visual image of the turbines performance while changing screens.

Typical Gas Turbine Screens

Control Screens

Monitor Screens

Auxiliaries

Tests

Startup Bearing temperature

Flame Overspeed test

Motors Exhaust temperature

Water wash

FSR control Generator RTDs Start check Generator/exciter Wheelspace

temperature Trip diagram

Synchronizing Seismic vibration Timers Buttons on the right side of all screens produce sub-menus of category-specific screens.

The main screen is the Startup screen. Since the gas turbine control provides fully automatic startup including all interfaces to auxiliary systems, all basic commands and 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 Start displays in the startup status field. A pop-up window displays above the Start-up button for verification. Upon verification, the application software checks the startup permissives and starts a sequence that displays Starting and Sequence in Progress messages.

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 the Aux button is clicked and the Start Check screen is selected, it displays graphical information for the Start Check/Ready to Start permissives.

A message reminds you to investigate the nature of the latched trip prior to clicking Master Reset.

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

16 Mark VI for Gas Turbine Control Retrofits GEI-100538A Application Overview

00

vi a

o 000

o 0

0

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

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

Typical Turbine Instrumentation

GEI-100538A Mark VI for Gas Turbine Control Retrofits 17

Typical Turbine Instrumentation Analog and digital devices found on a typical dual fuel gas turbine without emission suppression 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

18 Mark VI for Gas Turbine Control Retrofits GEI-100538A Application Overview

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

GEI-100538A Mark VI for Gas Turbine Control Retrofits 19

Packaging Mark VI packages can be customized to meet any site requirement. Package options that 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 unplugged for 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 #2

54" (1350 mm) 36" (900 mm) 91.5" (2,324 mm) 1600 lbs (725 Kg)

GEI-100538A Mark VI for Gas Turbine Control Retrofits 19

Typical Power Requirements The 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 bus are continuously monitored for grounding. A floating bus eliminates the need for the dc ground relay and dc under-voltage relay present in older controllers. The 125 V dc bus 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 solenoids

A separate uninterruptible power supply (UPS) is required to power the HMI and network equipment.

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

Steady-state Voltage Frequency Load Comments

125 V dc (100 to 145 V dc) 10 A dc Ripple

g GE Energy 1502 Roanoke Blvd. Salem, VA 24153-6492 USA +1 540 387 7000 www.geenergy.com

GEI-100538A Revised 051109 Issued 020525

Mark VI for Gas Turbine Control RetrofitsIntroductionAcronyms and AbbreviationsProduct OptionsArchitectureI/O InterfaceDiagnosticsCommunicationControl FunctionsSequencingProtection

HMITypical Turbine InstrumentationPackagingTypical Power Requirements