Package Familiarization LM2500 - 50 Hz

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

This document is intended for training use only. It is not intended to cover all possible variations in equipment or to provide for specific problems that may arise. Technical drawings and descriptions herein are intended to illustrate conceptual examples and do not necessarily represent as-supplied system details. System users are advised to refer to drawings of current release when conducting troubleshooting, maintenance procedures, or other activities requiring system information. GE Aero Energy Products advises that all plant personnel read this training manual and the Operation & Maintenance Manual to become familiar with the generator package, its auxiliary equipment and its operation.

This manual is not a replacement for experience and judgment. The final responsibility for proper, safe operation of the generator package lies with the Owners and Operators. Operation and performance of auxiliary equipment and controls not furnished by GE is the sole responsibility of the Owners and Operators. Reproduction of this guide in whole or in part without written permission is prohibited. 2262533TR

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TABLE OF CONTENTS SECTION

DESCRIPTION

1

1-1

COURSE INTRODUCTION

1-9

LM2000 50HZ TYPICAL PRE START WALK AROUND

2-1

GAS TURBINE BASIC PRINCIPLES

2-19

LM2000 DETAILS OF CONSTRUCTION

2-47

ENGINE OPERATING PARAMETERS

2-49

LM2000 INSTRUMENTATION

3-1

GAS TURBINE SUPPORT SYSTEMS

3A-1

SYSTEM CONFIGURATION AND SKID OVERVIEW

3B-1

HYDRAULIC START SYSTEM

3C-1

TURBINE LUBE OIL SYSTEM

3D-1

TURBINE GAS FUEL SYSTEM

3E-1

TURBINE WATER WASH SYSTEM

3F-1

VENTILATION AND COMBUSTION AIR SYSTEM

3G-1

FIRE PROTECTION SYSTEM

3H-1

TURBINE AUXILIARY SYSTEMS

3I-1

TURBINE-GENERATOR VIBRATION MONITORING SYSTEM

3J-1

24-VDC BATTERY SYSTEM

4-1

ELECTRICAL SYSTEM

4-2

ELECTRICITY AND THE PRINCIPLES OF POWER GENERATION

4-10

BRUSHLESS EXCITATION SYSTEM

2

3

4

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TABLE OF CONTENTS – (CONT.) SECTION

5

6

DESCRIPTION

PAGE

4-14

ELECTRIC GENERATOR DETAILS OF CONSTRUCTION

4-27

GENERATOR LUBE OIL SYSTEM

4-35

POWER CONTROL AND SYNCHRONIZATION

4-65

SYNCHRONIZATION

4-71

DIGITAL GENERATOR PROTECTION SYSTEM

4-81

MOTOR CONTROL CENTER

5-1

TURBINE CONTROL SYSTEM

5-3

ELECTRONIC CONTROL SYSTEM

5-5

TURBINE CONTROL PANEL

5-27

ATLAS PC CONTROL SYSTEM

5-55

OPERATOR SCREENS

5-67

FUEL MANAGEMENT SYSTEM

5-79

NORMAL START SEQUENCE

5-93

NORMAL STOP SEQUENCE

5-99

TURBINE CONTROL SYSTEM – FUNCTIONAL DESCRIPTION

APPENDIX APPENDIX – 3

DEFINITIONS FOR ALARM AND SHUTDOWNS

APPENDIX – 19

ABBREVIATIONS AND ACRONYMS

APPENDIX – 29

GLOSSARY

APPENDIX – 39

GAS TURBINE ENGINE THEORY DEFINITIONS

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SECTION 1 COURSE INTRODUCTION

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SYSTEM PACKAGE OVERVIEW

OVERVIEW OF GE AERO ENERGY PRODUCTS GE Aero Energy Products is a leading supplier of diesel and aeroderivative gas turbine packages for industrial and marine applications with many units operating throughout the world. We take single-source responsibility for the total equipment package, and we provide field service for the equipment once it has been installed.

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We put our best into each unit that we build—all our skill and field experience. We meet our customers’ needs with standardized designs, which have been proved and reproved in tropic heat, desert sand, and arctic cold. For our customers’ special requirements, we add features from our list of pre-engineered options. Then we build the unit with care in a modern factory and test it rigorously, under load, before shipment. Our obligation doesn’t end when the unit rolls out our door. We provide job-site supervision and operator training. We offer total plant operation and maintenance, if desired. Then we back up our customers with a multimillion-dollar inventory of turbine parts and a service department ready to perform field service anywhere in the world—24 hours a day, 365 days a year. Meeting our customers’ requirements for quality, dependability, and outstanding service has been the basis of the GE Aero Energy Products reputation since day one.

PURPOSE OF THE COURSE This training course will familiarize system operators with the basic operation of the gas turbinegenerator (GTG) set, alternating current generator, and subsystems that make up the GTG set package. The integration of these subsystems into an operational unit represents the value-added engineering contributed by GE Aero Energy Products.

COURSE DESCRIPTION This training course will provide adequate system and subsystem operational information to achieve maximum equipment efficiency. The correct interpretation of this information will lead to safe, reliable operation and extended equipment life. This course will cover the following: ¾ Gas turbine fundamentals, theory of operation, and details of construction ¾ Gas turbine support systems and equipment flow and instrument diagrams (F&ID) ¾ Generator fundamentals, theory of operation, details of construction ¾ Control system fundamentals, theory of operation, details of construction This course should be considered a mandatory prerequisite to maintenance training, which is a separate discipline requiring disassembly and reassembly instructions, as well as troubleshooting techniques using special tools and test equipment.

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CLASS HOURS The minimum course length is five calendar days, eight hours per day with a one-hour lunch break and a fifteen-minute break every one and one-half hours. The class start time is normally 8 a.m., and the finish time is 4 p.m.

PROGRESSIVE AND FINAL EXAMINATIONS Progressive examinations are given after each major subsection. The examinations are intended to be part of the learning process. The examinations are open book, and help from other class members is allowed. A final, comprehensive examination is given at the conclusion of the course. During the final examination, students may not communicate with others when answering the questions. The final examination allows GE Aero Energy Products and your employer to measure the effectiveness of the training and your understanding of the material and concepts presented. A course completion certificate will be given to qualified students. Additional courses are available: • Level I maintenance- The training will cover LM2000 engine routine, periodic, and unscheduled maintenance and Boroscope training. • Advance Control Systems - Woodward Atlas Control - The training will cover the Woodward governor equipment description, operations and calibration

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TYPICAL LM2000

SAFETY The following are general safety precautions that are not related to any specific procedures and do not appear elsewhere in this manual. Personnel must understand and apply these precautions during all phases of operation and maintenance.

HEALTH HAZARDS Use all cleaning solvents, fuels, oil adhesives, epoxies, and catalysts in a well-ventilated area. Avoid frequent and prolonged inhalation of fumes. Concentrations of fumes of many cleaners, adhesives, and esters are toxic and will cause serious adverse health effects and possible death if inhaled frequently. Wear protective gloves and wash thoroughly with soap and water, as soon as possible, after exposure to such materials. Take special precautions to prevent materials from entering the eyes. If exposed, rinse the eyes in an eyebath fountain immediately and report to a physician. Avoid spilling solvents on the skid. Review the hazard information on the appropriate Material Safety Data Sheet and follow all applicable personal protection requirements.

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ENVIRONMENTAL HAZARDS The disposal of many cleaning solvents, fuels, oils, adhesives, epoxies, and catalysts is regulated and, if mismanaged, could cause environmental damage. Review Material Safety Data Sheets, product bulletin information, and applicable local, state, and federal disposal requirements for proper waste management practices.

FIRE HAZARDS Keep all cleaning solvents, fuels, oil, esters, and adhesives away from exposed-element electric heaters, sparks, or flame. Do not smoke when using flammable materials, in the vicinity of flammable materials, or in areas where flammable materials are stored. Provide adequate ventilation to disperse concentrations of potentially explosive fumes or vapors. Provide approved containers for bulk storage of flammable materials, and approved dispensers in the working areas. Keep all containers tightly closed when not in use.

ELECTRICAL HAZARDS Use extreme care when working with electricity. Electricity can cause shock, burns, or death. Electrical power must be off before connecting or disconnecting electrical connectors. Lethal output voltages are generated by the ignition exciter. Do not energize the exciter unless the output connection is properly isolated. Be sure all leads are connected and the plug is installed, or that all personnel are cleared to at least 5 feet before firing the exciter.

COMPRESSED AIR HAZARDS Air pressure used in work areas for cleaning or drying operations shall be regulated to 29 psi or less. Use approved safety equipment (goggles or face shield) to prevent injury to the eyes. Do not direct the jet of compressed air at yourself or other personnel so that refuse is blown onto adjacent work stations. If additional air pressure is required to dislodge foreign materials from parts, ensure that approved safety equipment is worn, and move to an isolated area. Be sure that the increased air pressure is not detrimental or damaging to the parts before applying high-pressure jets of air.

PROCEDURAL HAZARDS Observe all specified and logical safety practices when assembling or disassembling the engine. Wear safety glasses or other appropriate eye protection at all times. Do not allow safety wire or wire clippings to fly from the cutter when removing or installing wire. Do not use fingers as guides when installing parts or checking alignment of holes. Use only correct tools and fixtures. Avoid “shortcuts,” such as using fewer-than-recommended attaching bolts or inferior-grade bolts. Heed all warnings in this manual and in all vendor manuals, to avoid injury to personnel or damage to gas turbine parts.

TOOLING HAZARDS Improperly maintained tools and support equipment can be dangerous to personnel, and can damage gas turbine parts. Observe recommended inspection schedules to avoid unanticipated failures. Use tooling only for the purpose for which it was designed, and avoid abuse. Be constantly alert for damaged equipment, and initiate appropriate action for approved repair immediately.

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GAS TURBINE OPERATIONAL HAZARDS The outside surfaces of the engine are not insulated; therefore, adequate precautions shall be taken to prevent operating personnel from inadvertently coming into contact with these hot surfaces. The gas turbine is a source of considerable noise. It is necessary for personnel working on the gas turbine or in its vicinity to wear proper ear protection equipment when it is operating. The gas turbine is a high-speed machine. In case of component failure, the skid housing would contain compressor and turbine blade failures, but might not contain major compressor or turbine disk failures. Operating personnel shall not be permanently stationed in or near the plane of the rotating parts. Low-pressure, high-velocity airflow created by the compressor can draw objects or personnel into the engine. Although an inlet screen is used, personnel should not stand in front of the inlet while the engine is operating. When entering the gas turbine enclosure, the following requirements must be met: ¾ The gas turbine will be shut down or limited to core idle power. ¾ The fire extinguishing system will be made inactive. The enclosure door shall be kept open. If the gas turbine is operating, an observer shall be stationed at the enclosure door, and confined space entry procedures will be followed. ¾ Avoid contact with hot parts, and wear thermally insulated gloves, as necessary. ¾ Hearing protection (double) will be worn if the gas turbine is operating. ¾ Do not remain in the plane of rotation of the starter when motoring the gas turbine. ¾ When performing maintenance on electrical components, turn off electrical power to those components, except when power is required to take voltage measurements. Lock out all controls and switches, if possible; otherwise, tag electrical switches “Out of Service” to prevent inadvertent activation. Tag the engine operating controls “Do Not Operate” to prevent the unit from being started during a shutdown condition.

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CLEANLINESS AND FOD FOD is the single major cause of premature gas turbine failure. Prevention is the only practical means of protecting against FOD, and adherence to the following guidelines cannot be overemphasized. • • • • • • • •

Empty pockets of all lose objects. Keep maintenance area clean and organized. Keep FOD containers in the work area to receive bits of safety wire, used gaskets, O-rings and other similar types of debris. USE THEM. Do not use the gas turbine as a shelf to hold parts and tools during maintenance. Install protective covers and caps on all exposed openings during maintenance. Remove protective caps and covers only when required to install a part or make a connection. After protective caps and covers are removed, inspect all openings and cavities for foreign objects and cleanliness. After maintenance, thoroughly clean and inspect work area. Account for all tools, parts, and materials used during maintenance.

PRODUCT BULLETINS Product Bulletins are issued by GE Aero Energy Products to inform customers of changes to and improvements in the gas turbine product. All Product Bulletins issued by GE Aero Energy Products and cross-reference of Product Bulletins, are available on the GE Aero Energy Products Bulletin Board System (BBS). The files on the BBS are compressed, self-extracting, MicroSoft Word document files. In addition to Product Bulletins, other technical information is available, and there are extended BBS features such as e-mail available for your use. If you require further information concerning BBS operation or account status, please fax your inquiry to BBS operation or account status, please fax your inquiry to BBS System Operator, GE Aero Energy Products at (281) 457-8412.

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LM2000 TYPICAL PRE START WALK AROUND

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INTRODUCTION

If followed good engineering practices dictates that three different types of walk-arounds by conducted on the package, a pre-start walk around, a running walk around, and a post shutdown walk around. The following are some typical checks to be conducted during each of these types of walk-arounds.

2.

PRE-START WALK AROUND:

Pre-start walk around is to be conducted with no machinery running. Starting at the generator end of the package.

2.1. GENERATOR LUBE OIL SKID

CHECKED BY

Check generator oil level. Check lube oil reservoir for standing oil. Check condition of auxiliary oil pump. Check for standing oil around auxiliary oil pump. Check condition of jacking oil pump, if applicable. Check for standing oil around jacking oil pump. Check duplex filters are set to one side or the other. Check duplex filters for leaks. Check lube oil thermostatic control valve for leaks. Check jacking oil pump filters for leaks. Check all jacking oil pump gauges are reading “0”, not above or below. Check that all instrumentation is in place and securely mounted. Check exciter bearing for leakage. Check exciter-cooling airway is clean and clear of any debris.

2.2. GENERATOR - LEFT SIDE

CHECKED BY

Check non-driven end bearing for leakage. Check rundown tank for oil leaks. Check that all instrumentation is in place and securely mounted. Check coupling guard is in place and secure.

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2.3. GAS TURBINE – LEFT SIDE DOOR

CHECKED BY

Open turbine enclosure door. Check for standing oil or possible gas leaks Check that all instrumentation is in place and securely mounted. Check overall condition of gas turbine. Check Emergency Stop button is in correct position. Check enclosure lights are working correctly. Check condition and correct position of “Fire-Eye”. Check turbine fire dampers are open. Close door and check door is secure.

2.4. GAS TURBINE ENCLOSURE – LEFT SIDE

CHECKED BY

Check all turbine gauges for calibration

2.5 GAS TURBINE – RIGHT SIDE DOOR

CHECKED BY

Open turbine enclosure door. Check for standing oil or possible gas leaks. Check that all instrumentation is in place and securely mounted. Check overall condition of gas turbine. Check variable geometry filter for leaks. Check Emergency Stop button is in correct position. Check enclosure lights are working correctly. Check condition and correct position of “Fire-Eye”. Check turbine fire dampers are open. Close door and check door is secure.

2.6

GENERATOR– RIGHT SIDE

CHECKED BY

Check drive end bearing for leakage. Check that all instrumentation is in place and securely mounted. Check coupling guard is in place and secure. Check all generator oil pump gauges are reading “0”, not above or below. Check rundown tank for oil leaks. Check non-driven bearing for leakage. Check exciter-cooling airway is clean and clear of any debris.

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2.7. SYSTEMS CHECKS 2.7.1 Gas Turbine Lube Oil System

Checked By

Check lube oil level in reservoir. Check lube oil reservoir for leaks. Check lube oil reservoir drain valve is locked shut. Check duplex supply filters are set to one side or the other. Check duplex supply filters for leaks. Check duplex supply filter ∆P gauge is reading “0”, not above or below. Check duplex scavenge filters are set to one side or the other. Check duplex scavenge filters for leaks. Check duplex scavenge filter ∆P gauge is reading “0”, not above or below. Check lube oil coolers for leaks. Check lube oil cooler valve alignment to ensure proper oil flow. Check lube oil thermostatic control valve for leaks. Check lube oil coolers for leaks.

2.7.2 Hydraulic Start System

Checked By

Check hydraulic start oil level in reservoir. Check hydraulic oil reservoir for leaks. Check hydraulic start pump assembly for leaks. Check condition of hydraulic start pump assembly. Check condition of hydraulic start motor Check condition of hydraulic start hoses. Check hydraulic start cooler for leaks. Check hydraulic start cooler airways are clear. Upon completion of walk-thru notify supervisor of results for any recommended actions prior to start.

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SECTION 2 GAS TURBINE BASICS

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GAS TURBINE BASIC PRINCIPLES (FIG 1)

GAS TURBINE BASIC PRINCIPLES The balloon drawings above illustrate the basic principles upon which gas turbine engines operate. Air compressed inside a balloon, as in (A) above, exerts force upon the confines of the balloon. The air, which has weight and occupies space, has by definition, mass. The mass of the air is proportional to its density, and density is proportional to temperature and pressure. Air molecules are driven farther apart as temperature increases and closer together as temperature decreases, as stated in Boyle's and Charles’ law (PV/T = K). P=pressure, V=specific volume and K=absolute temperatures in K (Kelvin) The air mass confined inside the balloon, accelerates from the balloon, creating a force when it is released as in (B) above. This force increases as mass and acceleration increase, as stated in Newton’s second law (F = MA) F=force and MA= mass acceleration. The force created by the acceleration of the air mass inside the balloon results in an equal and opposite force that causes the balloon to be propelled in the opposite direction, as stated in Newton’s third law. (Every action produces an equal and opposite reaction.) 2-2

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GAS TURBINE BASIC PRINCIPLES (FIG 1) Replacing the air inside the balloon, as in (C Fig 1), sustains the force and although impractical, allows a load to be driven by the force of the air mass accelerating across and driving a turbine, as in (D Fig 1). In (E Fig 1), a more practical means of sustaining the force of an accelerating air mass used to drive a load is illustrated. A housing contains a fixed volume of air, which is compressed by a motor-driven compressor. Acceleration of the compressed air from the housing drives a turbine that connected to the load. In (F Fig 1), fuel is injected between the compressor and the turbine to further accelerate the air mass, thus multiplying the force used to drive the load. In (G Fig 1), the motor is removed and the compressor is powered by a portion of the combustion gas, thus making the engine self-sufficient as long as fuel is provided. In (H Fig 1), a typical gas turbine-engine operation is represented. Intake air is compressed, mixed with fuel and ignited. The hot gas is expanded across a turbine to provide mechanical power and exhausted to atmosphere.

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Brayton Cycle

BRAYTON CYCLE Five processes occur in gas turbine engines, as illustrated above. These processes, first described by George Brayton and called the Brayton cycle, occur in all internal combustion engines. The Brayton steps are as follows: ¾ Compression occurs between the intake and the outlet of the compressor (Line A-B). During this process, pressure and temperature of the air increases.

¾ Combustion occurs in the combustion chamber where fuel and air are mixed to explosive proportions and ignited. The addition of heat causes a sharp increase in volume (Line B-C).

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¾ Expansion occurs as hot gas accelerates from the combustion chamber. The gases at constant pressure and increased volume enter the turbine and expand through it. The size of the passages is also increased, which allows a further increase in volume and a sharp decrease in pressure and temperature (Line C-D). ¾ Exhaust occurs at the engine exhaust stack with a large drop in volume and at a constant pressure (Line D-A). The number of stages of compression and the arrangement of turbines that convert the energy of accelerating hot gas into mechanical energy are design variables. However, the basic operation of all gas turbines is the same.

TURBINE Vs RECIPICATING ENGINE

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CONVERGENT AND DIVERGENT DUCTS Compressors in gas turbine engines use convergent and divergent ducts to generate the high pressures necessary to (a) provide a “wall of pressure,” preventing expanding hot gas from exiting through the engine inlet as well as through the exhaust; and (b) provide the proper ratio of air-to-fuel for efficient combustion and cooling of the combustion chamber. Pressure decreases through convergent ducts and increases through divergent ducts, a phenomenon which is demonstrated in paint spray equipment. Compressed air, forced through a convergent duct, generates a lower pressure through the narrow section to draw in paint. Expansion through a divergent section then increases pressure and air volume, dispersing the paint in an atomized mist.

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Gas Turbine Rotation and Engine Stations For the heavy-duty gas turbines, the left and right side of the gas turbine and its parts are determined by looking in the direction of the airflow, (looking downstream).

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AXIAL FLOW COMPRESSOR

AXIAL-FLOW COMPRESSOR Illustrated above is an axial-flow compressor. It compresses a large volume of low-pressure air at low velocity into a small volume of high-velocity air at high pressure. An apparent contradiction in the operation of the axial-flow compressor is that high pressure is generated, although the overall divergent shape would appear to cause a lower output pressure. Output pressure is increased by divergence in each static interstage section. Rotating compressor blades between each static stage increases the velocity that is lost by injecting energy.

INLET GUIDE VANES Inlet guide vanes direct, or align, airflow into the first rotating blade section where velocity is increased by the addition of energy. The following stator vane section is divergent, providing an increase in static pressure and a decrease in air velocity. Airflow then enters the second stage at a higher initial velocity and pressure than at the inlet to the preceding stage. Each subsequent stage provides an incremental increase in velocity and static pressure until the desired level of pressure and velocity is reached.

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INLET GUIDE VANES

INLET GUIDE VANES Some compressor stator vanes are designed to move, changing their divergence, allowing regulation of compressor outlet pressure and velocity to achieve the proper ratio of air for fuel combustion and cooling versus engine speed and power output.

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ANNULAR COMBUSTOR The flame-stabilizing and general-flow patterns are illustrated above for a typical “can-type” combustion chamber. Although modern engines use one continuous annular combustion chamber, the can-type simplifies illustration of the cooling and combustion techniques used in all combustion chambers.

CAN TYPE COMBUSTOR

ANNULAR TYPE COMBUSTOR

FLAME-STABILIZING AND GENERAL-FLOW PATTERNS

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The temperature of the flame illustrated in the center of the combustor is approximately 3200°F at its tip when the engine is operating at full load. Metals used in combustion chamber construction are not capable of withstanding temperatures in this range; therefore, the design provides airflow passages between the inner and the outer walls of the chamber for cooling and flame shaping. Air flowing into the inner chamber is directed through small holes to shape the flame centering it within the chamber, to prevent its contact with the chamber walls. Approximately 82% of the airflow into combustion chambers is used for cooling and flame shaping; only 18% is used for fuel combustion. Regulation of fuel flow determines engine speed. Stator vane control in the compressor controls pressure and velocity into the combustion chamber as a function of compressor speed. The primary functions of the gas combustor which must be met for the system to be effective are: ¾ Shield the combustor outer casing from convection and radiated heat. ¾ Provide adequate cooling for the walls of the combustion liner so that it does not disintegrate, causing FOD which could damage the turbine section. ¾ Provide the correct air to fuel ratio in the stabilizing flame zone for combustion. ¾ Dilute the products of combustion to an acceptable temperature before they impinge on the components of the turbine static and rotating assemblies. ¾ Reduce the air velocity to a level which will enable the flame to stabilize. ¾ In modern turbines -Provisions to ensure low NOx Emissions.

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IMPULSE REACTION-TYPE TURBINE DRIVE IMPULSE REACTION-TYPE TURBINE DRIVE The compressor drive turbine is an “impulse reaction”-type designed for maximum efficiency in converting hot-gas flow into rotational mechanical energy. A first-stage fixed nozzle directs flow into the first-stage of rotating blades. The impulse of expanding hot gas upon the lower surface of each rotating blade propels motion in the upward direction. Hot gas flow above the following blade creates a lower pressure above the blade as above an aircraft wing, causing additional rotational force. Subsequent stages operate identically, multiplying the rotational force. Compressor and load-driving turbines consist of a varying number of stages, depending upon the load being driven and other design considerations. The principles of impulse and reaction are described in the above figure. A pure impulse turbine merely deflects the fluid jet through a fixed angle transforming the applied momentum change of the fluid into a torque on the turbine wheel. The reaction process occurs when a gas accelerates through a converging duct and causes a force (thrust) in the opposite direction to the accelerating stream. Modern axial flow turbines use both principles in their design. In fact most turbines today produce torque from an even 50% / 50% split in reaction and impulse forces

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TURBINE TEMPERATURE DISTRIBUTION AND MONITORING Among the most important aspect of turbine operations (along with Vibration Monitoring) is temperature monitoring. The operator must pay very close attention to information coming from the turbine hot section thermocouples because these give the earliest warning of a critically damaging condition developing within the turbine. No matter how well designed the combustion chamber and dilution process may be there remains a radial and circumferential temperature distribution in the combustion products entering the turbine. These are shown in the following diagram with the temperature contours having the appearance of “fried eggs”. Each “fried egg” represents the temperature profile residing in the hot-gasses exiting the combustion chamber.

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This profile will “imprint” itself on the static and rotating sections of the turbine causing temperature gradients in the blade material. If these gradients are too large the blade material will crack even if there were no gas bending momentum or centrifugal loads. High temperature gradients are the most frequent cause of turbine damage and are the result of the combustion chamber and fuel injection system becoming compromised in some way such as to cause an uneven combustion of fuel in the annulus resulting in excessively hot zones. The combustion system can be compromised by blocked fuel injectors, blocked dilution ports, pieces of the combustion liner compromised, or fatigue failure of the combustor mechanical mounting system. Any hot streak conveyed downstream through the turbine will cause oxidation and cracking of blade material and may even cause accelerated creep damage particularly in rotating stages. To provide early warning of a potentially expensive failure of this vulnerable part of the entire turbine we place thermocouples downstream of the combustion system at a point close enough to pick up the temperature gradient, but not so close as to cause thermocouples to fail due to excessive heat.

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COMBUSTION ZONE MONITORING

COMBUSTION ZONES AT START UP Another important aspect of temperature monitoring is the manner in which the “Temperature Zones” (the flow path from each individual fuel nozzle) is distributed across the thermocouples. Even though the thermocouples are position directly in line of the hot gas flow path from the combustion chambers, temperatures indicated on the thermocouples are actually indicated values from adjacent fuel nozzles. The intake air begins a spiral motion as it enters into the axial compressor; this motion is continuous throughout its flow path of the turbine. Due to the high Compressor Discharge Pressure (CDP) of the air entering the combustion chamber and developing into a large volume of air after combustion has occurred, these hot gases exiting the combustion chamber are still flowing in a spiraling motion. Upon exiting the combustion chamber the temperatures of these hot gases are imprinted on thermocouples located several zones away from their origin. In the illustration above the eight combustion zones (made up of several fuel nozzles) are illustrated in different colors representative of the eight different hot gas flow zones. Also illustrated are the eight thermocouples located symmetrically around the turbine. The color indicated on the thermocouples represents the zone from which the temperature measured by the thermocouple is acquired. The illustration above is representative of a turbine at Start Up.

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COMBUSTION ZONE DURING ACCELERATION The Combustion Spread now illustrated shows that the thermal spread from the blue zone has shifted from TC #3 to TC #2 as the unit is accelerating to a Full Speed status.

COMBUSTION ZONE DURING FULL POWER The turbine is now operating at 100% Full Load, again a shift in the Combustion Spread thermal output for the blue zone can be noted by the shift from TC #2 back to TC #1.

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ENGINE CONFIGURATIONS

INDUSTRIAL SINGLE SHAFT

INDUSTRIAL TWIN SHAFT

Single Shaft Vs Two Shaft Engine Configuration The figure above shows the two standard industrial gas turbine shaft arrangements. Industrial single shaft illustration is the traditional single shaft assembly. It consists of the axial flow compressor; Turbine and Power Turbine are all mechanically linked. If we add to this shaft the generator and gearbox we have a shaft system with a high moment of inertia and this is the favored configuration for electrical generation because this provides additional speed (Frequency) stability of the electrical current during large load fluctuations. Industrial twin shaft illustration shows the standard industrial two shaft arrangement with the compressor and turbine only connected and an unconnected power turbine and output shaft that will rotate independently. This configuration is favored for variable speed drive packages such as pumps and compressors because the gas generator or gas producer can run at its own optimum speed for a given load. The two shaft arrangement can still be used for generator drive but its load acceptance capability is generally limited to 1/3 full output at any instant.

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TWIN SHAFT WITH POWER TURBINE

TWIN SHAFT

Aircraft jet engines have for many years been adapted for industrial use as shown in the diagrams above. The twin shaft with power turbine illustration above is essentially a two shaft arrangement with a gas generator originally designed for propulsion. An independently rotating Power Turbine manufactured especially to match the flow of the jet engine is added to the gas path as the power/torque producer. The twin shaft illustration shows a more complicated aero-derivative industrial turbine arrangement. This too, is still essentially a two shaft configuration but the gas generator core (an original jet-engine) was designed with two spools, a Low Pressure Shaft and a High Pressure Shaft. This engine configuration allows the load to be driven from either the exhaust end or the compressor air intake end. Aero-derivative engines are found in both mechanical drive and well as generator drive applications. The most famous grouping in today’s markets are the LM series produced by General Electric.

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SECTION 2A LM2000 DETAILS OF CONSTRUCTION

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LM2000 GAS TURBINE ENGINE Engine Overview The LM2000 consists of a gas generator (GG), power turbine, and output coupling shaft (forward) adapter. The gas generator is composed of a 16-stage high-pressure compressor (HPC), a 2-stage high-pressure turbine (HPT), an accessory drive system, and controls and accessories. The HPC and the HPT rotors are connected by mating splines. The HP rotor turns clockwise when viewed from aft, looking forward. The inlet duct and centerbody are the engine inlet components mounted to the compressor front frame (CFF). The structural frames provide support for the HPC rotor, bearings, compressor stator, HPT rotor, and the power turbine (PT) rotor. These include the CFF, compressor rear frame (CRF), and the turbine mid frame (TMF) in the GG, and the turbine rear frame (TRF) in the power turbine (PT). The PT joins to the GG via a joining kit to produce the gas turbine assembly. The PT is composed of a 6-stage low-pressure turbine rotor, a low-pressure turbine stator, and a TRF. It is aerodynamically coupled to the GG and is driven by the GG exhaust gases. The forward coupling shaft adapter is connected to the PT rotor and provides shaft power to the driven load.

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The GG compressor draws air through the inlet duct, around the centerbody, and through the CFF. The air then travels through the inlet guide vanes (IGV) and passes into the HPC. The amount of airflow in the 16-stage HPC is regulated by IGVs and six stages of variable stator vanes (VSV). The angular position of the VSVs is changed as a function of compressor inlet temperature (T2) and GG speed (NGG). This provides stall free-free operation of the compressor through the wide range of rotor speeds and inlet temperatures. Compressor discharge air is than directed to the combustion section. Hot gases from the combustor are directed into the HPT, which drives the HPC. The exhaust gases exit the HPT and enter the PT, which drives the coupling shaft forward adapter. The forward adapter mates to the packager supplied coupling shaft and drives the output load.

BEARINGS AND SUMPS Bearings and Sumps The two engine shafts are supported by seven bearings in four dry sumps, where synthetic oil is sprayed onto each bearing for cooling and lubrication. Ball bearings maintain axial or thrust positioning of each shaft. Other shaft loads are carried by roller bearings. Each bearing is numbered as it relates to engine station location and type: B for ball, and R for roller. Sumps are alphabetically identified from front to rear in the engine. The GT with a 6-stage power turbine assembly consists of two separate rotating systems: the GG and PT. Seven bearings are used: Located in sump A is 3R: sump B contains bearings 4R and 4B; sump C contains bearings 5R and 6R; and sump D contains bearings 7B and 7R. The GG and GT with a 2-stage PT contain only the first 4 bearings: 3R, 4R, 4B, and 5R.

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The forward end of the gas generator rotor is supported by the No. 3R bearing, which is housed in the CFF A sump. The aft end of the rotor is supported by the No. 4B and the No. 4R bearings, which are housed in the CRF B sump. The No. 5R bearing is a roller bearing supporting the rear shaft of the gas generator turbine rotor. The PT rotor support consists of three bearings: the No. 6R, 7B, and 7R bearings. The No. 6R and 7R bearings are roller bearings mounted on the forward and aft shafts respectively. The no. 7B bearing is a ball bearing mounted on the rear shaft, just forward of the No. 7R bearing. It carries the thrust load of the entire PT rotor. The rolling member of 6R bearing is mounted in the TMF. The 3R, 4R, 4B, 5R, and 7B are matched bearings and inner races. All bearings outer races, except No. 4B, 5R, and 7R are flanged. The No. 4B bearing is retained by a spanner nut across its outer face. The No. 5R and 7R bearings are retained by a tabbed ring which engages slots in the outer race. Bearings No. 3R and 5R, under some conditions, can be lightly loaded. To prevent skidding of the rollers under these conditions, the outer race is very slightly elliptical to keep the rollers turning.

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MAJOR COMPONENTS MAJOR COMPONENTS The illustration above is an exploded view of the LM2000 gas turbine engine which shows the major components of the engine. Each of these components is described in more detail in the following pages of this section: Inlet duct and center body Compressor front frame High-pressure compressor (HPC) assembly High-pressure compressor rear frame assembly Combustor assembly High-pressure turbine (HPT) assembly Turbine midframe assembly Power turbine (LPT) assembly Turbine rear frame assembly Exhaust duct assembly Flexible coupling shaft Accessory gearbox

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INLET DUCT AND CENTER BODY Inlet Duct and Center Body The inlet components direct air into the inlet of the gas generator to provide for smooth, nonturbulent airflow into the compressor. These components consist of the inlet duct and the centerbody. The inlet duct is constructed of aluminum and shaped like a bellmouth. It is bolted to the forward outer flange of the compressor front frame and contains the water wash manifold for injecting liquid cleaning solutions into the compressor. The centerbody is a flow divider bolted to the front of the hub of the compressor front frame. It is sometimes known as the bulletnose, and is available in aluminum or a composite plastic material.

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COMPRESSOR FRONT FRAME Compressor Front Frame The compressor front frame (CFF) forms a flow path for compressor inlet air. It is an assembly made from a single casting of stainless steel. Struts between the hub and outer case provide lubrication supply and scavenge oil for the A sump components. The frame also supports the compressor rotor front bearing, inlet duct, centerbody, forward end of the compressor casing, compressor inlet seals, inlet gearbox (IGB), and the A sump end cover. The frame provides mounting of attachment provisions for the GG front mounts (top and bottom locations) ground handling mounts, P2/T2 probe, and accessory gearbox (AGB) mounts. The frame also contains air passages for sump and seal pressurization and ventilation. The lower frame strut houses the radial drive shaft which transfers power from the IGB to the AGB mounted on the bottom of the frame and compressor case.

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HIGH-PRESSURE COMPRESSOR (HPC) ASSEMBLY High-Pressure Compressor (HPC) Assembly The high-pressure compressor is a 16-stage, high pressure ratio, axial flow design. Major components include the high-pressure compressor rotor (HPCR), high-pressure compressor stator (HPCS), and CRF. The number designations for the stages begins with stage 0 and ends with stage 15. The primary purpose of the compressor section is to compress air for combustion, however, some of the air is extracted for engine component cooling and seal pressurization. Stage 1 and 2 disks have a series of single blade axial dovetails, while each of stages 3 through 16 have one circumferential dovetail groove in which blades are retained. Close vane-to-rotor spool and blade-to-stator casing clearance are obtained with metal spray rub coating. Thin squealer tips on the blades and vanes contact the sprayed material. Abrasive action on the tips prevents excessive rub while obtaining minimum clearance. The compressor discharge pressure (CDP) seal serves to establish a differential pressure load to help balance the differences between axial loads of the HPCR and the HPTR.

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HPC ROTOR ASSEBLY HPC Rotor The high-pressure compressor rotor (HPCR) is a spool/disk structure. It is supported at the forward end by the No. 3 roller bearing, which is housed in the CFF A sump. The rear end of the rotor is supported by the No. 4 ball and roller bearings, which are housed in the CRF B sump. There are six major structural elements and five bolted joints as follows: Stage 1 disk Stage 2 disk with air duct forward interface Stages 3-9 spool Stage 10 disk Stages 11-13 spool with integral aft shaft Stages 14-16 spool A slip fit, single wall air duct that is supported by the aft shaft and the stage 2 disk, routes pressurization air through the center of the rotor for pressurization of the B sump seals. The use of spools reduce the number of joints and make it possible for several stages of blades to be carried on a single piece of rotor structure.

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HIGH-PRESSURE COMPRESSOR STATOR ASSEMBLY HPC Stator The high-pressure compressor stator (HPCS) assembly consists of two M-152 steel forward casing halves and two rear casing halves of Inconel 718, each split horizontally with all four pieces bolted together. They house the compressor variable and fixed vanes, and provide a structural shell between the CFF and the CRF. The HPCS has one stage of IGVs, 16 stages of stator vanes and outlet guide vanes (OGV). The IGVs and stages 1 through 6 are variable, and their angular positions change as a function of T2 and NGG. This variability gives the vane airfoil the optimum angle of attack for efficient operation without compressor stall. The IGV’s and the vanes which make up stages 1 and 2 are constructed of titanium. The vanes used in stages 3-16 are made of A286. The vane positions are controlled by a variable-geometry (VG) control. The variable stator control is an electro-hydraulic system consisting of an AGB mounted hydraulic pump, VSV servo-valve, and VSV actuators with integral linear-variable differential transformers (LVDT) to provide feedback position signals to the off-engine electronic control. The variable vanes are actuated by a pair of torque shafts. Each of the torque shaft forward ends is positioned by a hydraulic VSV actuator. Linkages connect directly from the torque shaft to the actuating rings of the variable vanes.

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The HPCS assembly has three bleed air manifolds. The 8th stage air is ectracted from inside the annulus at the tips of the eighth-stage vanes and is used for sump pressurization and cooling. An air duct which is supported by the front and rear shafts, routes the eight-stage air aft through the rotor for pressurization of the “B” Sump seals. Bleed air extracted between the ninth and tenth-stage vanes is used for turbine frame cooling and balance piston cavity pressurization. Bleed air extracted between the 13th and 14th stage vanes is used for cooling stage 2 HPT nozzles, interstage seal, first and second stage blade shanks, and for PT balance piston cavity pressurization. Borescope ports are provided in the casing at all stages of vanes to permit internal inspection of the compressor.

LM2000 HPC COMPRESSOR STATOR CASING AND ROTOR

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HIGH-PRESSURE COMPRESSOR REAR FRAME ASSEMBLY High-Pressure Compressor Rear Frame Assembly The CRF assembly is made of Inconel 718 and consists of the outer case, the struts, the hub, and the B sump housing. Its outer case supports the combustor, fuel manifold(s), 30 fuel nozzles, one igniter plug (two igniters are an option) and stage 2 HPT nozzle support. To provide compressor discharge air for customer bleed, an internal manifold within the frame extracts air from the combustion area and routes it through struts 3, 4, 8, and 9. The HPC discharge temperature (T3) is monitored by two T3 sensors mounted on the CRF. Six borescope ports located in the frame permit inspection of the combustor, fuel nozzles, and stage 1 HPT nozzle. Two borescope ports are provided in the rear portion of the case for inspection of the HPT blades and nozzles. The B sump housing is fabricated from Inconel 718 and attaches to the CRF. The housing forms the sump cavity and supports the sump seals, No. 4 race, No. 4 bearing and lube jet. To provide for differential thermal growth between sump service tubing and the surrounding structure, the tubes are attached only at the sump and have slip joints where they pass through the outer struts ends. The CRF, in conjunction with the combustor cow assembly, serves as a diffuser and distributor of compressor discharge air. The diffuser provides uniform low velocity air to the combustor.

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COMBUSTOR ASSEMBLY Combustor Assembly The combustor is of a singular annular design consisting of four major components: cowl (diffuser) assembly, dome, inner liner, and outer liner. The combustor assembly is mounted in the CRF, and is held in place by 10 equally spaced mounting pins. These pins provide axial and radial location and assure centering of the cowl assembly in the diffuser passage. Cowl Assembly The cowl assembly, in conjunction with the CRF, serves as a diffuser and distributor for the compressor discharge air. It furnishes uniform air flow to the combustor throughout a large operating range, providing uniform combustion at the turbine. The cowl assembly consists of a machined ring and inner and outer cowl inlets welded to the inner and outer cowl wall.

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Dome The dome houses 30 vortex-inducing axial swirl cups (one at each fuel nozzle tip). The swirl cups provide flame stabilization and mixing of the fuel and air. The interior surface of the dome is protected from the high temperature of combustion by a cooling-air film. Accumulation of carbon on the fuel nozzle tips is prevented by venturi-shaped spools attached to the swirler. Combustion Liners The combustor liners are a series of overlapping rings joined by resistance welded and brazed joints. They are protected from the high combustion heat by circumferential film-cooling. Primary combustion and cooling air enters through closely spaced holes in each ring. These holes help to center the flame and admit the balance of the combustion air. Dilution holes are employed on the outer and inner liners for additional mixing to lower the gas temperature at the turbine inlet. Combustion/turbine nozzle air seals at the aft end of the liner prevent excessive air leakage while providing for thermal growth.

IGNITION SYSTEM Ignition System The ignition system produces the high-energy sparks that ignite the fuel/air mixture in the combustor during starting. The system consists of a high-energy spark igniter, a high-energy capacitor-discharge ignition exciter, and an interconnecting cable. A redundant ignition system that replaces a plug in the compressor rear frame is also available. The ignition cables interconnect directly between the package-mounted exciter and igniters, which are mounted on the engine compressor front frame. During the start sequence, fuel is ignited, which is energized by the ignition exciter. Once combustion becomes self-sustaining, the igniter is deenergized.

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Ignition Exciter

HIGH-PRESSURE TURBINE ASSEMBLY

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High-Pressure Turbine Assembly The LM2000 HPT is an air-cooled, 2-stage design with high efficiency. The HPT section consists of the rotor and the stage 1 and 2 HPT nozzle assemblies. The HPT nozzles direct the hot gas from the combustor onto the HPTR blades at the optimum angle and velocity. The HPTR extracts energy from the exhaust gas stream to drive the HPCR to which it is mechanically coupled.

HIGH-PRESSURE TURBINE ROTOR ASSEMBLY HPT Rotor The HPTR consists of a forward shaft, two disks with air-cooled blades and blade retainers, a rotor spacer, a thermal shield, and an aft shaft. The forward HPT shaft transmits energy to the HPCR. Torque is transmitted through the spline joint at the forward end of the shaft. Two air seals are attached to the forward end of the shaft. The forward seal prevents CDP from directly entering the B sump. The aft seal maintains CDP in the plenum formed by the rotor and the combustor. This plenum is a balance chamber that provides a force that maintains the proper thrust load on the No. 4 ball bearing. The inner rabbet diameter on the forward shaft rear flange provides a positive radial location for the stage 1 blade retainer and a face seal for the rotor internal cooling air. The outer rabbet diameter on the flange provides location for stage 1 disk and stability for the rotor assembly.

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The spacer provides additional stability, and transmits torque from the stage 2 disk to the stage 1 disk. The thermal shield located between the two disks forms the outer portion of the turbine rotor cooling air cavity, and serves as the rotating portion of the interstage gas path seal. The HPTR is cooled by a continuous flow of compressor discharge air that passes through holes in the forward turbine shaft. The air cools the inside of the rotor and both disk before passing between the dovetails and out to the blades.

HIGH-PRESSURE TURBINE BLADE COOLING High-Pressure Turbine Blade Cooling Stage 1 High-Pressure Turbine Blades—The first-stage turbine blades, contained within the CRF, are internally cooled with HPC discharge air. The HPC discharge air is directed through the turbine disk to the blade roots, passing through inlet holes in the shank to serpentine passages within the airfoil section of the blade. This air finally exits through nose and grill holes in the leading edge of the blades, where it forms an insulating film over the airfoil 2-36

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surface through holes in the cap at the outer end of the blade and through holes in the trailing edge of the airfoil. Stage 2 High-Pressure Turbine Blades—Because the hot-gas path stream is cooler when it reaches the second-stage turbine blades, the cooling required to maintain a suitable metal temperature is not as great as with the first stage. The second stage blades are, therefore, only cooled by convection. The air passes through passages within the airfoil section and is discharged only at the blade tips.

HIGH-PRESSURE TURBINE STAGE 1 NOZZLE COOLING High-Pressure Turbine Stage 1 Nozzle Cooling Stage 1 HPT Nozzle- The stage 1 HPT nozzle directs high pressure gases from the combustion section onto stage 1 turbine blades at the optimum angle and velocity. The nozzles are coated to improve corrosion and oxidation resistance. There are 32 nozzle segments, each segment consisting of two vanes. The nozzle vanes are air cooled by convection and film cooling with compressor discharge air that flows through each vane. Internally, the vane is divided into the forward cavities. Air flowing into the forward cavity is discharged through holes in the leading edge and through gill holes on each side close to the

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leading edge to form a thin film of cool air over the length of the vane. Air flowing into the aft cavity is discharged through additional gill holes and trailing edge slots.

HIGH-PRESSURE TURBINE STAGE 2 NOZZLE COOLING High-Pressure Turbine Stage 2 Nozzle Cooling Stage 2 HPT Nozzle- The stage 2 nozzle directs the high pressure gases exiting from stage 1 turbine blades onto stage 2 turbine blades at the optimum angle and velocity. The stage 2 nozzle assembly is air cooled by convection. The nozzle vane center area and leading edge are cooled by air (stage 13) which enters the nozzle through the cooling air tubes. Some of the air is discharged through holes in the trailing edge, while the remainder flows out through the bottom of the vanes and is used for cooling the interstage seals and thermal shields. The turbine shrouds form a portion of the outer aerodynamic flow path through the turbine. They are located radially in line with the turbine blades and form a pressure seal to prevent excessive gas leakage over the blade tips.

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Interstage Seal The interstage seal assembly attaches to the nozzle segment. The seal controls the gas leakage between stage 2 nozzle and the turbine rotor. The sealing surface has three teeth for minimum temperature rise across the teeth. The interstage seal consists of casting brazed to a honeycomb surface. The seals are pregrooved to preclude seal rub under emergency shutdown conditions when thermal contraction would cause surface contact.

INTERSTAGE SEAL

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TURBINE MIDFRAME ASSEMBLY Turbine Midframe Assembly The turbine midframe assembly supports the aft end of the HPTR and the forward end of the PT rotor. It is bolted between the rear flange of the CRF aft outer case and the front flange of the PT stator. The frame provides a smooth diffuser flow passage for HPT discharge air into the PT. Piping for bearing lubrication and seal pressurization is located within the frame struts. The frame contains ports for the PT inlet thermocouples (T4.8) and pressure probe (PT4.8). These ports can be used to provide access for borescope inspection of the PT inlet area. The PT stage 1 nozzle assembly connects to the TMF assembly. The hub is a one piece casting with flanges to support the sump housing, stationary seals, inner liner support, and PT stage 1 nozzle support. The sump housing is bolted to the forward flange of the hub. The sump housing is of double wall construction. The liner assembly consists of an inner and outer liner and airfoil shaped strut fairings. The strut fairings incorporate a slip joint feature to accommodate thermal expansion. This liner assembly guides the gas flow and shields the main structure from high temperature. The liner

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assembly is supported at the forward end by inner and outer liner supports. Seals at both ends of the inner and outer liners are provided to prevent excessive leakage of cooling air from behind the liner assembly. Cooling air for the assembly is supplied from stage 9 HPC bleed air through five of the support struts.

POWER TURBINE (LPT) ASSEMBLY Power Turbine (LPT) Assembly The PT is a 6 stage aeroderivitive turbine suited for 3000 – 3600 rpm output speeds. The PT assembly consists of a turbine rotor, stator, rear frame, and a high speed coupling shaft. Power Turbine Rotor The PT rotor is a 6 stage low-pressure turbine rotor mounted between the No. 6 roller bearing, housed in the TMF C sump, and the No. 7 ball and roller bearings housed in the TRF D sump. It consists of six disks, each having two integral spacers, one on each side (except for stages 1

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and 6). Stage 1 has a seal at the forward end. Each disk spacer is attached to the adjacent disk spacer by close-fitting bolts. The front shaft is secured between stage 2 seal spacer and stage 3 disk, and the rear shaft between stage 5 disk and stage 6 rotating seal spacer. Blades of all six stages contain interlocking tip shrouds for low vibration levels and are retained in the disks by dovetails. Rotating seals, secured between the disks, mate with stationary seals to prevent excessive gas leakage between stages.

POWER TURBINE (LPT) ASSEMBLY Power Turbine Stator The PT stator consists of two casing halves split horizontally, stages 2 through 6 turbine nozzles, and six stages of blade shrouds. Stages 2 to 3 nozzles have welded segments of six vanes each. Stage 1 nozzle is assembled to the TMF assembly. The PT stage 1 turbine nozzle consists of 14 segments of six vanes each. The inner end is attached to the nozzle support, and the outer end is secured to the outer nozzle support ring which is secured between the frame aft flange and the PT stator front flange.

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Honeycomb shrouds, mounted in casting channels, mate with the shrouded blade tips to provide close-clearance seals and to act as a casing heat shield. The stationary interstage seals are attached to the inner ends of the nozzle vanes to maintain low air leakage between stages. Insulation is installed between nozzles/shrouds and casing to protect the casting from the high temperature of the gas stream. A liner installed for stages 1 through 3 isolates the casing from flow path gases.

TURBINE REAR FRAME ASSEMBLY Turbine Rear Frame Assembly The turbine rear frame (TRF) consists of an outer casing, eight radial struts, and a single-piece cast steel hub. The TRF forms the power turbine exhaust flowpath and supports the aft end of the power turbine stator case. It also provides a mounting flange for the outer cone of the exhaust system and provides attaching points for the gas-turbine rear supports. The hub supports a bearing housing for the No. 7 ball and No. 7 roller bearing. The hub and the bearing housings have flanges to which air and oil seals are attached to form the D sump. The struts contain service lines for lubrication supply, and sump scavenging and venting. The power turbine speed transducers are also mounted in the struts.

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EXHAUST DUCT ASSEMBLY

Exhaust Duct Assembly The exhaust duct consists of the inner and outer ducts, forming the diffusing passage from the power TRF. The diffusing section recovers a portion of the kinetic energy of the exhaust gases, leaving the power turbine before the 90-degree turn in the exhaust duct. The inner diffuser duct can be moved aft to obtain access to the coupling shaft. The exhaust duct is independently supported from the gas turbine base structure. Piston ring-type expansion joints are used to accommodate the thermal growth between the TRF and the exhaust duct.

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FLEXIBLE COUPLING SHAFT Flexible Coupling Shaft The high-speed coupling shaft consists of a forward adapter which mates with the power turbine, two flexible couplings, a distance piece, and an aft adapter. The aft adapter mates with the connected load. The forward and aft adapters are connected to the distance piece by the flexible couplings. The flexible couplings allow for axial and radial deflections between the gas turbine and the connected load during operation. Inside the aft adapter and the rear flexible coupling is an axial damper consisting of a cylinder and a piston assembly. The damper system prevents excessive cycling of the flexible coupling. Anti-deflection rings restrict radial deflection of the couplings during shock loads.

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ACCESSORY GEARBOX Accessory Gearbox Engine starting, lubrication, and speed monitoring of the compressor rotor is accomplished by accessories mounted on the accessory gearbox (AGB). The AGB consists of an inlet gearbox (IGB) located in the hub of the compressor front frame, a radial drive shaft inside the 6:00 o’clock position strut of the front frame, and a transfer gearbox (TGB) attached to the AGB. Both the TGB and the AGB are bolted underneath the front frame. • • • • • •

The following accessories can also be mounted on the AGB: Hydraulic or pneumatic starter Engine lube oil and scavenge pump Variable-geometry hydraulic oil pump Two magnetic speed pickups Air-oil separator

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ENGINE OPERATING PARAMETERS The major engine components, sensors, and important operating parameters are illustrated above.

HPC rpm (NGG) HPC Discharge Temperature (CDT, T3) HPC Discharge Pressure (CDP, PS3) PT rpm 60 Hz (NPT) PT rpm 50 Hz (NPT) PT Inlet Temperature (TIT, T5.4) Maximum Time Allowed For Ignition Maximum Time To Reach Starter Cutout Maximum Time To Reach Idle

Idle

Maximum Power

Maximum Operating Limit

6,8000 – 7,400 285 – 365

10,100

10,050

835 – 890

935

40 – 55

280 – 320

300 - 335

0 - 3,600 0 - 3000 1,455 – 1,592

1,535

1,150 – 1,350 20 seconds after fuel ignition

HPC (NGG) ≥ 4500 rpm at 90 seconds HPC (NGG) ≥ 6050 rpm at 120 seconds

ENGINE OPERATING PARAMETERS The engine-mounted sensors noted in the chart supply data for the fuel governor and sequencing systems that will be discussed in the Turbine Control System – System Operator Interface section. Inlet guide vanes, and VSVs are controlled by independent software algorithms in the offengine control system. The VG components are positioned by electro-hydraulic actuators with LVDTs for position feedback to the control system. Hydraulic supply pressure for the VG system is derived from the turbine lube oil system and will be discussed in the Turbine Lube Oil System section.

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DEFINITIONS FOR ALARM AND SHUTDOWNS For Shutdowns the following symbols must be verified for proper sequence of operation to verify Shutdown Conditions: FSLO Fast Stop Lockout Without Motor – Trips breaker, fuel shutoff immediately, chops steam and water. Can only be reset from the Turbine Control Panel. FSWM Fast Stop – Starter motor is engaged for 7.5minutes when NGG goes below 1700 RPM. Can only be reset from the Turbine Control Panel. Note: If T4.8 is = 8000 rpm If pressure < 15 PSIG (103 kPag)& NGG >= 8000 rpm

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Scavenge Oil Pressure Transmitter (PT-1022) Scavenge Oil pressure transmitter (PT-1022) provides for remote observations of scavenge oil pressure from the turbine. There is high-pressure alarms set point within the monitoring system. They are as follows: Alarm = 110 psig(758 kPag) INCR Temperature Element (TE-1028) Temperature Element (TE-1028) provides for remote monitoring of turbine supply oil temperature. There are low /high temperature alarms and trip set point within the monitoring system. They are as follows: Shutdown = Alarm = Shutdown = Alarm =

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200 ºF (93 ºC) INCR 190 ºF (88 ºC) INCR 90 ºF (32 ºC) DECR if NGG < 6800 rpm 20 ºF (-6 ºC) DECR

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VSV Actuator Pump

VARIABLE STATOR VANE ASSEMBLY Stator vane position is vital to stable, efficient operation of the engine. While the HPC is designed for peak aerodynamic efficiency at full power and full speed, it must also operate at lower speeds. At these lower speeds, the later stages of the compressor cannot consume all the air delivered by the earlier stages. The variable stators accommodate this situation by limiting the compression ratio of the first six stages of the compressor at low speeds and changing the compression at higher speeds.

Typical VSV Actuator System

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Variable Geometry Hydraulic Pump The variable geometry hydraulic pump is a positive displacement pump that draws oil form the turbine supply filter discharge header and supplies the hydraulic control unit (HCU) with the correct oil flow and pressure to move the variable stator vanes (VSVs) to the required position. The pump is mounted on and driven by the accessory gearbox. Variable Geometry Hydraulic Pump Oil Filter The VG pump filter is mounted near the VG pump, on the engine accessory gearbox. The filter has a pressure differential switch set at 30 psid (138 kPad) that sends a signal to the turbine control system for alarm indication. Hydraulic Control Unit (HCU) The hydraulic control unit receives position signals from the turbine control system. The HCU houses torque motor-positioned hydraulic servos to direct hydraulic fluid at regulated pressure to the VSV actuators or to the bypass position. Variable Stator Vane Actuators There are two variable stator vane (VSV) actuators. The actuators are double-acting hydraulic cylinder-piston type actuators. The HCU pressures on one side of the piston and vents the opposite side to position the VSV’s. Positioning of the VSV’s is accomplished with two hydraulic actuators, one at the 3:00 o’clock position and one at the 9:00 o’clock position. Each actuator uses an LVDT for position feedback to the control system. The control system is designed to provide excitation and signal conditioning for both LVDT’s and to control VSV position by means of closed-loop scheduling of VSV actuator position based on corrected HP rotor speed and inlet temperature.

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TURBINE GAS FUEL SYSTEM

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Gas Fuel System

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GAS FUEL SYSTEM The turbine engine operates on gaseous fuel (natural gas). For a detailed description of the internal fuel supply and combustion system for the turbine engine, see GE publication GEK97310 in Chapter 5 of the O&M manual. Refer to the fuel system drawing 20063-01-683260 in Chapter 7. Customer-supplied gas fuel is provided with a flow rate of 250 MMBtu/hr, maximum, a temperature of 250 °F, maximum, and a pressure of 365 to 405 psig. Gas fuel must meet General Electric quality requirements per specification MID-TD-0000-1. Refer to Appendix A the O&M manual for further information on GE’s fuel specifications.

Turbine Gas Fuel System Screen Display

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Main Skid At the main skid, gas fuel enters through a ball valve (not supplied by GE). A 100-mesh, Y-type strainer removes any large, entrained particles. Inlet flow rate is monitored by flow element FE2000, and flow indicator FI-2000 displays the totalized flow in pph/scfm. Inlet flow temperature and pressure are monitored by temperature element TE-2032 and pressure transmitter PT-2027, respectively. Based on the readings from TE-2032, an alarm is activated for fuel temperatures above 275 °F. At temperatures above 300 °F, a Cool Down Lockout (CDLO) shutdown is initiated. At temperatures above 325 °F, a Fast Stop Lockout Without Motor (FSLO) shutdown is initiated. Based on the readings from PT-2027, an alarm is activated at fuel pressures above 600 psig. At pressures above 650 psig or below 185 psig, an FSWM shutdown is initiated. In addition, when the fuel pressure at PT-2027 is less than 195 psig and the NGG speed is less than or equal to 7000 rpm, an alarm is issued. An alarm is also issued at pressures less than 320 psig when the NGG speed is greater than 7000 rpm. A 3/8" line branches from the main fuel supply line pressure upstream of the fuel shutoff valves. A combination gas fuel pressure control valve, which includes pressure regulator PCV-2025 (set at 80 psig), pressure relief valve PSV-2025 (set at 100 psig), and pressure indicator PI-2025, controls fuel pressure to the shutoff valve actuators. Fuel pressure is also monitored prior to entering the gas manifold by pressure transmitter PT2028. Fuel Shutoff Valves And Safety Venting Fuel flow to the combustor is regulated by two fuel shutoff valves. Solenoid actuated fuel shutoff valves FSV-2006 and FSV-2007 are quick-closure valve assemblies located upstream and downstream, respectively, from the fuel control valve FCV-2001. These fail-close valves are either fully open to allow fuel flow, or fully closed to prevent fuel flow. During startups, the control system first opens shutoff valves FSV-2006 and FSV-2007. Fuel flow is then adjusted by fuel metering valve FCV-2001. At shutdown, fuel gas is vented from the shutoff valves and interconnecting supply line by two paths. Shutoff valve FSV-2007 includes a quick exhaust valve assembly, which allows rapid closure of the valve and vents gas to a safe area via customer connection [11]. The shutoff valve actuators are vented to a safe area at customer connection [24].

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Fuel Shut-Off & Metering Valves Fuel Metering Valve Fuel metering valve FCV-2001 is installed with an electrically controlled, proportional actuator that is controlled by signals from the TCP. This Woodward metering valve incorporates precise valve positioning data, which together with fuel temperature and pressure measurements can be used to calculate the fuel flow rate. Refer to the Woodward documents in Chapter 5 of this manual for details on valve operation. The fuel metering valve is a rotary sleeve-and-shoe throttling valve in which the metering port area is determined by input shaft positioning from the actuator. The valve is spring-loaded to the minimum fuel direction, so loss-of-signal and loss-of-power situations cause a fuel shutdown. Between 50 and 40,000 pph of natural gas can be metered by the valve. The fuel metering valve actuator is an electro-hydraulic proportional device in which a torque motor servo-valve is energized by the electric control (from the TCP) to generate a pressure differential applied to operate the spool valve. Supply pressure is regulated by the spool valve to move a double-acting servo piston and provide terminal shaft output. Internal mechanical feedback is standard; GE AE also uses the electrical position feedback transducer for fail-safe operation. From the fuel gas control valve the fuel gas flows to the downstream shutoff valve, to the fuel gas manifold and then to one of the thirty fuel nozzles. 2262533TR

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Exhaust Collector Drain Exhaust Collector Drain Liquid Fuel System Significant amounts of flammable liquids and water wash solution may accumulate in the turbine exhaust collector. The exhaust collector drain system eliminates these accumulations to ensure safe starts. A flexible drain line routes accumulations from the collector to the fuel drain line through pneumatically operated, normally open FCV-2005. 8th-stage bleed-air manifold bleed air pressure is utilized to close the drain valve FCV-2005. As the turbine speed increases, positive pressure developed in the exhaust collector forces the condensate, water wash and liquid fuel that has accumulations in the exhaust duct out through the drain valve FCV-1205. The fluid is then routed through a check valve, and the manual fuel drain valve to customer connection.. As the turbine speed continues to increase, 8th-stage bleed air increases. When the pressure rises to 50 psig (344 kPag), FCV-2005 closes. The collector drain remains closed during normal operation.

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TURBINE WATER WASH SYSTEM

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Water Wash System Screen Display

COMPRESSOR WATER WASH SYSTEM THEORY OF OPERATION The water wash system provides a mechanism for cleaning engine compressor blades to increase compressor efficiency and improve engine power output versus fuel burned. There are many types of compressor fouling. The type and rate of fouling depend on the environment in which the gas turbine operates and the type of inlet filtration. Among the most common types of contaminants are: • Dirt or soil • Sand • Seashells • Coal dust • Insects • Salt (Corrosion) • Oil • Turbine exhaust gas Salt, aside from being a contaminant by itself, also causes corrosion of blading and ductwork and subsequent ingestion of rust and scale. Oil increases the ability of contaminants to cling to compressor passages and airfoils. The type of material that is deposited on the compressor blading influences the method of its removal. In other words, some material will respond to one cleaning media, others to another.

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Keeping the compressor internals clean can alleviate a number of problems before they ever come apparent. Besides the obvious benefits of enhanced efficiency (increased power output, lower T-3 temperatures, etc.), keeping the HPC clean will help in blades survive longer. If the compressor is dirty, additional weight is added to the airfoil and this increases the cyclic stress. Also, dirt in the dovetail slots will add to the existing friction loading at the dovetail/slot interface and between the two mechanisms a blade dovetail failure becomes more likely. Performing thorough water washes with high quality ingredients on a regular basis with help combat these conditions. Method of Detection There are two basic methods for determining the cleanliness of the compressor. Visual inspect and performance monitoring. Visual inspection: The best method for detecting a fouled compressor is visual inspection. This involves shutting the unit down, removing inlet plenum inspection hatch, and visually inspect compressor inlet, bellmouth, inlet guide vanes, and early stage blading. If any deposits, including dust or firmly deposits can be wiped or scraped off these areas, the compressor is fouled sufficiently to affect performance. The initial inspection also reveals whether the deposits are oily or dry. For oily deposits, a water-detergent wash is required followed by a clean water rinses. Location of the source of the oil and correction should be accomplished before cleaning to prevent recurrence of the fouling. Performance monitoring: A second method for detecting a fouled compressor is performance monitoring. Performance monitoring involves obtaining gas turbine data on a routine basis, which in turn is compared to baseline data to monitor trends in the performance of the gas turbine. The performance data is obtained by running the unit at steady on base load and recording output, exhaust temperatures, inlet air temperatures, barometric pressure, compressor discharge pressure and temperature, and fuel consumption. The data should be taken carefully with the unit warmed up. If performance analysis indicates compressor fouling, it should be verified by a visual inspection.

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Water Wash F&ID 683262

Water Wash Manifold Supply

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Turbine Inlet with On-Line Water Wash Ring and FOD Screen

TURBINE WATER WASH SYSTEMS Introduction Optimal turbine performance is achieved by periodically cleaning compressor stages of the gas turbine. The water wash system provides for washing the turbine when the turbine has been shut down for maintenance (off-line water washing). Off-line water washing may not be initiated until engine surface temperature is < 200 °F (93 ºC). Refer to F&ID 020020-01-683262, Water Wash System, provided in Chapter 7. Additional details on the turbine water wash system can be found in vendor documentation provided in Chapter 5 of the O&M manual. This section provides an overview of a typical turbine water wash system.

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Specifications governing water wash quality, approved cleaning agents, and antifreeze solutions have been included in Appendix A of GE publication GEK-97310 located in Chapter 5 of the O&M manual. Turbine Water Wash Operation The customer supplies the recommended amount of chemical concentrate (solvent) through the soap and water fill funnel and the recommended amount of water through water inlet. If necessary, the customer can add antifreeze for engine protection during cold-weather washing. The normal recommended chemical to water mixture is 1:4 (1 part chemical and 4 parts water). After permissives have been met, valves open to allow the wash solution to enter the manifold and spray nozzles using customer connection [72] for an on-line water wash and customer connection [72B] for an off-line water wash. The wash solution is pumped and filtered before entering the main skid. For the wash cycle to begin, SOV-5034 admits the compressed air, filtered to 5 µ, absolute. The air is then regulated by PCV-5028 before entering the diaphragm pump/pneumatic master assembly. Wash cycles last 10 minutes, after which, a purge cycle occurs automatically. The purge cycle uses instrument or compressed air, filtered to 5 µ, absolute, for 1 minute at a pressure of 100–120 psig (689-827 kPag). If a rinse cycle is used, rinse water temperature should range between 150 °F (66 ºC) and 180 °F (82 ºC). After rinsing, drain and clear the tank prior to the next water washing. Off-Line Water Wash System The off-line water wash (referred to as a crank-soak wash) consists of the following cycles: • wash • purge • soak (10 min) • rinse • purge • start Initiate an off-line water wash only after the engine surface temperature is < 200 ºF (93 ºC). Turbine Water Wash Features Water wash equipment located on the main skid consists of a manifold and spray nozzles and solenoid operated valves. Water Wash Tank The water wash tank, located on the water wash cart, has a 45-gal (170L) capacity and receives water and chemical concentrate through customer inlet. The tank is designed to withstand temperatures of 180 ºF (82 ºC).

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Water Wash Cart Water Wash Manifold and Spray Nozzles One manifold services the turbine engine during an off-line water wash and one manifold services the turbine engine during an on-line water wash. Typically, the off-line manifold has nozzles that produce micron droplets at a flow rate of 15 gpm (57 lpm). Water Wash Gauges and Valves The ball valve on the tank drain line is normally closed during non-wash cycles. During off-line water wash, wash solution is applied to the atomizing nozzles at 15 gpm (57 lpm) through a 50-µ filter. Solenoid-activated valve SOV-5032 admits off-line wash solution to turbine inlet port S1. Off-line water wash may not be initiated until gas turbine surface temperatures are less than 200 °F (93 ºC).

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Turbine Compressor Cleaning The water wash provisions are designed to meet the minimum water wash requirements given in the GE manual, GEK-97310, and to minimize exposure of service personnel to concentrated cleaning solvents. For specific guidelines on cleaning scheduling and recommended solvents, see GE manual, GEK97310, in Chapter 5 of the O&M manual. Permissives For Start Of Offline Water Wash • Turbine Crank Permissive, ref section. • T48 < 93°C • T3 < 93°C • Ambient temperature (TE 4082) > 10°C If ambient temperature < 10°C the operator must confirm that anti-freeze has been added to water wash fluid by selecting a Antifreeze button on the HMI. Operator will initiate start of water wash sequencing from HMI, and the logic will perform the following: 1)

The hydraulic starter system is started in a Manual Crank mode.

2)

The control signal to the hydraulic starter is set to accelerate the GG shaft to 1200 rpm.

3)

Open VSV.

4)

While accelerating, initiate flow of wash solution to the water wash manifold by opening the water wash supply valve (SOV 5010).

5)

At 1200 rpm, de-energize the starter, close the water supply valve, and let engine speed decrease to 100 rpm.

6)

At 100 rpm, energize the starter, open the water supply valve, and repeat the cycle until the solution is used up.

7)

Upon completion of the injection of the total amount of wash solution, the operator shall give a stop water wash command from the HMI.

8)

Deactivate the hydraulic starter.

9)

Close VSV.

10) A Normal stop is performed.

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11) Begin 10 minute soak timer – displayed on HMI. Once the soak time is finished, the operator is to rinse the engine by repeating the above procedure. The turbine should now be started and run at Core Idle speed for 5 minutes to dry. If this operation has not started after 10 minutes an alarm shall be announced to warn the operator. OPERATOR SCREENS The GTG Overview screen allows basic monitoring and control of the overall system. Control functions are accessed by faceplate pop-ups. Each control faceplate allows operator interaction and gives associated feedback. The screens displayed by the system software show criticaloperating parameters and system set points. Each screen and the information that it contains may be accessed by pressing its corresponding function. Refer to the Water Wash System Operator Screens.

Water Wash Screen

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VENTILATION AND COMBUSTION AIR SYSTEM

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Ventilation and Combustion Air System 012 The ventilation and combustion air system of the GTG set supplies filtered combustion air for turbine engine operation and filtered ventilation air for the turbine compartment. The verticallymounted turbine air filter module supplies combustion air to the gas turbine and ventilation air to the turbine compartment. The air filter house has been equipped with platforms, ladders, support legs, drift eliminators, pre-filter pads, and high efficiency filter elements.

Ventilation and Combustion Air System

FUNCTIONAL DESCRIPTION Refer to Ventilation and Combustion Air System figure, and Dwg. 20063-01-649239, Ventilation and Combustion System for the following discussion. The gas turbine engine and the turbine compartment supply fans draw filtered air from the vertically mounted filter module for turbine combustion and compartment ventilation, as previously described. The airflow is provided as two discrete streams: one stream provides a 115,000-scfm (3256-scmm) airflow for combustion in the turbine engine, the other provides 30,000-scfm (850-scmm) airflow for positive pressure turbine compartment ventilation. During normal operation, the airflow is as follows: Air, drawn by the turbine engine and direct drive ventilation fans, flows through the trash screens, drift eliminators, filter elements and enters the plenum of the air filter module. The trash screen inhibits large items from entering into the air stream and the drift eliminator removes moisture 2262533TR

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from the air stream. Gauge PDT-4005 monitors the pressure differential across the filters. PDT4005 signals pressure indicator PDI-4005 which displays the pressure drop across the filter elements. PDT-4005 activates alarm PDAH-4005 when the pressure differential reaches 5 in-Wg, while pressure differential transmitter PDT-4005 initiates a CDLO shutdown when the pressure differential reaches 8 in-Wg. Data from these transmitters is forwarded, in the form of 4–20-mA signals, to the electronic-control system for display on the DCS computer monitor. An alarm is also activated by temperature element TE-4082 should air temperature at the pre-filter intake fall to 43 °F. Exiting the air filter assembly, the airflow is provided as two discrete streams. Turbine Combustion Intake Airflow from the air intake assembly passes to the gas turbine engine through the air-inlet silencer, which reduces the noise from the turbine inlet to 85 dB(A). From the silencer, the air passes through a 2000-µ bellmouth screen cover before entering the turbine bellmouth. Combustion airflow, at a nominal rate of 150,000-scfm (3256 scmm) upon initial cleaning, enters the turbine engine, where it is mixed with fuel and burned in the combustor section. Exhaust from the gas turbine engine is expelled through exhaust ducting to the exhaust stack and out to atmosphere. Turbine Compartment Ventilation One of two turbine compartment fans draws air from the inlet air filtration system and ducts the ventilation air directly into the turbine room through 84 dB(A) silencers and backdraft dampers. Either of the two large, axial-flow fans, driven by 63 hp, 380 VAC, 3-phase motors, are capable of drawing up to 850 scmm of air, while the other remains on standby. The standby fan kicks in if pressure differential switch (PDT-4007) indicates low pressure, or if exit air temperature switch is activated by rising exit air temperature. PDT-4007 monitors the differential pressure inside the enclosure and will initiate an alarm to the control system if the differential pressure drops to .1 WG decreasing. Temperature element TE4054 monitors the turbine room temperature. If turbine room temperature reaches 140 °F (60 °C) increasing, TE-4054 initiates an alarm through the control system, and at 150 °F (66 °C) increasing, initiates a slow decel to min load (DM). Temperature element TE-4001 monitors enclosure exhaust air temperature. If exhaust temperature reaches 200 °F (93 °C) increasing, TE4001 activates an alarm. Ventilation air, having exchanged heat with the mechanical components, is forced up through the enclosure roof and expelled to the atmosphere through a fire protection damper and exhaust silencer, which limits noise at the outlet to 92 dB(A). The fire protection damper is counterweighted to enable pressure trip devices to remotely release the dampers when a fire is detected by the fire protection system. The fire protection damper trips only when the CO2 system is activated. The counterweights close the fire dampers to seal the turbine compartment while the compartment is flooded with extinguishing agent. The fire protection system must be reset manually.

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The main turbine terminal box, or MTTB, is provided with two air conditioners, MOT-4019A and MOT-4019B, to provide cooling or heating for the electronic components inside. RTD TE-4090 monitors the temperature of the MTTB and activates alarms TAH-4090 and TAL-4090 when MTTB temperature is ≥ 125 °F or ≤ 0 °F respectively.

Ventilation and Combustion Air System Generator Ventilation Airflow The generator is equipped with a separate ventilation system that includes inlet filters, inlet and exhaust silencers, and pressure and temperature sensors. The generator rotor is equipped with fan blades to produce a cooling airflow through the interior of the generator. The blades draw ambient filtered air into the generator and around its internal parts before expelling the now heated air through the generator exhaust vent. Refer to F&ID 20063-01683239, Ventilation and Combustion System, in Chapter 4 of this manual. During normal operation, the airflow is as follows: Air drawn through the inlet filters is monitored by pressure differential transmitter PDT-4008 and PDT-4009. The pressure differential transmitter initiates alarm PDAH-4008 and PDAH-4009 air pressure is ≥ 1.2" (2.5mm) WG. Data from these devices, in the form of 4–20-mA signals, is forwarded to the electronic-control system. The normally-open contacts of this switch also act as a start permissive, and will prevent turbine start if closed.

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Generator Temperature Monitoring Six RTDs (TE-4021A thru TE-4023B) mounted inside the generator at the stator monitor the temperature of the stator windings, activating an alarm at 273 °F (134 °C) and initiating an FSLO shutdown at 291 °F (144 °C). The exciter RTD TE-4031 activates an alarm at 194 °F (90 °C) and initiates a CDLO shutdown at 212 °F (100 °C). Three spares have been provided in case the primary stator RTDs fail. Two spare RTDs have been provided to monitor the inlet airflow temperature. RTD TE-4030 monitors the temperature of the airflow exhausted from the generator, activating an alarm at 194 °F (90 °C ) and initiating a CDLO shutdown at 212 °F (100 °C). Airflow from the generator hood, having exchanged heat with the generator’s external components, is expelled through the ceiling-mounted silencer. For more information on the generator, refer to the Meidensha generator manual in Chapter 5 of this manual set. A heating element HE-4050 is incorporated in the generator and is activated whenever the unit is shut down. This will prevent moisture from accumulating inside the generator due to outside temperature conditions. A heating element HE-4053 is incorporated in the main generator terminal box, or MGTB, and is activated whenever the unit is shut down. This will prevent moisture from accumulating inside the MGTB due to outside temperature conditions. RTD TE-4091 monitors the temperature of the MGTB and activates alarms TAH-4091 and TAL-4091 when MGTB temperature is ≥ 135 °F or ≤ 0 °F respectively. Prior to initiating start-up of the ventilation system, the following conditions shall be satisfied: • All fire dampers in open position The start-up sequence is as follows: 1) The Standby AC fan (MOT 4017A/B) is started to verify the turbine enclosure underpressure (PDT 4007). After 30 seconds, the pressure is checked and the fan is then stopped. If the fan fails to start or make underpressure, the start sequence is aborted. 2) The Duty AC fan (MOT 4017A/B) is started to verify the turbine enclosure underpressure (PDT 4007). After 30 seconds, the pressure is checked and the fan then continues to run. If the fan fails to start or make underpressure, the start sequence is aborted. Once the start-up procedure is completed, the ‘GT Ventilation System OK’ signal to sent to the start sequence to allow it to continue. During normal operation, the operator may manually start and stop the Standby fan for test/ verification purposes.

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Duty/Standby Changeover The 2 x 100% AC fans are designed for duty/standby operation. The controls logic is configured to allow both automatic and manual changeover from duty to standby. Manual changeover is selected by the operator from the HMI. Manual Changeover Manual changeover involves a change in priority and is initiated by the operator from the HMI. It can only be performed if the standby fan is not in fault. The operation is performed as follows: • The second [Standby] fan is started • Both fans are run simultaneously for 5 seconds • The first [Duty] fan is stopped The second fan, which is now running, is designated as the Duty fan. Automatic Changeover Automatic changeover is initiated by the controls logic on either of the following causes: • Loss of GT enclosure underpressure, PDT 4007 < L The changeover operation is performed in the same way as manual changeover, however the fan that is running at the end is now the Standby fan. The operator may manually switch priority between the fans, thereby designating the running fan as Duty. Whenever a standby fan is running, a “Standby fan running” alarm shall be generated to inform the operator. Reset of this alarm shall only be allowed after the fan has been stopped or selected as duty. System Shutdown Prior to stopping the ventilation system, the following permissive must be satisfied: • Post ventilation timer timed out. The timer is started when GG speed < 300 rpm and is set to 1 hours if flame has been established, otherwise it is set to 30 minutes. During this period, the TCP logic will prevent the ventilation fans from being stopped. • Fuel gas shutoff valves are closed. • GT start sequence not in progress. • No gas detected inside turbine or fuel gas compartment. When the ventilation system is stopped, either manually or automatically due to failure, the fuel gas system shall be depressurized.

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Special Operations Both Fans Run In the event of the following conditions: • High GT Enclosure Temperature (TE 4002A or TE 4002B) • Gas Detected (from F&G Panel) Both the Duty and the Standby fans are started, and kept running for the duration of the fault. There is no ‘Standby Fan Running ‘ alarm announced. Once the fault is cleared and reset, the operator may reset boosted ventilation, i.e. stop the standby fan. Both Fans Shut Down In the event of the following conditions: • Fire Detected (from F&G Panel) • CO2 Released (from F&G Panel) Both the Duty and the Standby fans are stopped immediately, and cannot be restarted until fault is cleared and reset. OPERATOR SCREENS The GTG Overview screen allows basic monitoring and control of the overall system. Control functions are accessed by faceplate pop-ups. Each control faceplate allows operator interaction and gives associated feedback. The screens displayed by the system software show criticaloperating parameters and system set points. Each screen and the information that it contains may be accessed by pressing its corresponding function.

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ENCLOSURE VENTILATION SCREEN DISPLAY

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Typical Enclosure Ventilation Screen Display The Enclosure Ventilation Screen display allows the operator to monitor the turbine enclosure ventilation auxiliary system. When an alarm is unacknowledged, the instrument tags will change color to flashing red. When an alarm is acknowledged but not rest, the instrument tag will change to a solid red. Automatic navigation to the alarm summary graphic is provided from any flashing red or solid red instrument tag.

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FIRE SUPPRESSION AND GAS DETECTION SYSTEM

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Fire Suppression and Gas Detection System 012 The fire suppression and gas detection system for the GTG set monitors the turbine-engine compartment for the presence of fire and accumulations of combustible gas. Carbon dioxide (CO2) is used as the fire-extinguishing agent for the main skid. The fire suppression and gas detection system consists of a programmable microprocessor-controlled panel that receives inputs from various sensors, such as optical flame detectors, thermal spot detectors, combustible gas detectors, hand switches, etc. The panel is located in the termination cubicle of the TCP. Refer to Fire Suppression and Gas Detection System, Block Diagram (below), for an overview of the system. Additional details on the fire suppression and gas detection system can be found in engineering drawings provided in Chapter 7 of this manual.

Fire Suppression and Gas Detection System

FUNCTIONAL DESCRIPTION CO2 in high concentrations may be harmful. Evacuate all personnel when CO2 is released. Purge compartments prior to reentry. Failure to observe this warning could result in serious injury or death. Read the Wilson Fire and Gas Protection Manual prior to operating or maintaining the system. Before operating or maintaining the fire protection system, read vendor publications in Chapter 5 of this manual and applicable safety guidelines in National Fire Protection Association (NFPA) Publication 12, Standard on Carbon Dioxide Extinguishing Systems. Refer to F&ID 20063-01-683254, Fire Protection System in Chapter 7 of this manual set. In case of a fire, an emergency shutdown is initiated and fuel flow to the turbine engine is terminated. The compartment-ventilating fans de-energize, fire dampers close, and the solenoid-operated valves open to release the fire-extinguishing agent. When an alarm input is received, the control panel energizes a timer to start a time-delay sequence that allows the operator to evacuate the main skid area before the extinguishing agent is released. A red emergency push button station has been provided outside the doors to the engine compartment for manually initiating alarms and releasing the fire-extinguishing agent. The fire suppression and gas detection system is interlocked with the turbine vent fans and shuts down these fans to confine the fire within the compartment. Similarly, when the gas accumulation exceeds the pre-set 10% lower explosion level (LEL), a series of events takes place. The dampers remain open and the standby fan activates in order to increase compartment ventilation and expel the gas from the compartments to the atmosphere; fuel flow continues. When the sensors detect a 25% high explosion level (HEL) of gas accumulation, fuel

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flow is stopped, the dampers remain open, and the standby fan activates to expel the gas from the compartment if not already in service.

Fire Suppression and Gas Detection System, Block Diagram

The fire and gas protection panel processes the input(s) and executes corresponding outputs to open the solenoid-operated valves at the main bank of CO2 bottles to release the fire-extinguishing agent. To alert personnel, a horn and a red beacon light are energized both inside and outside the turbine compartment and at the fire control panel at the TCP. The control panel has a built-in audible alarm, liquid crystal display (LCD), and illuminating indicators for informing operators of the current state of operation. Fire Control Panel Annunciator Refer to Section 5 for a complete description of the annunciator panel displays. Evacuate all personnel from main skid compartment before activating a manual release station. Death by asphyxiation could occur. Fire-extinguishing Agent CO2 is used as the extinguishing agent for the main skid. The system’s CO2 is stored in two bottles, main and reserve, outside the engine compartment. The CO2 bottles have been provided with solenoid-operated discharge heads. A check valve on each bank ensures the activation of one bank at a time. CO2 is discharged upon the activation of dry-line discharge pressure switch PSHH-3048 typically set to 150 psig increasing. If pressure in the line reaches 150 psig, a shutdown will be initiated. CO2 activation produces a signal at the fire protection panel that is relayed to the sequencer. The sequencer then initiates an orderly LM2000 50Hz shutdown sequence. Observe the guidelines and requirements in NFPA Publication 12, covering the use of block valves in fire-extinguishing systems. Failure to do so could result in serious injury or death.

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Safety Features The fire detection panel has a reset button that enables it to be returned to its standby configuration after being tripped. Other safety features are as follows: •

•

A manually operated block valve, located at the output of the collection manifold, has been installed to prevent the entry of the fire-extinguishing agent into the main skid enclosures. This valve can be locked in either the open or the closed position. Valve position is monitored by the control panel. This valve must be opened before the system can achieve standby status. A key-operated switch has been provided to silence the horn after an alarm, following the release of the extinguishing agent. Only after the cause for alarm has been cleared is it safe to reenter the enclosure.

FIRE PROTECTION SYSTEM – F&ID

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LOCATION OF C02 SYSTEM – RT. SIDE TURBINE ENCLOSURE

Controls and Indicators This section describes the operating controls and indicators of the Fire Protection System for the GTG set. The figures are intended to assist operating and maintenance personnel to become familiar with controls and indicators and their functions. Each table in this section lists the associated controls and indicators by item number (or letter), name, and function. The tables are supported by a figure that illustrates each numbered (or lettered) item listed in the related table. The figures and accompanying tables are typical. The following is a list of tables and their accompanying illustrations (Table 3.1, Controls and Indicators) that are associated with this system.

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3

4

5

6

BASIC OPERATORS COURSE

7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 2

FAULT 1 FAULT 2

FAULT 1 FAULT 2

FAULT 3

FAULT 3

FAULT 3

S I L E N C E

R E S E

I N H I B I T

R E S E

T

GAS ALARMS

17

AUX =

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

SYSTEM ALARMS

T

HEAT DETS

I N H I B I T

FIRE

STEP

4

R

HIHI ALARM HI ALARM

FAULT 2

FAULT

SET RESET

FAULT 3 FAULT 3

I N H I B I T

8

R

R

E

E

S

S

E

E

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

E S E T

LO ALARM FAIL

FIRE PROTECTION PANEL Item

Control/Indicator

Function

1

Fire Suppression and Gas Detection System Panel

Comprised of plug-in modules that link to flame, temperature, and gas detection sensors inside the turbine and generator enclosures. Interfaces with the turbine control system to provide the necessary engine shutdown, ventilation fan on/off signals, and other operator messages. For detailed information on this system, refer to the Wilson Fire Equipment & Service Company Manual in Chapter 5 of this manual.

2–8

Spare Modules

Not used on this project.

9–11

Gas Modules (NT420)

Accept analog signals from gas detectors in the generator (Module 12) and turbine (Modules 13 and 14) enclosures. Calibrated values are displayed as a percentage of the lower explosion limit (LEL) of the gas-air mixture (represented by % LFL on modules). Display also indicates over- or underrange sensor inputs and programming information for setting alarm parameters. Each gas module contains two pushbuttons to initiate programming: Step–

When step and reset pushbuttons are depressed simultaneously, displays menu items that enable operator to calibrate and set gas system alarms and shutdown limits.

Set Reset – Resets module conditions after all alarms have been cleared. Each gas module also contains four alarm LEDs that illuminate red when activated: HiHi Alarm – Illuminates when gas level has reached 100% LEL. Hi Alarm –

Illuminates when gas level has reached 25% LEL.

Lo Alarm – Illuminates when gas level has reached 10% LEL. Fail –

3G-6

Illuminates when an internal diagnostic fault has occurred.

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7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 2

FAULT 1 FAULT 2

FAULT 1 FAULT 2

FAULT 3

FAULT 3

FAULT 3

S I L E N C E

R E S E

I N H I B I T

R E S E

T

GAS ALARMS

17

AUX =

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

SYSTEM ALARMS

I N H I B I T

STEP

4

R

HIHI ALARM HI ALARM

FAULT 2

FAULT

SET RESET

FAULT 3 FAULT 3

I N H I B I T

8

R

R

E

E

S

S

E

E

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

E

LO ALARM FAIL

S E T

T

HEAT DETS

FIRE

FIRE PROTECTION PANEL Item 12

Control/Indicator

Alarm Module

Function Receives fire and gas system alarms that have been activated by the Input or Manual Pull Modules. The alarm module contains six LEDs and a Silence/Reset switch: Bell – Not used in this configuration. Horn – Illuminates and flashes when horn is activated. Strobe – Illuminates after receiving alarm signal. Fault 1 thru Fault 3 – Illuminate yellow when a malfunction occurs in the module system.

13

Input Module

Accepts signals from temperature and optical flame detector sensors in the generator enclosure. Once activated, initiates Release and Alarm Modules. This module has three fire and three fault LEDs and a reset switch: Fire 1 thru Fire 3 –

Illuminate red when receive alarm signal; trip auxiliary relay.

Fault 1 thru Fault 3 – Illuminate yellow when a malfunction occurs in the module system. Two-position, momentary Reset switch: Reset – Resets module conditions after all alarms have been cleared. Center – Off.

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7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 2

FAULT 1 FAULT 2

FAULT 1 FAULT 2

FAULT 3

FAULT 3

FAULT 3

R

S I L E N C E

E S E

I N H I B I T

R E S E

T

GAS ALARMS

17

AUX =

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

SYSTEM ALARMS

I N H I B I T

STEP

4

R

HIHI ALARM HI ALARM

FAULT 2

FAULT

SET RESET

FAULT 3 FAULT 3

I N H I B I T

8

R

R

E

E

S

S

E

E

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

E S E T

T

HEAT DETS

FIRE

LO ALARM FAIL

FIRE PROTECTION PANEL Item

Control/Indicator

14

Input Module

Function Accepts signals from three optical flame detectors located in the front of the turbine enclosure. This module contains three fire and three fault LEDs and a Reset switch: Fire 1 thru Fire 3 –

Illuminate red when receive alarm signals; trips auxiliary relay.

Fault 1 thru Fault 3 – Illuminate yellow when a malfunction occurs in the module system. Two-position, momentary Reset switch: Reset – Resets module conditions after all alarms have been cleared. 15

Release Module

Center – Off. Releases primary and reserve banks of CO2 gas cylinders after pre-set time delays (30- and 10-sec). Responds to Input or Manual Pull Module status through system bus to determine if two releases are necessary. The module has six LEDs and an Inhibit/Reset switch: Main (top of panel) –

Illuminates when primary bank of CO2 gas cylinders has been released.

Reserve (top of panel) – Illuminates when reserve bank of CO2 gas cylinders has been released. Main (middle of panel) – Illuminates if continuity problems are detected in the solenoid or pressure switch lines. Reserve – Illuminates if continuity problems are detected in the solenoid or pressure switch lines.

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7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 2

FAULT 1 FAULT 2

FAULT 1 FAULT 2

FAULT 3

FAULT 3

FAULT 3

S I L E N C E

R E S E

I N H I B I T

R E S E

T

GAS ALARMS

17

AUX =

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

SYSTEM ALARMS

I N H I B I T

STEP

4

R

HIHI ALARM HI ALARM

FAULT 2

FAULT

SET RESET

FAULT 3 FAULT 3

I N H I B I T

8

R

R

E

E

S

S

E

E

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

E

LO ALARM FAIL

S E T

T

HEAT DETS

FIRE

FIRE PROTECTION PANEL Item

Control/Indicator

15 (Cont)

Release Module

Function PSW (power) – Flashes when Inhibit mode is active. Abort –

Not used in this configuration.

Three-position, momentary Inhibit/Reset switch:

16

Manual Pull Module

Inhibit –

Controls release signals to allow module tests without risk of CO2 gas activation. Operates only when panel is in normal operating mode.

Center –

Off.

Reset –

Resets module conditions after all alarms have been cleared.

Responds to activation of manual pull stations and activates Alarm and Release Modules. The module has two LEDs and an Inhibit/Reset switch: Fire –

Illuminates red when any manual pull switch in the turbine and generator enclosures has been activated.

Fault –

Illuminates yellow when internal diagnostic fault has occurred in the system.

Three-position, momentary Inhibit/Reset switch:

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Inhibit –

Controls release signals to allow module tests without risk of primary and reserve CO2 gas cylinder bank activation (Inhibit LED flashes). Testing can only be done in the normal operating mode.

Center –

Off.

Reset –

Resets module conditions after all alarms have been cleared.

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7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 2

FAULT 1 FAULT 2

FAULT 1 FAULT 2

FAULT 3

FAULT 3

FAULT 3

S I L E N C E

R E S E

I N H I B I T

R E S E

T

GAS ALARMS

17

AUX =

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

SYSTEM ALARMS

I N H I B I T

STEP

4

R

HIHI ALARM HI ALARM

FAULT 2

FAULT

SET RESET

FAULT 3 FAULT 3

I N H I B I T

8

R

R

E

E

S

S

E

E

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

E S E T

T

HEAT DETS

FIRE

LO ALARM FAIL

FIRE PROTECTION PANEL Item 17

Control/Indicator

Fault Module

Function Announces any malfunction in the fire and gas system. Faults displayed locally on the respective modules are transferred to this module. This module also identifies fault categories and provides the mechanism for resetting the audible fault horn. There are three LEDs and a Reset switch in this module: System – Illuminates when a fault is detected in the system.

3G-10

Power –

Illuminates when battery supply voltage is low.

Aux –

Not used in this configuration.

Reset –

Two-position, momentary Reset switch. Resets module conditions after all alarms have been cleared.

Center –

Off.

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CO2 BOTTLES

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STROBE LIGHT

HEAT SENSOR

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ENCLOSURE FIRE DAMPER AND ACTUATOR ASSEMBLY (CLOSED)

FIRE PROTECTION SYSTEM SCREEN DISPLAY

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TURBINE AUXILIARY SYSTEMS

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Screens The CRT/CPU segment of the control system allows the operator to gain insight into the operational trends of the GTG set and its ancillary equipment systems. The screens displayed by the system software show critical-operating parameters and system set points. Each screen and the information that it contains may be accessed by pressing its corresponding function, or “F,” key. The following Cimplicity system screens are typical for an LM2500 unit.

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TURBINE AUX. SYSTEMS - #1

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TURBINE AUX. SYSTEMS - #1

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TURBINE-GENERATOR VIBRATION MONITORING SYSTEM

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Turbine-Generator Vibration Monitoring Systems012 The vibration monitoring system for the turbine-generator set consists of sensing elements in the turbine casing, and at each end of the generator rotor to detect vibration during operation. These sensors transmit vibration signals to the TCP, and activate alarms and initiate turbine shutdowns as established by preprogrammed vibration set-points.

VIBRATION MONITORING SYSTEM FUNCTION DIAGRAM

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Vibration Monitoring System Theory Of Operation The vibration monitoring system produces vibration magnitude data with adjustable alarm and shutdown set points for engine and generator safety. The figure above illustrates the LM2000 engine and generator vibration sensors and electronic components. Aft and forward engine accelerometers are installed on the turbine rear frame (TRF) and compressor rear frame (CRF). These sensors produce complex electrical waveforms, resulting from the frequency and amplitude of engine vibration. Interface modules, installed in relative close proximity to the sensors, integrate 10-mV/g acceleration signals to obtain 100mV/sec velocity signals for processing in modules that plug into the control rack. The rack is mounted in the turbine control panel. Tracking filters installed in rack slots 3, 4, 5, and 6 receive low-pressure turbine (LPT) and highpressure turbine (HPT) velocity and speed signals. The tracking filters present the velocity components associated with the two turbine speeds on front panel displays. In summary, four velocity signals are produced: one from each accelerometer, filtered at N1 and at N2 speeds. They are noted as follows: (1) Engine (FWD) vibration velocity at (HPC, N1) speed (2) Engine (AFT) vibration velocity at (HPC, N1) speed (3) Engine (FWD) vibration velocity at power turbine (PT, N2) speed (4) Engine (AFT) vibration velocity at power turbine (PT, N2) speed

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Generator Bearing Proximitors Proximitors are installed on the drive and non-drive ends of the generator drive shaft bearing housings, to measure displacement between the bearing housings and the generator shaft. Two proximitors are mounted on each bearing housing perpendicular to the shaft axis and displaced 90° radially. The proximitors are referred to as x and y drive and non-drive end proximitors. Displacement measurements from the four proximitors are displayed on modules installed in rack slots 7 and 8 as follows: • Drive end x • Drive end y • Non-drive end x • Non-drive end y

TURBINE AUXILIARY SYSTEMS (1 of 2)

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ACCELEROMETER Accelerometer Theory of Operation - In the study of physical systems, it is often desirable to observe the motion of a system and, in particular, its acceleration. Accelerometer can be described as a combination of the two transducers – the primary transducer, typically a single degree of freedom vibrating mass, or seismic mass, which converts the acceleration into displacement, and a secondary transducer which converts the displacement of the seismic mass into an electric signal. As the accelerometer reacts to motion, it places the piezoelectric crystal into compression or tension, which causes a surface charge to develop on the crystal. The charge is proportional to the displacement of the crystal. As the large body moves, the mass of the accelerometer will move with an inertial response. The piezoelectric crystal acts as the spring to provide a resisting force and damping. As the seismic mass moves, it places a piezoelectric crystal into compression or tension, which causes a surface charge to develop on the crystal, which is proportional to the motion

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ACCELEROMETER RESPONDING

VIBRATION MONITORING SYSTEM

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Vibration Monitoring System 1. Low Voltage DC Power Supply / Future Expansion: Operates under fully loaded conditions with a single power supply. When two power supplies are installed in a rack, the supply in the lower slot acts as the primary supply and the supply in the upper slot acts as the backup supply. If the primary supply fails, the backup supply will provide power to the rack without interrupting rack operation. 2. Rack Interface Module: Primary interface that supports Bently-Nevada proprietary protocol used to configure the rack and retrieve machinery information. The rack interface module provides the connections needed to support current Bently-Nevada Communications Processors and Dynamic Data Interface External. 3. Communications Gateway Module: Provides serial communications between the 3500 Monitor System and a plant information system such as a distributed control system (DCS) or a programmable logic controller (PLC). Collects data from the modules in the rack over a high-speed internal network and sends this data to the information system upon request. The module is able to establish communications with up to six hosts over Ethernet. 4. Aero GT Vibration Monitor: 4-channel monitor that accepts input from four Velocity Transducers and uses these inputs to drive alarms. The monitor can be programmed using the 3500 Rack Configuration Software to execute any filter options. 5. Keyphasor Module: 2-channel module used to provide Keyphasor signals to the monitor modules. The module receives input signals from proximity probes or magnetic pickups and converts the signals to digital Keyphasor signals that indicate when the Keyphasor mark on the shaft is under the Keyphasor Probe. A Keyphasor signal is a digital timing signal that is used by monitor modules and external diagnostic equipment to measure vector parameters like 1x amplitude and phase. 6. Proximitor Monitor: 4-channel module that accepts input from proximity transducers, linear variable differential transformers (DC & AC LVDTs), and rotary potentiometers and uses this input to drive alarms. It is programmed by using the 3500 Rack Configuration Software to perform any of the following functions: Thrust Position, Differential Expansion, Ramp Differential Expansion, Complementary Input Differential Expansion, Case Expansion, and Valve Position. 7. Future Expansion 8. 4 Channel Relay Module: Contains four relay outputs. Each relay output is fully programmable using AND and OR voting. The Alarm Drive Logic for each relay channel can use alarming inputs (alerts and dangers) from any monitor channel in the rack. The Alarm Drive Logic is programmed using the Rack Configuration Software. 9. Dynamic Pressure Monitor: Single slot, 4- channel monitor that accepts input from various high temperature pressure transducers and uses this input to drive alarms. The monitor has

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one proportional value per channel, bandpass dynamic pressure. The bandpass corner frequencies are configured using the 3500 Rack Configuration Software along with an additional notch filter. 10 - 16. Future Expansion Note: In gear-driven generator units, gearbox vibration is measured with additional dualvibration modules installed in a second chassis

VIBRATION AND SPEED SENSING INSTRUMENTATION Vibration and Speed Sensing Instrumentation The auxiliary systems instrumentation diagram illustrates the location and operating parameters of the vibration and speed monitoring sensors associated with the gas turbine package. Maintenance Inspection/Check Schedule Inspection Check Required

Inspection Frequency

Vibration Signatures

Weekly

I

Instrumentation

12 Months or 8000 Hours

I

3I-8

Maintenance Level

Remarks Check Bently Nevada gauges for measuring vibration. Check calibration of the Bently Nevada gauges, pressure and temperature switches.

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ACCELEROMETER - AFT

ACCELEROMETER – FWD

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PROXIMITER PROBES – DRIVE END

PROXIMETER PROBE – NON-DRIVE END

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OPERATOR SCREENS The GTG overview screen allows basic monitoring and control of the overall system. Control functions are accessed by faceplate pop-ups. Each control faceplate allows operator interaction and gives associated feedback. The screens displayed by the system software show criticaloperating parameters and system set points. Each screen and the information that it contains may be accessed by pressing its corresponding function designator.

TURBINE/GENERATOR VIBRATION SCREEN DISPLAY The Turbine/Generator Vibration Display Screen, can be accessed from the HMI. This screen allows the operator to simultaneously monitor all of the turbine and generator vibration inputs. These inputs are received from the Bently Nevada Vibration Monitoring System.

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This Page Intentionally Left Blank

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D.C. POWER SYSTEM BATTERY AND BATTERY CHARGER

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BATTERY AND BATTERY CHARGER SYSTEMS Introduction Separate battery and battery charger systems furnish DC power for GTG set operation. A 24VDC system provides backup power for the turbine control system and the fire suppression and gas detection system. A 125-VDC system (BOP) provides backup power for the generator protective relay system and the breaker control scheme. Batteries for the 24-VDC system are stored on battery racks in the battery room that is isolated from the TCP. The battery room is adequately ventilated and provides access to the back of the switchgear area. Information on the battery systems can be found in vendor documentation provided in Chapter 5 of this manual. Additional details can be found in engineering drawings provided in Chapter 4 of this manual. This section provides an overview of the typical battery systems associated with the GTG set. Turbine-Generator Battery Systems Operation Control System 24-VDC Battery System This system provides 24-VDC power for the turbine and generator monitoring and control circuits. In the event of primary power failure, the batteries are capable of providing 24-VDC power at an approximate discharge rate of 50.8 A for 8 hours. Fire Suppression and Gas Detection 24-VDC Battery System This system provides 24-VDC emergency backup power for the fire suppression and gas detection system. In the event of primary power failure, the batteries are capable of providing 24VDC power at an approximate discharge rate of 6.35 A for 8 hours. Turbine-Generator Battery Systems Features The batteries are sealed valve regulated lead acid type batteries. The 24-VDC batteries operate best at temperatures ranging between −4 °F and 104 °F (-20 °C and 40 °C). Refer to TurbineGenerator Battery System, Block Diagram, below for an overview of the battery systems.

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TURBINE-GENERATOR BATTERY SYSTEM, BLOCK DIAGRAM The 24-VDC battery charger for control power operates best with an ambient temperature between -4 °F and 122 °F. The 24-VDC battery charger for fire suppression and gas detection operates best with an ambient temperature between −4 °F and 122 °F. Control System 24-VDC Battery System The 24-VDC battery bank consists of two battery racks containing 6 cell blocks of 2SLA400 batteries with nominal cell capacities of 400 ampere-hours (Ah). Two 24-VDC battery chargers keep the battery bank fully charged: one battery charger is normally in active use while the other is in a standby mode. In the event of failure of the primary battery charger, the system switches to the standby charger. Fire Suppression and Gas Detection 24-VDC Battery System The 24-VDC battery bank consists of two battery racks containing 6 cell blocks of 12SLA50 batteries with nominal cell capacities of 50 Ah. A single 24-VDC battery charger keeps the battery bank fully charged. Battery Alarms Battery chargers have alarms that alert operators when there is a failure in the system. The alarm system is linked to the TCP. The alarms are activated for the following reasons: • • • •

DC failure – no response or low response from battery (loss of output or battery going bad) AC failure – input to charger is bad low volts – system volts not being maintained (bad cell, break in connection) ground fault – short on a unit.

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Start-Up 1. Start with both input and output breakers OFF. 2. First, check that the connected battery voltage is correct (e.g. 120 volts for a 120-volt charger). It is OK if the battery voltage is different from the nominal value by a few percent. If the battery voltage is more than 10% different from the rated voltage of the charger, recheck your connections before turning on either breaker. 3. Then close the AC input breaker. Check that the voltage comes up to approximately 15% above nominal. (Some voltages overshoot on initial start-up is normal). 4. Next, close the DC output breaker. The charger will immediately begin to supply current, if required by the battery or load. 5. In chargers with alarms code “6”, the front panel AC FAIL and CHARGER FAIL lights will extinguish and it should be replaced by the green AC ON light. 6. The charger will automatically supply power to the load and maintain the battery without further attention. If the charger does not start as described, or appears to have failed, check the following: • • • •

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Verify that the AC mains power is available Verify that no external circuit breakers are tripped Verify that contractor-installed AC, DC and alarm connections are correct Disconnect AC and DC power sources. Open the charger. Verify that no components (e.g. main DC output fuse, if fitted) or harness connections are blown, loose or damaged.

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BATTERY CHARGER

BATTERY BANK

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Float/Boost Modes Two modes of voltage control are provided in all DCT chargers as follows: Float The float mode is the battery “maintenance” voltage. It is normally fully charged voltage of the battery. This is normally charging position for all batteries and the recommended charging position at all times for Valve Regulated Lead Acid (VRLA) batteries. Boost This voltage is slightly higher then the float setting. Boost slightly overcharges the battery in order to ensure that the cells of the battery are fully charged to the same voltage. Continued operation in boos is not recommended because of high charging voltage will cause battery electrolyte to boil away quickly. This is a particular problem with VRLA batteries where there is no way to replenish lost electrolyte. Float/Boost Control DCT chargers are equipped with one of the four following float/boost voltage control systems, depending on the configuration ordered: Float/Boost Front Panel Rotary Switch The charger will operate indefinitely in the mode selected. The AUTO position may be shown on the front panel. If the AUTO position is locked out, the AUTOBOOST feature is not supplied. AUTO/FLOAT/BOOST Front Panel Rotary Switch When the selector switch is in the FLOAT or BOOST mode, the charger will operate indefinitely in the mode selected. The AUTO mode selects automatic equalization of the battery. The charger determines when the battery is in need of fast charging, and it operates in the fast charge boost mode only until the battery is fully charged. The charger determines state of charge by measuring the amount of current drawn from the output terminals. When the selector switch is in AUTO position the charger will start in the boost mode and stay there until current demanded drops below about 50% of the chargers rated current. When current demand increases to about 70% of the chargers rated output, the charger will resume operation in the BOOST mode. The AUTO settings eliminate the need to periodically equalize the cells of a battery as the charger does this automatically.

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Manually Initiated Boost Timer, Plus AUTO/FLOAT/BOOST Rotary Switch Selection of the auto position allows the charger to operate in the AUTOBOOST mode. Selection of the float mode forces the charger to remain in the float mode unless the boost timer is activated by turning past zero. If the boost timer is activated, the charger will revert to FLOAT mode after the time selected on the timer expires. Selection of the BOOST mode forces the charger into boost charge, where it will remain until BOOST is deselected manually. Alarm Indications Note; Chargers are equipped with a dead front panel. Alarm LEDs are behind the dead-front panel and will be visible when they illuminate due to an alarm condition, or when the test button is pressed. Chargers with no alarms have no LEDs or test buttons. The alarm/display circuit monitors battery voltage and charger performance. The alarm circuitry consists of eight separate circuits: AC Fail, Charge Fail, High DC, Low DC, Low Voltage, Load disconnect, Ground Fault, Option, and summary. Note that some of the alarm relays utilize time delays of approximately 25 seconds. This is deliberated, and it is intended to eliminate the incidence of spurious alarm indications.

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24-VDC Battery System The 24-VDC-system supplies power for the turbine-generator components requiring 24-VDC. Some of these components are the emergency lube oil pump, the TCP, the GCP, and also the fire protection system. A. 24-VDC Battery Charger (Control Power). When input power of 208 VAC is present from the lighting-and-distribution panel of the MCC, this 150-A charger supplies 24 VDC to charge the 24-V battery bank (control Power). B. 24V Battery (Control Power) This battery system provides the necessary 24-VDC power required for continued turbine-generator monitoring and control. The capacity of this 24V battery system is 3 hours at required load (101 A). Containing M-412-Style batteries, the two-tiered battery module is located on level ground in an easily accessible area away from heat sources. C. 24-VDC battery Charger (Fire and Gas Protection) When input power of 120 VAC is present from the lighting-and –distribution panel of the MCC, this 25A charger supplies 24 VDC to charge the 24V battery bank 9Fire and Gas Protection). D. 24V Battery (Fire and Gas protection) This battery system provides the necessary 24VDC power required for continued fire and gas detection and fire suppression activation.

FPP BATTERY BANK AND CHARGER

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SECTION 4

ELECTRIC SYSTEMS

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ELECTRICITY AND THE PRINCIPLES OF POWER GENERATION

Field Around A Current-Carrying Conductor FIELD AROUND A CURRENT-CARRYING CONDUCTOR Current flow through a conductor produces a magnetic field, as illustrated above. The direction of magnetic flux lines is predictable by Ampere’s right-hand rule. A compass near the conductor can be used to verify the presence and direction of the magnetic field. Electric generators utilize magnetic fields to control and generate electric power.

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ELECTROMAGNET AND RIGHT-HAND RULE One of the effects of a conductor carrying a current is to produce a magnetic field. Any conductor carrying a current will, in fact, act as a magnet. If we cause current to flow in a piece of wire, a magnetic field is induced. The converse is also true—if you move a piece of wire so that it cuts through a magnetic field, an electric current will flow in the wire. Forming the conductor in the previous illustration into a coil, as illustrated above can increase magnetic field strength. To make the magnetic field of the loop stronger, form the wire into a coil containing many loops. The individual fields of all the loops reinforce one another and form a single strong magnetic field, extending both inside and outside the loop. The field strength of the coil will then be proportional to current flow and the number of turns in the coil. The magnetism also increases with increasing current. Note that once current ceases to flow in the conductor, magnetism is lost. Flux lines per unit area, or flux density, is greater at the ends of the coil where flux lines leave the North (N) pole and enter the South (S) pole.

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The direction of the magnetic field about a current-carrying conductor is determined by the direction of current flow. If a current-carrying conductor is grasped in the right hand with the thumb pointing in the direction of current flow, the fingers wrapped around the conductor will point in the direction of the magnetic lines of force. This is known as the “Right-Hand Rule.”

Field Developed By A Coil FIELD DEVELOPED BY A COIL Magnetic field strength can be increased by forming the conductor in the previous illustration into a coil, as illustrated above. Each coil turn reinforces the flux generated in the preceding turn, according to Ampere’s right-hand rule. The field strength of the coil will then be proportional to current flow and the number of turns in the coil. Flux lines per unit area, or flux density, is greater at the ends of the coil where flux lines leave the North (N) pole and enter the South (S) pole. Permeability is the property of magnets to retain their magnetism over time. Magnets of high and low permeability are used to control generator output voltage and power

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CURRENT FLOW IN A CONDUCTOR Moving a conductor relative to a magnetic field or moving a magnetic field relative to a conductor, as illustrated above can induce current flow in a conductor. The rate of relative motion is also directly proportional to the induced current. The energy required to produce relative motion is analogous to the energy used in rotating a mechanical pump to produce liquid flow, as illustrated above. The circulating liquid flow is analogous to current flow in the electric circuit. The switch in the electrical circuit is analogous to the valve in the mechanical liquid circuit.

Current Flow In A Conductor

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Simple Single-Phase Generator SIMPLE SINGLE-PHASE GENERATOR Illustrated above is a permanent magnet with high permeability rotating near a single-loop conductor. As the N and S poles rotate (to positions) near the loop, the flux density is increased and reversed when the opposite pole approaches. The reversal in flux direction produces a once-per-cycle reversal in current flow, such that an oscillating waveform is produced. The waveform produced is sinusoidal, having a peak-positive value as each N pole passes and a peak-negative value as each S pole passes.

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Simple Three-Phase Generator

SIMPLE THREE-PHASE GENERATOR By positioning three loops, or coils, around a rotating magnet, as illustrated in (A) above, three voltage waveforms are generated with each revolution. By arranging the coils 120 mechanical degrees apart (industry standard), three-phase power is produced, as illustrated in (B) above.

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ELEMENTARY GENERATOR In order to understand the ac waveform, it does well to examine how it is produced. To do this, we need to understand the mechanism of ac power generation. An elementary generator consists of a loop of wire placed so that it can be rotated in a uniform magnetic field to produce electricity in the loop. If sliding contacts are used to connect the loop to an external circuit, a current will flow around the external circuit and the loop. The pole pieces are the north and south poles of the magnet that supply the magnetic field. The loop of wire that rotates through the field is called the armature. The ends of the armature loop are connected to rings called slip rings, which rotate with the armature. Current collectors, called brushes, “brush off” the slip rings to pick up the electricity generated in the armature and carry it to the external circuit. In the description of the generator outlined, visualize the loop rotating through the magnetic field. As the sides of the loop cut through the magnetic field, they generate an emf, which causes a current to flow through the loop, slip rings, brushes, ammeter, and load resistor—all connected in series. The emf, which is generated in the loop and, therefore, the current that flows, depends on the position of the loop in relation to the magnetic field.

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Rpm = 120 ×

Frequency_(Hz)_ Number of Poles

For 50 Hz,

rpm

=

120 X 50

Poles And 2-Pole Machine

rpm

=

6000 2

= 3000

4-Pole Machine

rpm

=

6000 4

= 1500

6-Pole Machine

rpm

=

6000 6

= 1000

8-Pole Machine

rpm

=

6000 8

= 750

Relationship of Shaft Speed vs Number of Poles RELATIONSHIP OF SHAFT SPEED VERSUS NUMBER OF POLES Power frequency is a function of the number of poles on the rotor and the rotor speed, as shown in the table above. The LM2000 power turbine operates at 3000 rpm, allowing the generator to produce 50-Hz power with a two-pole rotor.

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GENERATOR BRUSHLESS EXCITATION

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GENERATOR STATOR COIL

A

ROTATING DIODES (SIMPLIFIED)

MAIN ROTOR COIL (SIMPLIFIED)

EXCITER ROTOR COIL

B

PMG ROTOR

C EXCITER STATOR COIL

PMG STATOR COIL

GENERATOR STATOR COILS

AUTO MAN.

VOLTAGE REGULATOR

GS-220-01

TWO BIG IDEAS When magnetic lines of force cut a coil, a VOLTAGE is built in the coil. When a current is passed through a coil, a MAGNETIC FIELD is built around the coil.

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Electric Generator Symbols ELECTRIC GENERATOR SYMBOLS The symbol for an electric generator is that of a “wye”-connected transformer, illustrated in (A) above, without a primary winding. The neutral tie relates to stator connections that can be made at either end of the stator windings. The physical stator winding ends are brought out at the left-hand and right-hand sides of the generator frame. Either end of the stator windings may be declared the “line side” or the “neutral side,” whichever is most convenient for external connections. The neutral grounding transformer, illustrated in (B) above, is a safety measurement device whose output is zero, unless unbalanced stator currents occur.

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Brushless Excitation System The generating system illustrated in (A) above uses a rotating electric magnet rather than a permanent magnet. Current flow through the rotating windings is supplied by a battery and brushes, which contact rotating slip rings. A variable resistor in the external battery current loop regulates current flow through the rotating coil. This Excitation current determines the strength of the rotating magnetic field and, therefore, the voltage and/or power output from the stator windings. The Excitation scheme, illustrated in (B) above, provides magnetic linking of the stationary and rotating parts of the machine without using brushes. Brushless excitation has become an industry-preferred standard, eliminating the wear and failure problems associated with brush-type exciters. In the brushless excitation scheme, the rotating flux lines of the permanent magnet induce an AC voltage in the surrounding stationary windings. This AC voltage is rectified, and the resulting DC is regulated and applied to a set of stationary windings called the Exciter Field. The exciter field windings surround an exciter rotor, which has induced in it an AC voltage. The AC voltage output of the exciter rotor is rectified by diodes, which also rotate. The DC output from the rotating diodes is applied to the main rotor to control the electrical output of the main stator windings. The regulation of exciter field current, therefore, is a mechanism for controlling the 3phase generator output.

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GENERATOR DETAILS OF CONSTRUCTION Design The LM2000 50Hz GTG set features a Meidensha generator, which is a two-bearing machine equipped with a brushless rotating exciter and a permanent magnet generator (PMG) on the nondrive end. For details on the generator, refer to the Meidensha Operation and Maintenance Manual found in Chapter 5 of the O&M Manual. Rating The AC generator operates at a synchronous speed of 3000 rpm and continuously supplies an output voltage of 11.5 kV at a frequency of 50 Hz at .85 power factor (PF) for this project. The unit is bolted to the gas turbine-generator package main skid, such that the rotor is axially aligned with the power turbine drive shaft. A flexible coupling connects the generator rotor to the engine drive shaft.

Generator Location

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1. 2. 3. 4.

Stator Winding Stator Core Rotor Rotor Endcap

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5. Shaft Mounted Fan 6. Bearing Oil Seal 7. Exciter Cooling Air Duct 8. Endframe Bearing

9. Exciter Stator 10. Rotating Diodes 11. Exciter Rotor 12. PMG

TYPICAL ELECTRIC GENERATOR LAYOUT

Cutaway of Meidensha Generator

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Stator The stator core (2) is made of high-quality cold-rolled silicon steel laminations with minimal core loss. These laminations are punched to produce segments and their surface is insulated by baked varnish. The treatment is effective in reducing eddy current loss in the core. In order to cool the core effectively, ventilation ducts are provided at proper intervals in an axial direction for smooth radial ventilation. Both ends of the core are fitted with non-ferrous fingers, which are clamped with sufficient pressure to tighten the core using clamping plates. The core back is thick enough to permit passage of necessary magnetic flux. Therefore core loss is minimal, the entire core strength is adequate, and vibration is effectively suppressed. The stator frame (1) is constructed of welded steel sheets, and is rigid enough to support the stator core. The stator frame is also designed to have sufficient rigidity against vibration of double frequency, which is distinctive to the 2-pole machine. It also withstands the violent impact that may occur upon sudden short circuit failure.

TYPICAL GENERATOR ROTOR MAIN ROTOR Since the rotor revolves at high speed, special attention is paid to the selection of material, design, and fabrication. The rotor core and the shaft are machined from a solid forged-steel alloy that has

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excellent magnetic and metallurgical properties. The shaft material is carefully checked by supersonic crack detection, and specimen is taken to confirm the mechanical strength and electromagnetic characteristics. The rotor coil is provided with slots for accommodating the field coils and with ventilation grooves on both sides of each slot. Wedges of non-magnetic alloy fix the field coils in the rotor slots. This will keep the field coils in their correct positions under the strong centrifugal forces encountered during operation. The field windings are composed of spiral coils made of silver-copper alloy. The formed coils are fitted in the slots of the rotor core and then baked. Thus the core slots are insulated in advance against grounds by the use of L-shaped layers made of glass cloth impregnated with epoxy resin. In order to avoid radial deformation towards the outside by strong centrifugal force during revolution of the rotor, both ends of the winding projecting from the core slots are held in place by non-magnetic retaining rings. The insulation cylinder is inserted between these rings and the windings. The coils are fixed with this cylinder for protection against deformation due to centrifugal force and temperature changes. The insulation cylinder is provided with ventilation ducts for the passage of ample cooling air for the winding ends. A single brush, spring-loaded against the rotor, carries stray ground currents from the rotor to the frame ground (Fig. 1, item 26). The brush is located near the drive end of the main rotor.

Generator Airflow

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Cooling Air Circuit The generator produces a considerable amount of heat during operation that is removed through generator ventilation. As illustrated in Generator Airflow, the generator rotor is equipped with fan blades to produce a cooling airflow through the interior of the generator. The cooling air is guided to ensure efficient air distribution throughout the rotor and stator end windings and the air gap. It is then passed through the ventilation air ducts provided radially on the stator core, which is divided into several blocks. A part of the cooling air is extracted for the cooling of the excitation equipment via the air ducts connected on the non-drive end of the generator. The heated air is then exhausted from the opening at the center top of the stator frame. For further information on generator ventilation, as well as turbine ventilation, refer to F&ID 020020-01-683239, Ventilation and Combustion System, located in Section 7 of the O&M Manual. Lubrication System Lubrication is the process by which a film of lubricant is placed between bearing facing surfaces for the purpose of controlling friction and wear. Such films are designed to minimize contact between the surfaces by adhering tenaciously to them and having sufficient viscosity to resist being squeezed out of potential contact zones (viscosity can be thought of as resistance to flow), so as to prevent wear. However, the viscosity must not be so great as to prevent easy shearing of the lubricant, since this allows the frictional force opposing the movement of one surface across the other to be low. In order to emphasize the importance of the lubrication of the bearings, it should be noted that the generator rotor is very heavy, and the surface speed of the shaft is very fast at 3000 rpm. Should this system fail for any reason, it is easy to see that the bearing and shaft would suffer major damage in a very short time. A shaft-driven positive displacement lube oil pump is supported on a bracket and driven through a flexible coupling from the non-drive end of the generator drive shaft. Pressure from the pump is adequate to supply bearings lube oil pressure at speeds above approximately 400 rpm (N2 >3000 rpm). Below 400 rpm, an AC motor driven lube oil pump provides lubrication. In event of an AC pump failure, run down tanks will gravity feed oil to the bearings to provide lubrication. Details are covered in the Generator Lube Oil System section

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Tapered-Land Thrust Bearing

Bearings The generator rotor shaft bearings are a pressure-lubricated, babbitt-sleeve type. The babbitt faces have been grooved for even oil distribution, and the drive-end bearing incorporates thrust pads to limit longitudinal movement of the rotor. Except for startups and shutdowns, the bearings receive lube oil from a pump driven by the exciter end of the rotor shaft. Lubricating oil for startups and shutdowns is provided by the 2.5-hp, 360-VAC generator auxiliary pump. This pump also serves as a backup should the shaft-driven pump fail. The shaft-driven pump is supplemented by two 16gallon (61 Liter) rundown tanks, which supply lubricating oil to the bearings in the event of an auxiliary pump failure during shutdowns. Bearing Construction The bearings are of the elliptical journal type. They are constructed of cast iron shells lined with white metals (Babbitt). The exciter end bearing is insulated for the prevention of shaft current. Since insulation is secured with the bearing, it is unnecessary to insulate the piping. The bearings have spherical outer surfaces to prevent unbalanced exertion of a load due to shaft deflection. The driven end bearing is provided with a shaft grounding brush. By utilization of a forced lubrication system, the oil is fed through the lubrication hole of the bearing bracket. The oil passes through the oil grooves provided along the lower-half outer edge of the bearing and is led further to the bearing inside grooves that are located at the horizontal split lines. Thrust bearings are installed between the drive-end journal and the bearing, to prevent longitudinal loads that may be imposed upon the drive turbine. The side leakage of oil from the journal bearing is fed to the thrust bearing. The thrust bearing consists of a series of thrust pads mounted in carrier rings at each end of the drive journal bearing. This bearing uses the lubrication principle of the wedge-shaped oil film; that is, an oil film between two sliding surface assume a tapered depth with the thicker film on the entering side. In this assembly, the oil wedges are formed on each bearing pad. The oil automatically assumes the taper required by shaft speed,

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loading and oil viscosity. Thrust is transmitted from the integral rotating thrust collar to (either the active or passive face) through the thrust pads and then to the integral bearing thrust collar. During operation, the shearing of the shaft on the oil film develops heat. The bearing is designed to operate at a certain temperature and any deviation is an indication of a problem, either with the bearing, or with the lubrication system. In order to monitor the bearing temperature, an RTD is embedded in the metal of the bearing. By comparing bearing oil inlet temperature and the embedded bearing RTD, the differential temperature will evaluate bearing performance. Thrust bearings are not normally required on these generators since the shaft aligns itself axially to electrical magnetic center when the field is energized. Should the generator experience a seismic shock, the axial forces of the rotor could cause excessive thrust loads on the generator and reduction gear. The lower half of the driven end bearing housing is provided with the provision for the journal jacking oil piping and thrust jacking oil piping. The lower half of the of the non-drive end bearing housing is provided with the provision for the journal jacking oil piping. These provisions allow for connection to the jacking oil pump, which provides high-pressure oil to lift the rotor shaft off the journal bearings and center the shaft between the thrust bearings. This reduces the torque required to rotate the shaft during start-up or motoring sequences. The shaft-driven lube oil pump is adequate to supply bearing lube oil pressure at speeds above approximately 400 rpm (N2 >3000 rpm). At lower speeds, auxiliary pumps provide lubrication. An orifice in the supply lines controls the bearing oil flow. Drain oil discharges into the bottom of the bearing housing, through a sight flow indicator where it is returned to the lube oil reservoir. Bearing Insulation The generator generates a shaft voltage during operation. When a bearing oil film is locally broken, this shaft voltage results in a flow of shaft current, thus causing the bearing damage. To avoid such difficulties, an insulation sheet is inserted in the exciter end bearing.

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Generator Bearing Seal System GENERATOR BEARING SEAL SYSTEM Pressurized knife-edge oil seals are mounted on the inboard and outboard faces of the bearing housing. The outer chamber is supplied with pressurized air bled from the downstream side of the main generator fan. Pressurization prevents oil and oil vapor from flowing along the shaft and out of the bearing housing. Instrumentation Instrumentation installed within the generator by the generator manufacturer is as follows: •

Four resistance temperature detectors (RTD's) are embedded in each stator winding—one in each winding is a spare.

•

Four RTD's are installed in the air duct flow path—two are operational, two are spares (on water cooled generators they are used to monitor water temperatures).

•

Two dual element RTD’s are embedded in the bearings, one on the generator drive end and one on the exciter end.

•

Two RTD’s are embedded in the thrust bearing, one on the active face and one on the passive face. They are used for diagnostic purposes.

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Two dual element RTD’s are installed in the bearings oil supply drain flow, one on the generator drive end and one on the exciter end.

EXCITER AND DIODE ASSEMBLY The exciter assembly consists of a permanent magnet alternator (PMA), an exciter stator and rotor, a rotating diode rectifier and an earth fault detector. These components are installed at the non-drive end of the generator shaft. The PMA stator consists of a single-phase winding in a laminated core. Permanent magnets rotate on the rotor inside the stator to produce approximately 120VAC at 50 Hz (N2 =3000 rpm). The 4-22

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PMA output AC voltage is rectified and regulated by the modular automatic voltage regulator (MAVR). The exciter stator, which receives the MAVR output DC voltage, is mounted around the exciter rotor. It consists of a stationary ring that supports the stator poles and carries the magnetic flux between adjacent poles. Stator windings are series-wound around laminated poles. The exciter rotor is constructed from punched laminations and contains resin-impregnated, form-wound, and three-phase windings. A rotating diode assembly rectifies the AC voltage induced into the exciter rotor.

Meidensha Diode Wheel

EXCITER DIODE WHEEL

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EXCITER DIODE WIRING EXCITER DIODE WIRING The rotating rectifier (diode wheel) unit is composed of the individually fused silicon diodes, C-R absorbers of which are composed of resistors and capacitors. The silicon diodes are connected to form a 3-phase full wave rectifier circuit. The fuses are mounted on the reverse side of the rotating rectifier assembly. Because diodes have only two failure modes (shorted or open), the fuses provide overcurrent protection. Each diode has a peak inverse voltage that is more than 10 times the rated field voltage. Therefore it has ample tolerance against possible surges.

Typical Diode Wheel From a Brush Generator

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Diode Failure Detection Communication (EMI) surges occurring in the rectifier circuit are completely absorbed by the CR absorbers (capacitor-resistor) circuit connected in parallel with each silicon diode. The rotating rectifier unit is mounted on the cooling fin inside reinforcing ring. The silicon diodes mounted on the rotating rectifier unit of the brushless type generator are required specially to secure high reliability. Failure in these rotating diodes has hardly ever occurs, however, the diode failure relay in the Micro-AVR, detects the exciter current ripple for the AC exciter. Diode failure detection is accomplished by sensing ripple induced into the exciter field caused by the unbalanced load This unit detects any failure in the rotating diodes such as short circuit, disconnecting failure and transmits a failure signal to control panel. The setting for diode failure relay shall be adjusted and confirmed during a commissioning test. The excitation system is designed so that the generator can continue the operation at full load even if one diode has open circuited or one fuse has opened causing the short-circuited diode. In this case, the generator may be kept in service, but it should be shut down at the earliest opportunity to replace the failed diode and fuse.

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Electronic Rotor Earth Fault Detector (FRG-00) The generator field windings and associated connections such as an exciter armature windings and rotor rectifier diode circuit are fully isolated from earth. The generator could operate in the event of a single earth fault, however, the occurrence of a second earth fault results in high fault current and major damage to the generator. Meidensha has developed the electronic rotor earth fault detector for the purpose of continuous monitoring of the insulating level of the rotor windings. The FRG-00 has adopted fully static techniques and design to detect a single earth fault and to give an alarm so that the generator can be taken out of service and repaired at the earliest opportunity. Outline description • During the operation of a generator, it is possible to detect an earth fault in the rotor windings. • The signal transmission system from the rotor side is an electromagnetic induction method so that the system withstands a long time of continuous operation. • While the generator operating condition changes from no load to the rated load, the system operation can be maintained without being fed from an outside power source. • The FRG-00 is capable of checking a fault occurring within itself. Configuration The FRG-00 is comprised of the following components: • Earth Fault Detection Module • Signal Transmission Coils • Earth Fault Discrimination Circuit Unit The power supply for the earth fault detection module located on the rotor side is obtained from the independent sub-coil installed in the same slot as the AC exciter armature winding. The earth fault detector module monitors the insulation resistance of the field winding and generates a required output signal. The signal transmission coils are installed in a pair; one for the rotor and another for the stator. The earth fault discrimination circuit unit is installed inside the generator protection or control panel. It is used for the dissemination of the occurrence of an earth fault and for the generation of the earth fault output signal. Generator Heaters Four heaters are mounted on the bottom section of the generator frame. One heater is mounted on the access plate of the exciter.

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GENERATOR LUBE OIL SYSTEM

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GENERATOR LUBE OIL SYSTEM F&ID – 020020-02-683248 GENERATOR LUBE OIL SYSTEM The generator lube oil system provides pressurized lubrication to the generator bearings. The major components of the lubrication system are as follows: • • • • • •

Lube oil storage reservoir, 205-gal capacity Generator-driven lube oil pump Motor-driven auxiliary AC lube oil pump Generator duplex fan oil cooler Lube oil filter assembly Two lube oil rundown tanks, 16-gal capacity

To prevent damage, the generator bearings must be lubricated whenever the generator rotor shaft rotates. Thus, lubricating oil must be supplied to the bearing assemblies during startups, at operational speeds, and while the rotor shaft coasts to a stop after shutdowns. To ensure that these lubrication requirements are met under all conditions, two independently operated pumps and two rundown tanks are used in the generator lube oil system. 2262533TR

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Generator-Driven Lube Oil Pump This pump, which is mounted to the exciter end of the generator housing, is directly driven by the generator rotor shaft and supplies lube oil to the bearings at the normal operational shaft speed (3000 rpm). Because its efficiency decreases at lower shaft speeds, the pump must be supplemented by an auxiliary pump to ensure adequate lubricating oil flow during startups and shutdowns. Auxiliary Lube Oil Pump The auxiliary pump supplies oil to the generator bearings for the first 5 minutes of startup, during shutdowns, and in case of generator-driven pump failure. This pump is driven by a 2.5-hp, 380-V, 3-phase, 50-Hz AC motor, which is controlled by the turbine sequencer in the TCP. The sequencer monitors the lube oil system pressure and generator shaft speed, and activates the auxiliary pump during generator startups, shutdowns, and any other time that the lube oil pressure drops to 12 psig. A warning indication appears on the DCS monitor should the pump activate with the generator turning at normal operating.

Emergency Lube Oil Rundown Tanks Two lube oil rundown tanks, one for each generator-bearing assembly, have been provided in case of an auxiliary pump failure. During shutdowns, oil stored in these tanks drains to the bearings while the generator rotor coasts to a stop. The 16-gal (61 ltr) capacity of each tank ensures sufficient lubricating capability from 400 rpm to rest.

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Instruments and Controls Manually operated ball valves have been provided to isolate components for repairs and maintenance. System Operation Refer to F&ID Dwg. 020020-01-683248, Generator Lube Oil System in section 7 of the O&M manual set. System operation is as follows for the GTG set: Lube oil pumps draw oil from the system reservoir through independent suction lines. Both pumps feed a common discharge line. A check valve maintains oil in the generator-driven pump to ensure instantaneous oil flow to the bearing assembly whenever the pump begins operation. Valve PCV-0013 prevents the lube oil pressure in the common discharge line from exceeding 30 psig (206 kPaG) and ports excess oil back to the reservoir. A relief valve PSV-0003 prevents pressure at the output of the auxiliary pump from exceeding 85 psig (586 kPaG). Heated lube oil from the discharge of either the generator-driven or the auxiliary pump is cooled by a duplex fin-fan heat exchanger before flowing through the duplex oil filter assembly. The heat exchanger assembly is customer located. The lube oil may bypass the coolers if thermostatic control valve TCV-0000 determines the temperature to be < 140 °F (60 °C). As the lube oil temperature increases during turbine operation, the valve progressively directs more oil through the heat exchanger until, at 140 °F (60 °C), nearly all the oil flows through the heat exchanger. After the lube oil passes through control valve TCV-0000, temperature indicator TE-0025 measures actual lube oil temperature downstream of the cooler, signaling an indicator and activating an alarm and shutdown. Temperature indicator TI-0025 provides a temperature reading to the electronic-turbine control system. Alarm TAH-0025 activates when temperatures reach 160 °F (71 °C) or higher, and a cooldown lockout (CDLO) is activated when temperatures reach 190 °F (89 °C) or higher. From the heat exchanger, the cooled oil flows into the duplex oil filter. This filter has a manual transfer valve that directs all oil through the selected filter element, making the unselected element available for service or replacement. Differential pressure transmitter PDT-0015 indicates the pressure differential across the filter elements. PDT-0015 activates alarm PDAH-0015 at the electronic-turbine control system if the differential pressure reaches 20 psid (138 kPaD). Pressure indicator PI-0015 provides a pressure reading to the electronic-turbine control system. A pressure balance valve has been provided for maintenance use during engine shutdown to confirm that differential pressure gauge PDT-0015 indicates zero when no pressure differential exists. Pressure at the filter output is controlled by pressure control valve PCV-0013 which prevents the supply line pressure from exceeding 30 psig (206 kPaG. This valve protects against overpressure, which can force oil past the seals in the generator-bearing assemblies, by porting excess oil back to the reservoir. Pressure transmitter PT-0026 monitors pressure down stream of the filter, signaling

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an indicator and activating an alarm and shutdowns. Pressure indicator PI-0026 provides a pressure reading to the electronic-turbine control system. Alarm PAL-0026 is activated when pressure drops to 25 psig or less. CDLO shutdown PALL-0026 is activated when pressure drops to 20 psig (138 kPaG) or less, and an FSLO shutdown is activated when pressure drops to 12 psig (82 kPaG) or lower. FSLO shutdown PAHH-0026 is also activated when pressure increases to 60 psig (413 kPaG) or higher. From PT-0026, lubricating oil flows to the two rundown tanks and to the generator shaft-bearing assemblies. Overflow lines connect the tops of the tanks to the drain lines from the bearing assemblies. In each tank, two level transmitters (LT-0041 and LT-0042) monitor tank oil level, intiating a CDLO shutdown (LALL-0041 and LALL-0042) whenever the level drops 6" (152 mm) below the top of the associated tank. Lube oil enters the generator shaft-bearing assemblies through the orifice at the non-drive end and another orifice at the drive end. Sensing elements TE-0021 and TE-0023 monitor bearing temperatures, activating an alarm at 212 °F (100 °C) and initiating a shutdown at 221 °F (105 °C). Sensing elements TE-0035 and TE-0036 monitor the temperature of lube oil leaving the bearings, activating an alarm at 185 °F (85 °C) and initiating a shutdown at 194 °F (90 °C). Sensing elements TE-0021, TE-0023, TE-0035, and TE-0036 transmit this data in the form of 4–20-mA signals to the electronic control system for display on the DCS monitor. Oil from the bearing assemblies is gravity-drained back to the generator lube oil reservoir. Sight glasses in each drain line permit visual verification of oil flow. The air/oil separator on the lube oil reservoir vents any gases entrained in the returning lube oil. Immersion heater HE-0005 maintains the reservoir oil temperature at 90 °F (32 °C). Tank thermometer TE-0020 monitors reservoir oil temperature, and signals temperature indicator TI0020, which provides a temperature reading to the electronic-turbine control system.TE-0020 also activates alarm TAL-0020 if the oil temperature falls to 70 °F (21 °C). Level transmitter LT-0001 activates alarm LAL-0001 if the oil level drops to 10.65" (270 mm) or more below mounting flange of the transmitter (63% of full). LT-0001 activates alarm LAH-0001 if the oil level rises to 5" (127 mm) or higher below the mounting flange of the transmitter (83% of full). LT-0001 will initiate a shutdown if the oil level falls to 13" (330 mm) or lower below the mounting flange of the transmitter (55% of full).

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OPERATOR SCREENS The GTG Overview screen allows basic monitoring and control of the overall system. Control functions are accessed by faceplate pop-ups. Each control faceplate allows operator interaction and gives associated feedback. The screens displayed by the system software show critical operating parameters and system set points. Each screen and the information that it contains may be accessed by pressing its corresponding function key. The Unit Main Menu Screen illustrates the plant’s main menu, providing a graphic hierarchy from the highest plant level. Any operator screen can be navigated by clicking on the associated identifier and text description.

Generator Lube Oil System Screen Display The first unit level sub-graphic in each group can be navigated by clicking on the associated unit group. The Generator Lube Oil Screen display can be accessed from function G1B5, as shown above.

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Generator Ventilation and Combustion Air System Screen Display

Performance Screen Display

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POWER CONTROL AND SYNCHRONIZATION

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TYPICAL POWER PLANT WITH TWO GENERATORS POWER DISTRIBUTION The diagram above is a one-line drawing, illustrating the three-phase distribution of power in a typical power plant with two power generators. Devices and components that connect power generators to the power delivery point, and to metering, protection, and control circuitry, constitute the Power Distribution System. The major components of the power distribution system include power transformers, potential transformers (PTs), current transformers (CTs), and circuit breakers. TRANSFORMERS All transformers step up or step down voltages in proportion to the ratio of turns on their primary and secondary windings, but differ in design according to application requirements. Power transformers (1) are designed to transfer power from one voltage level to another. Efficient power transformers require large wire sizes and massive ferrous cores. Generators furnished by G.E Aero Energy Products deliver power at 11 kV in 50-Hz systems or 13.8 kV in 60-Hz systems. Power transformers (1) (above) transform the generator bus voltage to the utility bus level, to a lower level for the motor control center (MCC). The MCC distributes lower voltage to

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motors, pumps, heaters, and other internal power plant equipment, which is discussed in another section. Current transformers (4) are used to measure current flowing in conductors. They have many turns on their secondary windings and few turns on their primary windings. The primary windings are wired in series, with connected loads to impose as little burden, or loss, as possible on the power system. The secondary windings provide a relatively low voltage, which is proportional to the current flowing in the primary windings. Current transformers furnished by S&S Energy Products typically have turns ratios of 2000:5, or 400 amperes per ampere in 11-kV applications, and 3000:5, or 600 amperes per ampere in 13.8-kV applications. Measurement instrumentation, connected to the secondary windings, is calibrated for 5 amperes full scale or approximately 38.1 MVA in 11-kV systems and approximately 71.7 MVA in 13.8-kV systems. Mega-volt-amperes (MVA) are calculated as follows: VA

3 / 1 × 106 = 3-phase MVA

(13,800 × 3000 × 1.732/106 = 71.7 MVA or 11,000 × 2000 × 1.732/106 = 38.1 MVA) The secondary windings of CTs should not be opened when power is applied. Voltage buildup in the secondary windings can exceed breakdown levels. Current transformer secondary windings should be connected (shorted) when not connected to measurement equipment or other loads. Potential transformers (3) are used to measure and monitor high voltages. To reduce dangerous high voltages to safe levels for instrumentation and personnel safety, PTs have many turns on their primary windings and few turns on their secondary windings. The high-voltage primary windings are connected between points across which voltage is to be measured or monitored. The lower voltage secondary winding is proportional to the high-voltage primary winding by the primary to secondary turns ratios of the transformer. Ratios of 100:1 are typical for compatibility with the generator voltage regulator and synchronizer subsystems.

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POWER DISTRUBUTION CIRCUIT BREAKERS Circuit breakers (2) connect or disconnect conductors and are designed to operate at various voltages and loads. Circuit breakers connect (make) or disconnect (break) voltages in the 15-kV range carrying currents of 3000 amperes. Large circuit breakers are opened and closed by mechanically wound springs. Direct-current (DC) motors, supplied by batteries, wind (or charge) the springs. Electric solenoids, activated by external low-current contacts, close or open (trip) the circuit breakers. Should the charging system fail, the charging springs may be wound by hand-operated cranks called charging cranks. Once the charging springs are wound, the breakers may be tripped or closed by hand-operated levers on the front of the breaker units. Circuit breakers are designated by numbers assigned by a convention established by the Institute of Electrical and Electronics Engineers (IEEE). Breakers numbered 52G are generator breakers; breakers designated 52L are load breakers. When more than one generator or load breaker is used in a particular location, it is followed by a number (e.g., 52G-1, 52G-2 or 52L-1, 52L-2, etc.). To minimize wear on circuit breaker contacts, it is advisable to close and open them when current flow through the breaker contacts is as small as possible. A serious contact wear problem occurs when breaker units are tripped under high-inductive loading conditions. In such cases, an arc forms across the newly formed air gap between the contacts through which current tends to continue flowing. For this reason, and to lessen the impact on other components, generator loading is reduced to approximately 1.5 MW or less before the contacts are opened.

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Single-Generator Instrumentation and Control Interconnections EQUIPMENT INTERFACES Illustrated above is a three-line drawing, indicating the typical interconnection of PTs, CTs, and circuit breakers needed to provide synchronization, metering, protection, and control circuitry for a single generator. A PT is installed on each side of the generator circuit breaker for voltage monitoring. The synchronization control subsystem enables the circuit breaker to close only when the voltage magnitudes and phase angles on each side of the circuit breakers are identical. Synchronization can be accomplished manually or automatically by monitoring these voltages. The modular automatic voltage regulator (MAVR) establishes generator excitation current based upon generator load or voltage output requirements. Since load measurement requires a voltagecurrent calculation, both are applied to the unit. The MAVR is discussed in the Excitation Current Control section.

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Other connections are required for metering and protection requirements. Differential current protective relays (87G), for example, measure the current into and out of each stator winding and trip the generator output circuit breaker if a difference occurs. Such a difference would occur if a short or current leakage path developed between stator windings or between a winding and ground. The 87G relay and other protective relays are discussed in the Generator Protective Relay System section in this manual.

ONE-LINE DIAGRAM (Dwg. XXX031, Sht. 1)

The equipment interfaces illustrated on the previous drawing can be located on the typical electrical one-line drawing above. Connections that are noted as “Continued on Sheet 2” are applied to metering and synchronizing circuitry. It should be noted that the DGP™ block refers to the Digital Generator Protection System, which is discussed in the Generator Protective Relay System section. Rotor ground fault relay 64 and alarm relay 74 connect to the Micronet Computer and cause engine shutdown, as do signals from the vibration, fire protection, and other engine support systems. The MCC is indicated with its step-down transformer for powering pump motors, ventilation fans, the hydraulic engine starting motor, and other 480- or 360-volt equipment. The MCC is discussed in the Motor Control Center section. Inside the MCC is a lighting-and-distribution 2262533TR

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panel. The lighting-and-distribution panel distributes power for battery chargers, lighting, and other equipment requiring 120 volts.

One Line Diagram Synchronizing Circuitry (Dwg. XXX031, Sht. 2)

Sheet 2 (above) of the typical one-line diagram, indicates connections to synchronizing and metering circuitry. The digital synchronizer module (DSM), veri-sync 25A and 25B relays, the synchroscope, and the synchronizer lights are indicated. These devices are discussed in the Synchronization section. The synchronizing circuitry may be switched via relays to allow synchronization across one of several circuit breakers in a power system.

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Synchronization Meter and Lights

GENERATOR CONTROL EFFECTS vs. OUTPUT CIRCUIT BREAKER STATUS OPERATOR CONTROL INPUTS

CIRCUIT BREAKER OPEN

CIRCUIT BREAKER CLOSED

INCREASE/DECREASE ENGINE THROTTLE POSITION

INCREASE/DECREASE GENERATOR OUTPUT FREQUENCY

INCREASE/DECREASE GENERATOR POWER OUTPUT

INCREASE/DECREASE GEN. EXCITATION CURRENT

INCREASE/DECREASE GENERATOR OUTPUT VOLTAGE

INCREASE/DECREASE GENERATOR POWER FACTOR/VAR LEVELS

Generator Controls

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GENERATOR CONTROLS Power Factor and Volt-Amperes Reactive With the circuit breaker open, increasing or decreasing generator excitation current increases or decreases the generator output voltage, and increasing or decreasing engine speed increases or decreases the generator output frequency. When the circuit breaker is closed, however, varying excitation current and engine speed have entirely different effects. The table above compares the effect of changing excitation current and engine speed with the generator output circuit breaker open and closed. When the breaker is closed, it is assumed that it is closed onto an infinite bus. * When the circuit breaker is closed, a varying engine throttle position no longer affects frequency. Power is increased as more fuel is added and decreased when fuel is reduced, as can be seen by increases or decreases in megawatt output, and by observing voltage-phase angles at random points in the power system and comparing them with the voltage-phase angle at the powergenerating sources. The voltage at each power-generation point will lead the voltage at load points as a function of load characteristics and, to some extent, propagation time. These differing values may be expressed as angular displacements in the sinusoidal voltage waveform. Current flow (and, therefore, power) increases into any load from a source whose voltage angle leads those from other sources. The lead angle is increased as more generator-driving shaft horsepower is added, thus directly relating shaft horsepower to electrical power output. *

An infinite bus is generally considered one in which the power contributed by a single generator is not greater than 1/20th the total power supplied to the bus

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Current, Voltage, and Power Relationships When the circuit breaker is closed, varying excitation current no longer affects voltage; only the angle between the current and voltage is affected. The current-voltage angle relates to the characteristics of the load imposed on the generator and to generator excitation current. Figure (A) above illustrates voltage (e), current (i), and the product of e and i for one cycle of current and voltage. The product (p) is the power waveform produced by multiplying e × i at each instant in the cycle. Because e and i are in phase (i.e., cross zero at the same time), p is never negative. This condition exists when loads are resistive without inductance or capacitance. When loads are inductive, i is forced to follow e as a function of the amount of inductance. Figure (B) illustrates a case where i lags behind e by approximately 30°. In this case, e is negative for a portion of the cycle before i becomes negative. During this interval, p is negative because of the algebraic product of negative and positive values. The result is a downward shift in p average. Figures (C) and (D) show a progression where i lags further and further behind e, with corresponding lower and lower values of p. In Figure (E), the shift is 90°. In this case, p average is zero. Figure (F) is a vector diagram that simplifies discussion of the current/voltage relationship. Real power is related to the metered values of e and i and the lag angle θ. As the angle increases, real power is lowered. At θ = 90°, real power is zero.

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The voltage and current product is often referred to as volt-amperes (VA) or mega-volt-amperes (MVA). By definition, the trigonometric cosine of the angle θ has been named power factor (PF). Real power then is the product of VA and PF. p = VA (PF) or p = VA (cos θ. The vector diagram in Figure (F) also includes a var component. Volt-amperes-reactive are the component of power. Volt-amperes-reactive increase as real power decreases and are a convenient reference of how much real power a generator or power station is producing. The relationship between VA, var, and PF can also be expressed as follows: (Real Power)2 + (var)2 = (VA)2 or Real Power = (VA)2 − (var) 2 Most industrial loads are inductive; however, capacitive loading can occur. Capacitive loads cause an opposite effect wherein current leads rather than lags voltage. In such cases, var becomes negative. Since var can be negative or positive, var always carries a sign prefix. Increasing or decreasing generator excitation current can control power factor or var. As excitation current into the generator increases, the PF angle and var increase and, conversely, decrease as excitation decreases. The control system is capable of regulating excitation current to control var or PF.

BRUSHLESS EXCITATION SCHEMATIC

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Typical Generator Exciter

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EXCITATION CURRENT CONTROL EXCITATION CURRENT CONTROL The brushless excitation scheme, as previously discussed, uses a permanent magnet generator (PMG) to generate excitation current. The Micro-AVR voltage regulator rectifies the alternatingcurrent (AC) output of the alternator and regulates the resulting direct-current (DC) flow through the exciter field windings. The regulator, manufactured by Brush Electrical Machines, Ltd., has been given the product name Microprocessor Automatic Voltage Regulator, or MicroAVR. Silicone Controlled Rectifier With Input and Output Waveforms Silicone Controlled Rectifiers, also referred to as Thyristors, are similar to diodes with the exception of a third so-called “Gate” connection. The symbol for an SCR is shown at the top of the above illustration. Below the SCR symbol are waveforms at its “A” and “B” connection points. When the switch in the diagram is open, and there is no connection between the Cathode and Gate terminals, the SCR blocks Anode signals from reaching the Cathode, however, when the switch is closed, connecting the Gate to the Anode, the unit performs like an ordinary diode passing only the positive half-cycle of the signal at its Anode to the Cathode. The waveform (B) indicates the portion of the positive half cycle appearing at the Cathode if the switch closure is delayed until the 135º point of the positive-going half cycle at “A”. By delaying the switch closure, the percentage of the positive half cycle at “A” appearing at “B” can be controlled thus performing the dual function of rectification and DC regulation.

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Micro Automatic Voltage Regulator Functional Block Diagram

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The SCR, in the above diagram, rectifies AC current from the generator shaft-driven permanent magnetic alternator (PMA) and provides controlled DC current into the generator exciter field windings. Current and potential transformers sense the generator bus voltage and current from the generator bus. The voltage and current values, when multiplied, provide VA data. Voltage and current zero crossover points provide current lead or lag angles for calculation of power factor and VARS. (Power Factor = VA Cosine of the measured angle; VARS = VA Sine of the measured angle). The calculated power factor or VAR value is selected from a switch on the Turbine Control Panel (TCP) labeled “P.F./VAR Select.” This signal is applied to the inverting input of summing junction (a). The non-inverting input is derived from a motor operated potentiometer adjusted from the TCP by a momentary raise or lower switch labeled “Auto Raise/Lower.” The resulting error signal drives SCR Gating Pulse Generator (a). The error signal that drives SCR Gating Pulse Generator (b) is derived from a second motor operated potentiometer controlled from the TCP by a switch labeled “Manual Raise/Lower.” The manual raise lower input operates only when the “Auto/Man Select” switch is in the “Man” position. The automatic raise lower input operates only when the “Auto/Man Select” switch is in the “Auto” position. Inter-communication connections between the two pulse generators allow the inactive channel to track the active channel thus preventing transients in the SCR circuit when transferring between automatic and manual modes. A TCP mounted null meter (N.M.) indicates any difference between the two channels. It should be noted that closed-loop control is provided only in the automatic operational mode. When manual mode is selected, the control loop is open since there is no feedback to create an error signal. The SCR circuit includes a TCP mounted interrupting switch labeled “Exciter On/Off” and monitoring circuitry that senses excitation current and voltage. The monitoring circuit is interconnected with the “Auto/Man Select” switch and with the Digital Protective Relay system. The monitor circuitry generates operator alarms, automatically switches from the automatic to the manual channel, and initiates protective relay functions as appropriate to maintain the generator excitation current within the limits of the generator’s operational capability curves. LED indications on the Micro Automatic Voltage Regulator panel indicate the parameter or parameters that have exceeded their normal operational limits. (See MAVR front panel descriptions) Alternative configurations are supplied as customer options to allow added control flexibility for operational situations that require them. A voltage control optional input into summing junction (a) from a generator bus PT provides a third control selection using the “P.F./VAR Select” switch, e.g., voltage in addition to power factor and VARS. The voltage control option can provide added stability when the generator is

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connected to less than an infinite bus and voltage varies significantly with load changes or in “islanded” installations. A voltage control input and a second summing junction “(b)” can be implemented as an option allowing voltage control rather than fixed control when the manual mode is selected. Voltage from a generator bus PT is applied to summing junction (b) where it is summed with the output from the “Man Raise/Lower” motor operated potentiometer. SCR pulse generator (b) is then driven to raise or lower the generator bus voltage to null the motor operated potentiometer set point. The manual voltage control option is typically an internal implementation without front panel selection.

MICROPROCESSOR AUTOMATIC VOLTAGE REGULATOR THEORY OF OPERATION The Microprocessor Automatic Voltage Regulator (MicroAVR) is designed to control the excitation of a brushless generator. It is housed in a 19-inch rack assembly requiring only external instruments and control switches to provide the complete excitation system. The MicroAVR incorporates independent main and standby excitation channels with built-in monitors, which automatically select standby control in the event of a fault being detected. An automatic follower is provided to adjust the setting of the standby regulator to match that of the main automatic voltage regulator (AVR).

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The standby regulator can be selected to function as an automatic voltage regulator requiring the minimum of adjustments, or, if preferred, as a conventional manual regulator requiring manual voltage adjustments as load changes. The unit is provided with a hand-terminal, which is used during commissioning and maintenance. It makes adjustment of the regulator or monitor simply a matter of keying in the required parameters, which are indicated on a digital display. It can be used to display voltage rise time and overshoot or it can display critical AVR parameters during fault diagnosis.

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Standby Module Standby Module The standby control module provides a completely independent means of controlling excitation. The standby excitation system can be selected to function as an AVR requiring the minimum of adjustment, or, if preferred, as a conventional manual regulator, providing a wide range of exciter field control. This is especially useful during commissioning or generator testing. As with the main control channel, control is provided by a single-phase, full-wave, half-controlled bridge rectifier for the AVR. Manual control uses the same bridge rectifier and shares the standby digital reference affected by the raise/lower logic. Other features include an automatic follower to keep the standby regulator tracking the main control channel, low-frequency cutoff, and a field voltage limiter and null balance indication using local LED's or a remote balance meter. Standby Module LED Indications LED 1 Standby Low – Indicates that the standby is firing later than the main AVR. When both LED’s are extinguished, this indicates a balance between the main AVR and the standby AVR.

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LED 2

Standby High – Indicates that the standby is firing earlier than the main AVR. When both LED’s are extinguished, this indicates a balance between the main AVR and the standby AVR.

LED 3

Standby Power Supply Healthy – Indicates the state of the standby power supply.

LED 4

Control Power Supply Failed – Indicates that the main control card power supply has failed. The AVR will transfer to standby.

LED 5

Standby At Minimum.

LED 6

Main Control Operating – Indicates that the main AVR is operational.

Button

Standby Raise – Increases MicroAVR voltage output.

Button

Standby Lower – Decreases MicroAVR voltage output.

Button

Auto Channel Supply – Main power switch for the MicroAVR.

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Utilities Module Utilities Module The utilities module provides separate regulated power supplies (derived from the permanent magnet pilot exciter) for the main auto control module, monitor module and the hand-held terminal. It also provides generator diode failure circuitry, which is functional in main or standby control. The voltage sensing transformers for the main control module are also located in the utilities module. Utilities Module LED Indications LED 1

Control ±15V Healthy – Indicates that the control module power supply is energized.

LED 2

Monitor ±15V Supply Healthy – Indicates that the monitor module power supply is energized.

LED 3

Monitor 5V Healthy – Indicates that the monitor module power supply is energized.

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LED 4

Control 5V Healthy – Indicates that the control module power supply is energized.

LED 5

General Alarm – Indicates that one of the following fault indications has occurred: ¾ Loss of monitor power supply ¾ Loss of standby regulator power supply ¾ Monitor card microprocessor fault

LED 6

Monitor Tripped – Indicates that one of the following conditions has occurred: ¾ ¾ ¾ ¾ ¾ ¾

Main control card RAM battery backup low Over voltage Under voltage Over excitation Under excitation Over flux

Main control card microprocessor fault LED 7

Diode Failure – Indicates that a diode has failed. A diode failure relay detects exciter field current ripple and when this exceeds a pre-set limit, the LED illuminates.

LED 8

Spare

Button

DFI Test – Provides a means of testing the diode failure circuit. Approximately 2 seconds after pressing the button, local indication is given and the diode failure alarm relay is energized.

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Control Module Control Module (Main Auto) This card contains the control microprocessor and its software, and the associated hardware interfaces. The control program resides in read-only memory (ROM), and the control settings, which are specific to the contact, are programmed into battery backup random access memory (RAM) using the hand-held terminal. These settings are made during factory testing and are later checked during commissioning. This card measures line voltage (three phase) and current signals (single phase) and provides firing pulses to control the thyristor rectifiers located in the main frame. The firing pulses are adjusted to maintain the excitation at the required level. Control Module LED Indications LED 1

Memory Battery Low – Indicates state of battery which backs up contact data programmed into memory. Battery life is 5–10 years.

LED 2

Watchdog Dropout – Indicates that the program has failed to cycle.

LED 3

Over excitation Limiter – Indicates that the MicroAVR has reached its over excitation limit.

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LED 4

Under excitation Limiter – Indicates that the MicroAVR has reached its under excitation limit.

LED 5

Power Factor Control – Indicates that power factor control has been selected.

LED 6

Overflux Limiter – Limits the voltage/frequency ratio to a level adjustable between 1.08 and 1.20 per unit.

LED 7

var Shed – Sheds var’s based on predetermined increments.

LED 8

var Control – Indicates that var control has been selected.

Micro Reset Resets the microprocessor timing, which is controlled by a 16-MHz crystal. Serial Communication Port Provided for transmitting and receiving information to and from a remote terminal or a hand-held terminal for commissioning and maintenance.

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Monitor Module Monitor Module The monitor module is similar to the main control module and contains the control microprocessor and its software, and the associated hardware interfaces. The monitor program resides in ROM and the project-specific monitor settings are programmed into battery backup RAM using the hand-held terminal. These settings are made during factory testing and are later checked during commissioning. The MicroAVR transfers from the main control channel to the standby control channel on the operation of any of these monitors. A monitor latch/reset facility is provided which allows resetting by pushbutton when the fault has been removed. A monitor inhibit feature is available for control by an external switch signal. A monitor fault alarm is provided to energize the general alarm relay on the utilities module and prevent automatic selection of standby control in the event that one of the following occurs: ¾ Monitor power supply failure ¾ Standby module power supply failure ¾ Monitor watchdog dropout alarm ¾ Monitor battery low alarm

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Monitor Module LED Indications LED 1

Memory Battery Low - Indicates state of battery which backs up contract data programmed into memory. Battery life is 5–10 years.

LED 2

Watchdog Dropout – Indicates that the program has failed to cycle.

LED 3

Over excitation Monitor – Indicates that an over excitation condition has occurred (AVR trips to standby after 5 seconds).

LED 4

Under excitation Monitor - Indicates that an under excitation condition has occurred (AVR trips to standby after 5 seconds).

LED 5

Over voltage Monitor – Indicates that an over voltage condition has occurred (AVR trips to standby after 6 seconds).

LED 6

Under voltage Monitor - Indicates that an under voltage condition has occurred (AVR trips to standby after 6 seconds).

LED 7

Over flux Monitor – Monitors the voltage/frequency ratio to ensure that it is within limits.

LED 8

Spare

LED 9

Control Failed Button Mon Reset – – Indicates that a watchdog dropout alarm has occurred.

LED 10

Spare

When any of the monitor functions trip, they remain latched until the fault has been corrected and this button is pressed. Micro Reset Resets the microprocessor timing that is controlled by a 16-MHz crystal. Serial Communication Port Provided for transmitting and receiving information to and from a remote terminal or a hand-held terminal for commissioning and maintenance.

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Typical Generator Capabilities Diagram GENERATOR CAPABILITY LIMITS The diagram above describes a typical generator’s capability diagram or operating chart that indicates the operating conditions of a generator in relation to the various constraints, which apply. Section A of the curve indicates the reactive limit necessary to prevent overheating of the excitation windings. Section B indicates the limit placed by rated stator current. Section C indicates the under excitation limit and with excitation levels below this the machine may not develop enough synchronizing torque to remain in step with the system and may pole slip. At an operating point, such as x in the generator capability diagram the sides of triangle a, b, and c relate to var’s, real power, and VA as it does in the power triangle located to the left of the capability diagram. The values of PF, var’s, real power, and VA can be determined for each boundary point in the capability diagram. These parameters should be visualized by operators and related to the capability diagram of their particular generator.

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Microprocessor Automatic Voltage Regulator Main Chassis OPERATOR CONTROL PROCEDURES Startup At startup, the REGULATOR ON/OFF switch (ES, Generator Excitation) should be in the ON position and the EXCITATION MODE SELECT switch should be in the AUTO position. When the generator is a synchronous speed, the generator voltage will ramp to nominal voltage level through the AVR controls. The AUTO R/L control should then be used to match the generator voltage and the bus voltage as part of the synchronization procedure. (See Synchronization Procedures section.) WARNING: THE GENERATOR EXCITATION SWITCH (ES) IS USED FOR COMMISSIONING AND FAULT FINDING, AND SHOULD BE OPERATED BY TRAINED PERSONNEL ONLY. After the circuit breaker is closed and the generator is producing power, the AUTO R/L control can be adjusted for the desired operating point within the capability limit curve for the generator. The selection of VAR or POWER FACTOR control is made by a strap setting within the module or by an optional switch on the TCP. Automatic-to-Manual Regulator Failover Should the unit fail over to manual mode, the operator should adjust the MAN R/L control to achieve an operating point within the safe operating limits of the generator’s capability.

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Manual-to-Automatic Regulator Changeover As previously mentioned, the manual regulator automatically tracks the automatic regulator to prevent transients in the regulator output when a transfer from automatic to manual mode occurs. Switching back to automatic mode without a transient, however, requires a manual procedure as follows: ¾ Adjust the manual regulator output by lowering or raising the MAN R/L controls until the generator is operating within safe limits. ¾ When zero is indicated on the null meter, release the AUTO R/L control and place the EXCITATION MODE SELECT switch in the AUTO position. Lamps on the TCP and/or information blocks on the cathode-ray tube display indicate a successful transfer from manual to automatic.

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SYNCHRONIZATION

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Synchronization Circuitry SYNCHRONIZATION CIRCUITRY Synchronization circuitry is implemented in the GE Aero Energy Products control system to allow operators to match the voltage, frequency, and phase of the generator voltage to the voltage on the opposite side of the 52G generator circuit breaker. Options are available to connect the synchronizing circuitry across breakers in power systems other than the 52G breaker. Regardless of the circuit breaker across which synchronization occurs, the requirements are the same (i.e., the voltage, frequency, and phase on each side of the respective breaker must be the same for safe breaker closure). The functional diagram above illustrates the synchronizing circuitry. Potential transformers (PTs) provide voltage sense inputs from both sides of the circuit breaker that are to be closed. The sense voltages are applied to two Veri-Sync relays and a digital speed-matching (DSM) module. The Veri-Sync relays are connected to different phases (B-C and A-B), and the DSM is connected between the A and the C phases. The arrangement assures that all three-phase voltages meet synchronizing requirements. Contacts within each module close when matching conditions are met and are wired in series to enable circuit breaker closure.

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The SYNCHRONIZE switch (S1) is a three-position switch on the turbine control panel (TCP). In the OFF position, power to the Veri-Sync relays is interrupted and the DSM module is disabled. It is good practice to place the switch in the OFF position when the synchronizing circuitry is not in use. ¾ In the AUTO position, the DSM module drives the turbine raise/lower speed controller to match the generator frequency to the generator bus frequency and drives the microprocessor automatic voltage regulator (MicroAVR) to match the generator and bus voltages. In the AUTO position, contacts in the veri-sync and DSM modules directly connect to the circuit breaker close contacts. ¾ In the MAN position, automatic engine and voltage raise/lower outputs are disabled and operators must manually operate engine and voltage raise/lower controls to achieve synchronizing conditions. The TRIP/CLOSE switch (S2) must also be operated by hand to achieve circuit breaker closure. Veri-Sync and DSM modules continue to monitor synchronizing conditions and prevent closure of the circuit breaker under unsafe conditions. It should be noted that circuit breaker trip contacts can be operated at any time through S2, regardless of loading conditions. Lamps connected between phases B and C are provided on the control panel for operator monitoring. When the two voltages are at minimum phase-angle difference, the voltage difference will also be at minimum, causing minimum current flow through the lamps. The synchroscope, connected between phases A and B, has a 360° pointer that rotates at a speed proportional to the phase-angle difference between the voltages. Its direction of rotation is determined by which voltage is faster or slower. When the generator frequency is higher than the generator bus frequency, rotation is clockwise and, conversely, counterclockwise when the generator frequency is lower than the generator bus frequency.

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SYNCHRONIZATION SYNCHRONIZATION PROCEDURES Before starting the synchronization procedure, ensure that the turbine engine has reached syncidle speed. Manual Synchronization The procedure for Manual synchronization is as follows: ¾ Position the SYNCHRONIZE switch (S1) to the MAN position. ¾ Using the MicroAVR AUTO R/L control handle, match the generator and bus voltages displayed on the synchronization cubicle front-panel meters. ¾ Operate the Power Turbine Raise/Lower speed control until the synchroscope rotates slowly in the slow-to-fast (clockwise) direction. Observe the synchroscope lamps are at minimum illumination as the synchroscope nears the 12 o’clock position.

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¾ Position the CIRCUIT BREAKER TRIP/CLOSE switch (S2) to the CLOSE position when the synchroscope reaches the 11 o’clock position during its slow (clockwise) rotation. Synchronization is indicated by the synchroscope stopping at the 12 o’clock position and the red CIRCUIT BREAKER CLOSED lamp illuminating. Automatic Synchronization The procedure for Automatic synchronization is as follows: ¾ Position the SYNCHRONIZE switch to the AUTO position. ¾

Observe the SYNC LIGHTS and SYNCHROSCOPE for synchronization lock.

Observe that the red CIRCUIT BREAKER CLOSED indicator illuminates.

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DIGITAL GENERATOR PROTECTION SYSTEM

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M-3425 Generator Protection System DIGITAL GENERATOR PROTECTION SYSTEM THEORY OF OPERATION The M-3420/3425 generator protection system is a microprocessor-based unit that uses digital signal processing technology to provide seventeen protective relaying functions for generator protection. The M-3420/3425 can protect a generator from abnormal voltage and frequency, internal winding faults, system faults, inadvertent energizing, negative sequence current, reverse power, loss-of-field, over excitation (V/Hz) disturbances, while also providing loss-of-VT-fuse detection, and breaker failure/flashover protection. Six input contacts can be programmed to block any relay function and/or trigger the oscillograph recorder. Any of the functions or the input contacts can be individually programmed to activate any one or more of the eight programmable output contacts. The M-3420/3425 provides time-tagged target information for the thirty-two most recent events and includes self-test, self-calibration and diagnostic capabilities. A switching mode power supply provides the M-3420/3425 with the various power supply voltages required for operation. A redundant power supply is available as an option.

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With the optional M-3931 MMI (Man-Machine Interface) Module, The M-3420/3425 also provides capability for local metering of various quantities, including phase, neutral, and sequence voltage and currents; real and reactive power, power factor, and positive sequence impedance measurements.

PROTECTIVE RELAY FUNCTIONS TABLE 3420 Relay No.

Description

24

Volts/Hertz function provides over-excitation protection for the generator and unitconnected transformers. Includes delayed trip and alarm functions.

27

RMS Under voltage function detects any condition causing long-term generator under voltage.

32

Directional power function provides anti-motoring (power flow to generator) and overload protection. Includes time delay to avoid transient trips.

40

Loss of Field function provides protection for a partial or complete loss of field excitation.

46

Negative Sequence Over current function provides protection against possible rotor overheating and damage due to unbalanced three phase currents in the generator.

51V

Inverse Time Phase Over current with Voltage Control relays, one per phase, are used to trip circuits selectively and to time-coordinate with other up or down stream relays. Time-coordination allows lower-level breakers to open and prevents fault propagation.

59

RMS Over voltage function provides over voltage protection for the generator.

81

Frequency function provides either over- or under frequency protection of the generator. Under frequency causes generator heating; over frequency damages connected loads.

86

Trips output circuit breaker if other interconnected relays detect unsafe conditions. Fault conditions must be corrected before reset is permitted.

87GD Ground Differential function provides ground fault protection. Phase Differential function provides protection for all internal winding faults.

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ADDITIONAL RELAY FUNCTIONS TABLE 3425 24

Volts

27TN64S Stator GND 21

Phase Distance.

78

Out of Step.

51T

Pos Seq Overcurrent.

46

Neg Seq Overcurrent.

64F/8 Field GND Brush Lift. 818R Frequency/Proof. Protective Relay Function Table Protective relays are assigned standard numbers that define their functions, in accordance with the National Electrical Code and the Institute of Electrical and Electronics Engineers (IEEE). The table above provides a brief description of the important generator protective relay types used in this system. Each of these relays is reset by a target-reset pushbutton on the panel. The 86 relay is operated by other relays. It, in turn, trips the 52G circuit breaker. The 86 relay must be reset with a manual handle; however, it cannot be reset until the relay (or relays) that caused the 86 to operate have been reset. It is recommended practice that operators notify supervisory personnel before resetting any relay that has operated to allow troubleshooting. The cause of operation of any protective relay should be understood before a reset is permitted.

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M-3420/3425 GENERATOR PROTECTION SYSTEM M-3420 Generator Protection System Front Panel 1. Com 1 – Standard 9-pin RS-232C DTE-configurated communications port. This port is used to locally set and interrogate the M-3420 via a portable computer. 2. Relay OK – Green LED that is under control of the M-3420 microprocessor. A flashing OK LED indicates proper program cycling. The LED can also be programmed to stay lit continuously. 3. Time Sync – Green LED will light to indicate that the IRIQ B time signal is received and validated. This IRIQ B signal is used to correct the hour, minute, seconds and millisecond information. When the IRIQ B signal is synchronized, the real time clock will be corrected every hour.

BRKR Closed – Red LED will light to indicate when the breaker status input (52b) is open. Osc. Trig – Red LED will light to indicate that the oscillograph data has been recorded in the unit’s memory. Target – This LED will illuminate when any of the relay functions operate. Diagnostic – Red LED will flash ERROR CODE number if any. PS1/PS2 – Green LED’s will remain lit for the appropriate power supply as long as power is applied to the unit and the power supply is operating properly. Target Reset – This pushbutton resets the target LED if the conditions causing the operation have been removed. It is reset by pressing and then releasing the button immediately, (this action also provides a means for testing the LED’s). Holding the TARGET RESET pushbutton displays the present pickup status of the M-3420 functions.

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M-3931 MAN-MACHINE INTERFACE M-3931 Man-Machine Interface (MMI) The M-3931 MMI module provides the means to interrogate the unit and input settings or access data directly from the front panel. The indicators and controls consist of: 1

LCD – Displays menus, which guide the operator to M-3420 function or set point values. Menus consist of two lines. The top line provides a description of the current menu selection. The bottom line lists lower case abbreviations of each menu selection with the current menu selection highlighted by being in uppercase. While the unit is not in use, and has not operated, the user logo lines are displayed until ENTER is pressed, at which time the first-level menu is displayed. If the unit has operated, the LCD cycles through a sequence of screens summarizing the operation status conditions (targets) until ENTER is pressed.

2

Arrow Pushbuttons – The left- and right-arrow pushbuttons are used to choose among menu selections displayed on the LCD. When entering values, the left- and right-arrow pushbuttons are used to select the digit (by moving the cursor) of the displayed set point that will be increased or decreased by the use of the up- and down-pushbuttons. The up- and down-arrow pushbuttons only increase or decrease input values or change between upper and lower case inputs. Upper case inputs are active whereas lower case inputs are inactive. If the up or down button is held when adjusting numerical values, the speed of increment or decrement is increased.

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3

Exit Pushbutton – Used to EXIT from a displayed screen to the immediately preceding menu. Any change set point will not be saved if the selection is aborted via the EXIT pushbutton.

4

Enter Pushbutton – Used to choose a highlighted menu selection, to replace a set point or other programmable value with the currently displayed value, or to select one of several displayed options (such as ENABLE or DISABLE a function)

M-3920 Target Module M-3920 Target Modules The target module includes 24 individually labeled TARGET LED’s (Light Emitting Diodes) to target the operation of the M-3420 functions on the front panel. Target Indicators – Normally, the 24 red TARGET LED’s are not lit. Upon operation, the LED’s corresponding to the cause(s) of the operation will light and stay lit until reset, while the eight OUTPUT LED’s will reflect the present state of the OUT1 – OUT8 output contacts. Pressing and releasing the TARGET RESET pushbutton will momentarily light all LED’s (providing a means to test them) and resets the TARGET LED’s if the condition causing the operation has been removed. Detailed information about the cause of the last 32 operations is retained in the unit’s memory for access through the LCD display via the VIEW TARGET HISTORY menu. 2

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Output Indicators – Indicate the status of the programmable output contacts.

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Accessing Screens To prevent unauthorized access the M-3420 has three levels of access codes. Each access code is a user defined one- to four- digit number. 1

Level 1 Access – Read set points, monitor status, view target history.

2

Level 2 Access – Read and change set points, monitor status, view target history.

3

Level 3 Access – Access to all M-3420 configuration functions and settings.

A level 3 user can only alter access codes.

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MOTOR CONTROL CENTER

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Typical Motor Control Center

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TYPICAL MOTOR CONTROL CENTER The motor control center (MCC) is a power distribution circuit breaker array that provides overload protection and switching of power to devices such as motors and heaters. The assembly also provides circuit breaker protection for lighting and distribution circuits. Each circuit breaker is labeled on the front panel. Primary 3-phase power enters through cables at the upper-left corner panel. Busbar connections are routed from the primary 3-phase input cable connection lugs throughout the cabinet. Individual circuit breaker assemblies plug into the busbars. Voltage outputs to loads are carried through cables from each unit.

CIRCUIT BREAKER TAGGED IN THE OFF POSITION

CIRCUIT BREAKER

CIRCUIT BREAKER UNIT FRONT PANEL The individual high-current breaker panels contain a “starter,” in addition to a breaker. The starter is a set of high-current–capacity contacts, capable of withstanding multiple ON/OFF cycles without significant degradation. The starter contacts may be remotely or locally controlled. The individual circuit breaker panels also contain an overload sensor which opens the starter contacts to prevent overload conditions from damaging connected equipment. The overload sensor opens the starter at approximately 80% of the circuit breaker trip point, to avoid opening the circuit breaker except under the most severe overloads. Selection of remote or local starter control is provided through the HAND-OFF-AUTO control switch (2) on the typical panel above. Lamp (3) is red and is on when the starter is closed. Lamp (4) is green and is on when the starter is open or off. These lamps have built-in pushbuttons for lamp test. Pressing pushbutton (5) resets the starter after a circuit overload has been corrected.

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CIRCUIT BREAKER UNIT SCHEMATIC CIRCUIT BREAKER UNIT SCHEMATIC The schematic above illustrates a typical circuit breaker unit controlling a 7.5-hp motor with an enclosed heater. The heater prevents moisture condensation in the motor when it is not operating. Three-phase power is applied through 30-A breaker (1). A coil (8), when energized, closes the starter contacts (2). HAND-OFF-AUTO switch (10) receives 120-VAC through the transformer (5) when the circuit breaker (1) is closed. In the OFF position, the HAND-OFF-AUTO switch prevents energizing coil (8). In the HAND position, the coil (8) is energized, closing starter contacts (2) and energizing the load (4) through overload contacts (3). In the AUTO position, the coil (8) is energized through remote contacts (11). The load motor heater is energized through normally closed contacts (6) when the circuit breaker (1) is closed. When coil (8) energizes, closing the starter (2), contacts (6) transfer, opening the heater circuit. Should any one of the 3-phase overload contacts (3) open, overload contacts (9) are also opened to deenergize the starter coil (8). The overload contacts are reset by a front panel pushbutton. Fuses F1, F2, F3, and F4 protect the transformer and internal components.

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SECTION 5 TURBINE CONTROL SYSTEM

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ELECTRONIC CONTROL SYSTEM The GTG set is operated through use of an electronic-control system. This system comprises computerized-control subsystems. The sequencer is installed in the TCP and the fuel supply manager is installed in the MTTB. The microprocessors and digital logic circuitry in these subsystems provide the speed and autonomy of operation required for safe, efficient operational control. Two major system components are as follows: • • • • • • • • • • •

Woodward Atlas microprocessor based digital fuel controller FANUC 90/70 PLC Sequencer. Bently Nevada 3500 Digital vibration monitor M-3425 digital multi-function generator protective relay system Digital auto/manual voltage regulator Auto and manual synchronization Multi-function digital meter for electrical power values Human-Machine Interface that provides graphic “screens” Operator control switches and push buttons Serial output and Ethernet data port for customer's DCS Parallel printer port

The turbine-generator control system detects turbine engine and generator parameters; responds to operator directions; and performs fuel management, startup, shutdown sequencing, and electric power generator synchronization. The unit also senses unsafe conditions, generates operator alarms, and shuts down the engine when necessary to avoid danger to personnel or equipment. Starting and stopping the gas turbine engine or changing its modes of operation must be accomplished in a sequence that considers engine reliability and personnel safety. Prior to startup, ventilation fans and lube oil pumps must be in operation, engine and starting subsystem status must be verified, and operator mode selections and start authorization must be given. After startup has been initiated, fuel system initialization must precede ignition and warm-up intervals must be satisfied before the engine is permitted to accelerate. Synchronism to the electric utility feed bus must then be established and the generator output circuit breaker closed. These sequential operations are all controlled by the turbine-generator control system. The Atlas control system implements Woodward’s real time operating system. The control is based on a 5 millisecond interrupt (the Minor Frame Timer or MFT). The operating system schedules application tasks and control algorithms at the beginning of each MFT. In the application program each part or function of the application is executed in a scheduled multiple of the MFT called a rate group, or RG. In this manner, all tasks or control functions are implemented exactly at a scheduled time, which allows for accurate and consistent control dynamics. The tool used to develop this program is the Graphical Application Program (GAP). GAP is a Woodward developed Windows based program that uses standard blocks to develop an application.

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PLTG Kaji Power Station

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LM2000 50HZ GENERATOR PACKAGE 1.

BASIC OPERATORS COURSE

Sequencer The sequencer controls the order and timing of critical events in the operation of the GTG set. It issues operating commands to the control subsystems in response to data received from the sensors and detectors in the equipment and GTG subsystems. The GE Fanuc manuals located in Vol. 1 - Chapter 5 of the O&M manuals, provides detailed descriptions and diagrams.

2.

Fuel Supply Manager The fuel manager controls the operation of the turbine fuel systems. The purpose of the fuel manager is to maintain a constant generator output frequency. The fuel manager achieves this goal by regulating fuel flow to hold generator speed at a constant 3000 or 3600 rpm under all load conditions, including no-load, full-load, and load-fluctuating operation. The fuel manager also: • manages the matching of generator output frequency to the frequency of utility power for automatic synchronization and paralleling; •

controls the acceleration and deceleration of the gas turbine engine by varying the fuel flow; and

•

initiates, regulates, and terminates fuel flows into the gas turbine engine.

The Atlas manual located in Vol. 1 - Chapter 5 of the O&M manual set provides detailed descriptions of the fuel control system. System Integration GE AEP’s One-Line Diagram, 020020-01-683031, shows how these components relate to the control subsystems to achieve overall operational control. The data forwarded by subsystem transmitters, indicators, and sensors enable the sequencer and fuel manager to perform the critical events required for startups, shutdowns, and normal operation. System Responses The TCP cubicles have the switches and keypads required for issuing operator commands to the electronic-control system. As the system executes the commands in a preprogrammed order, indicator lamps, gauges, and meters on the TCP and the program screens on the DCS monitor (display operational responses and statuses.

5-4

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Turbine Control Panel The TCP contains meters, indicators, switches, and various control systems connected with the GTG set. An operator can initiate the turbine-generator’s electronic control system to perform automatic startup, fuel management, load assumption, and system operation from the TCP. Critical parameters are constantly monitored and alarms or shutdowns are initiated automatically, as appropriate, for out-of-tolerance conditions. Automatic fuel control and turbine sequencing are controlled by the logic control system software and hardware. Also, an operator or anyone on site can initiate, as necessary, a manual emergency shutdown at any time. Each cubicle is briefly described as follows: Control Cubicle— This cubicle contains the voltage regulator and switches for controlling generator operating conditions. This cubicle contains controls and monitors for turbine operation, and the Beckwith Integrated Generator Protection System (IGPS) for monitoring the operation of the turbine engine and generator. Termination Cubicle— This cubicle contains the vibration monitoring system panel and the fire protection panel. This cubicle provides the wiring interface between the TCP cubicles, and provides for connection to the operating and monitoring circuits in the turbine-generator unit. Also contained in this cubicle are the fuse blocks and circuit breakers for the control and fire systems. Turbine-Generator Control Panel (TCP) Item

Control/Indicator

Function

1

Control Cubicle

Contains switches for controlling generator electrical conditions and output and for synchronizing the generator and bus prior to placing the generator on-line with the utility or plant bus. Includes Brush automatic voltage regulator (Prismic-AVR) rack and controls the Beckwith Integrated Generator Protection System (IGPS).

2

Termination Cubicle

Contains generator protection system, the vibration monitoring system, and the fire suppression and gas detection system. Contains all termination points from the control cubicle to the equipment and systems external to the TCP.

2262533TR

PLTG Kaji Power Station

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Turbine-Generator Control Panel (TCP)

5-6

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle Item

Control/Indicator

Function

1

Horn

Produces an audible sound to alert operators when alarms or shutdown conditions occur.

2

Meter, Digital Multifunction

Micro-based unit that simplifies the monitoring and management of generator electrical conditions and output. In addition to displaying generator output conditions, control and alarm relays are programmed to activate alarms for measured output values, i.e. high or low current and voltage conditions. The three-page display consists of eleven windows per page. All the windows on pages 1 and 2 are active. The Active Energy window is the only active window on page 3. The UP ARROW/RESET MAX. has 2 functions. When pressed for at least 5 seconds, this button resets both Maximum Ampere Demand and kW Maximum Demand values to zero. This button is also used to scroll forward when choosing parameters and values. Press the DOWN ARROW/PAGING button the keypad to scroll from page to page. The selected page will disappear after 30 seconds. The select button is used to enter the Definition Mode, change parameters, select relay and set point delay. When the Reset Energy button is pressed continuously for more than 5 seconds Energy kWH, Returned Energy kWH, and Reactive Energy kVARH are reset at zero. This button will also return you to a higher programming level.

3

Lamp, Synchronizing

Illuminate at maximum intensity when the generator and utility bus are out-of-phase and reach minimum intensity when the generator and utility bus are in-phase.

4

Meter, Synchroscope

Meter indication pointer rotates through 360 degrees to display generator and utility bus phase differential. At the 12 o’clock position, the generator and utility bus are in-phase.

5

Switch, Synchronize

Selects automatic or manual synchronization mode. In manual position, operator must operate engine speed and voltage regulator controls to match frequency and voltage required for synchronization. In automatic position, frequency and voltage are adjusted by the digital synchronization module.

6

Ammeter, Null Balance

Displays difference between automatic and manual regulator output signals for controlling generator excitation current. When meter indicates zero, transfer between automatic and manual regulator control can be executed without a transient in the generator output.

7

Relay, Lockout (Generator)

Two-position switch. Allows manual operation of the 86G relay.

2262533TR

PLTG Kaji Power Station

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle

5-8

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle (Cont) Item

Control/Indicator

Function

8

Switch, Circuit Breaker Control “52G”

Allows operator to open or close the generator output circuit breaker 52G.

9

PF/VAR Adjust Switch

Allows operators to raise or lower the power factor operational set- point.

10

PF/VAR Control Enable Switch

Allows operators to select power factor or VAR regulation control modes.

11

Manual Voltage Adjust Switch

Allows operators to raise or lower the operational setpoint when the voltage regulator is operating in the manual mode.

12

Excitation Mode Switch

Three-position selector switch with spring-loaded return to Norm position. Switches generator excitation control between automatic (Auto) and manual (Man) modes.

13

Automatic Voltage Adjust Switch Allows operators to raise or lower the operational setpoint when the voltage regulator is operating in the automatic mode.

14

Automatic / Manual Voltage Regulator

Housing for the microprocessor automatic voltage regulator (Prismic-AVR) components.

15

Monitor Module

Contains the monitor microprocessor, its software, and the hardware interfaces. The monitor program resides in ROM and the project specific monitor settings are programmed into battery backed-up RAM using the hand held terminal. This module measures generator line voltage and current and includes the following functions: voltage monitoring, excitation monitoring, and event recorder.

16

Main Control Module

Contains the control microprocessor, its software, and its associated hardware interfaces. The control program resides in read only memory (ROM) and the control settings, which are specific to each unit, are programmed into battery backed-up random access memory (RAM) using a hand held terminal. These settings are made during factory testing and checked during commissioning.

17

Utilities Module

Provides separate regulated power supplies (derived from the permanent magnet pilot exciter) for the Main Control and Monitor Modules and the hand held terminal. It also provides generator diode failure circuitry, which is functional in main or standby control. The voltage sensing transformers for the main control module are also located on this module.

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PLTG Kaji Power Station

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle

5-10

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle (Cont) Item

Control/Indicator

Function

18

Standby Control Module

Provides a completely independent means of controlling excitation. The standby excitation system can be selected to function as an automatic voltage regulator requiring the minimum of adjustments or, if preferred, as a conventional manual regulator providing a wide range of exciter field control. As with the main control channel, control is provided by a single phase full wave, half controlled rectifier bridge for the AVR.

19

LED Indicators

Detect electrical activity on the Standby, Utilities, Main Control, and Monitor Modules. All indicators are on a hinged panel.

20

Power Switch

Delivers power to the auto channel supply.

21

Blower

Circulates air through the control cubicle.

2262533TR

PLTG Kaji Power Station

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle

5-12

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle Item

Control/Indicator

Function

1

System Emergency Stop “TCP” Switch

Red mushroomhead switch. Operates to initiate emergency shutdown of the GTG set.

2

Switch, Local/Remote Selector

Two-position selector switch: Local – System is controlled from TCP. Remote – System is controlled from customer Digital Control System (DCS).

3

Switch, Speed Adjust

Three-position selector switch that is spring-loaded to return to the Norm position. Used to Lower or Raise speed adjustment signals to the turbine control system.

4

Integrated Generator ® Protection System (IPS )

® The integrated protection system (IPS ) for generators is a microprocessor-based digital relay system that provides protection, control, and monitoring of the generator. The operator can develop ® or modify relay functions via a personal computer and the IPScom software. Additional information is found in the Beckwith M-3425 Instruction Book in Chapter 5 of this manual.

5

COM1 Serial Interface

Standard 9-pin RS-232C DTE configured communication port that normally will be used for local setting and interrogating of the ® M-3425 via a portable computer running IPScom software.

6

Relay OK LED and Time Sync LED

The green Relay OK LED is under control of the M-3425. A flashing OK LED indicated proper program cycling. The LED can also be programmed to be continuously lit. The green Time Sync LED will light to indicate that the IRIQ B time signal is received and validated.

7

Breaker Closed LED and Oscillograph Recorded LED

The red Breaker Closed LED will light to indicate when the breaker status input (52B) is open. The red Oscillograph Recorded LED will light to indicate that oscillograph data has been recorded in the unit’s memory.

8

Target LED

Diagnostic LED that flashes an error code number (if any).

9

Power Supply #1 & #2 LED The Green Power LED indicator will remain lit for the appropriate power supply whenever power is applied to the unit. A second power supply is available as an option.

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PLTG Kaji Power Station

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle

5-14

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Control Cubicle (Cont) Item

Control/Indicator

Function

10

Target Reset

Pushbutton used to reset target readings.

11, 12, 14, 15

M-3931 Man-Machine Interface (MMI) Module

Provides the means to interrogate the M-3425 and to input settings, access data, etc. directly from the front panel. Components include the (11) Liquid Crystal Display (LCD), (12) arrow pushbuttons, and (14 & 15) Exit and Enter pushbuttons.

13

Target Module

Contains 24 individually labeled Target Light Emitting Diodes (LEDs) to target the operation of the M-3425 functions on the front panel. Normally, the Target LEDs are not lit. Eight individually labeled Output LEDs will be lit as long as any module output is picked up.

16

TSB1

Bus Potential Test Switch

17

TSB2

Generator Potential Test Switch

18

TSB3

Generator Current Metering Test Switch

19

TSB4

Bus Current Protection Test Switch

20

TSB5

Generator Current Protection Test Switch

21

TSB6

Spare Test Switch

22

TSB7

Spare Test Switch

23

TSB8

Generator Lockout Relay Test Switch

2262533TR

PLTG Kaji Power Station

5-15

LM2000 50HZ GENERATOR PACKAGE 2

BASIC OPERATORS COURSE 5

4

3

6

7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 1 FAULT 2

FAULT 2 FAULT 3

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

S I L E N C E

AUX =

E S E

FAULT 2

FAULT

SET RESET

STEP

FAULT 3 FAULT 3

FAULT 3

I N H I B I T

R E S E

4

R E

HIHI ALARM HI ALARM

I N H I B I T

LO ALARM FAIL

S E

8

HEAT DETS

R

R

E

E

S

S E

E

T

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

T

SYSTEM ALARMS

FIRE

FAULT 1 FAULT 2

FAULT 3

I N H I B I T

R

T

GAS ALARMS

17

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

TERMINATION CUBICLE

1 18

20

19 35

3500/20 Rack Interface Module

3500/100 Low Voltage DC Power Supply

3500

3500/92 Comm Gateway Module

OK

OK

TX/RX

TX/RX

TM CONFIG OK R E S E T

22 23 24 25

21

3500/44M Aero DT Vibration Monitor OK

3500/40

3500

Proximito Monitor

Future Expansion

OK

TX/RX BYPASS

3500/25 Keyphasor Module

TX/RX 1

1

2

3

3

PROGRAM

4

4

RACK ADDR

OK

OK TX/RX CH 1 ALARM CH 2 ALARM CH 3 ALARM CH 4 ALARM

2

RUN

3500/32 4 Channel Relay Module

TX/RX BYPASS 1

2

26

27 28

3500/64M Dynamic Pressure Monitor

29

30

31

32

33

34

3500

3500

3500

3500

3500

3500

3500

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

BUFFER TRANSDUCERS

Future Expansion

3500

CONFIG PORT

G-29-03

Termination Cubicle

5-16

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Termination Cubicle Item

Control/Indicator

Function

1

Fire Suppression and Gas Detection System Panel

Comprised of plug-in modules that link to flame, temperature, and gas detection sensors inside the turbine and generator enclosures. Interfaces with the turbine control system to provide the necessary engine shutdown, ventilation fan on/off signals, and other operator messages. For detailed information on this system, refer to the Wilson Fire Equipment & Service Company Manual in Chapter 5 of this manual.

2–8

Spare Modules

Not used on this project.

9–11

Gas Modules (NT420)

Accept analog signals from gas detectors in the generator (Module 12) and turbine (Modules 13 and 14) enclosures. Calibrated values are displayed as a percentage of the lower explosion limit (LEL) of the gas-air mixture (represented by % LFL on modules). Display also indicates over- or underrange sensor inputs and programming information for setting alarm parameters. Each gas module contains two pushbuttons to initiate programming: Step– When step and reset pushbuttons are depressed simultaneously, displays menu items that enable operator to calibrate and set gas system alarms and shutdown limits. Set Reset – Resets module conditions after all alarms have been cleared. Each gas module also contains four alarm LEDs that illuminate red when activated: HiHi Alarm – Illuminates when gas level has reached 100% LEL. Hi Alarm – Illuminates when gas level has reached 60% LEL. Lo Alarm – Illuminates when gas level has reached 20% LEL. Fail – Illuminates when an internal diagnostic fault has occurred.

12

Alarm Module

Receives fire and gas system alarms that have been activated by the Input or Manual Pull Modules. The alarm module contains six LEDs and a Silence/Reset switch: Bell – Not used in this configuration. Horn – Illuminates and flashes when horn is activated. Strobe – Illuminates after receiving alarm signal. Fault 1 thru Fault 3 – Illuminate yellow when a malfunction occurs in the module system.

2262533TR

PLTG Kaji Power Station

5-17

LM2000 50HZ GENERATOR PACKAGE 2

BASIC OPERATORS COURSE 5

4

3

6

7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 1 FAULT 2

FAULT 2 FAULT 3

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

S I L E N C E

AUX =

E S E

FAULT 2

FAULT

SET RESET

STEP

FAULT 3 FAULT 3

FAULT 3

I N H I B I T

R E S E

4

R E

HIHI ALARM HI ALARM

I N H I B I T

LO ALARM FAIL

S E

8

HEAT DETS

R

R

E

E

S

S E

E

T

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

T

SYSTEM ALARMS

FIRE

FAULT 1 FAULT 2

FAULT 3

I N H I B I T

R

T

GAS ALARMS

17

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

TERMINATION CUBICLE

1 18

20

19 35

3500/20 Rack Interface Module

3500/100 Low Voltage DC Power Supply

3500

3500/92 Comm Gateway Module

OK

OK

TX/RX

TX/RX

TM CONFIG OK R E S E T

22 23 24 25

21

3500/44M Aero DT Vibration Monitor OK

3500/40

3500

Proximito Monitor

Future Expansion

OK

TX/RX BYPASS

3500/25 Keyphasor Module

TX/RX 1

1

OK

OK TX/RX CH 1 ALARM CH 2 ALARM CH 3 ALARM CH 4 ALARM

2 2

RUN

3

3

PROGRAM

4

4

3500/32 4 Channel Relay Module

TX/RX BYPASS 1

2

RACK ADDR

26

27 28

3500/64M Dynamic Pressure Monitor

29

30

31

32

33

34

3500

3500

3500

3500

3500

3500

3500

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

BUFFER TRANSDUCERS

Future Expansion

3500

CONFIG PORT

G-29-03

Termination Cubicle

5-18

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Termination Cubicle (Cont) Item

Control/Indicator

Function

13

Input Module

Accepts signals from temperature and optical flame detector sensors in the generator enclosure. Once activated, initiates Release and Alarm Modules. This module has three fire and three fault LEDs and a reset switch: Fire 1 thru Fire 3 – Illuminate red when receive alarm signal; trip auxiliary relay. Fault 1 thru Fault 3 – Illuminate yellow when a malfunction occurs in the module system. Two-position, momentary Reset switch: Reset – Resets module conditions after all alarms have been cleared. Center – Off.

14

Input Module

Accepts signals from three optical flame detectors located in the front of the turbine enclosure. This module contains three fire and three fault LEDs and a Reset switch: Fire 1 thru Fire 3 – Illuminate red when receive alarm signals; trips auxiliary relay. Fault 1 thru Fault 3 – Illuminate yellow when a malfunction occurs in the module system. Two-position, momentary Reset switch: Reset – Resets module conditions after all alarms have been cleared. Center – Off.

15

Release Module

Releases primary and reserve banks of CO2 gas cylinders after preset time delays (30- and 10-sec). Responds to Input or Manual Pull Module status through system bus to determine if two releases are necessary. The module has six LEDs and an Inhibit/Reset switch: Main (top of panel) – Illuminates when primary bank of CO2 gas cylinders has been released. Reserve (top of panel) – Illuminates when reserve bank of CO2 gas cylinders has been released. Main (middle of panel) – Illuminates if continuity problems are detected in the solenoid or pressure switch lines. Reserve – Illuminates if continuity problems are detected in the solenoid or pressure switch lines.

2262533TR

PLTG Kaji Power Station

5-19

LM2000 50HZ GENERATOR PACKAGE

2

BASIC OPERATORS COURSE

5

4

3

6

7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 1 FAULT 2

FAULT 1 FAULT 2

FAULT 2 FAULT 3

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

S I L E N C E

FAULT 3

I N H I B I T

R

AUX =

E S E

E S E

STEP

4

R

FAULT 2 FAULT 3 FAULT 3

E

HIHI ALARM HI ALARM

I N H I B I T

LO ALARM FAIL

S E

8

HEAT DETS

R

R

E

E

S

S E

E

T

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

T

SYSTEM ALARMS

FIRE

FAULT

SET RESET

FAULT 3

I N H I B I T

R

T

GAS ALARMS

17

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

TERMINATION CUBICLE

1 18

20

19 35

3500/20 Rack Interface Module

3500/100 Low Voltage DC Power Supply

3500

22 23 24 25

21

3500/92 Comm Gateway Module

3500/44M Aero DT Vibration Monitor

OK

OK

OK

TX/RX

TX/RX

TX/RX

TM CONFIG OK R E S E T

BYPASS

3500/25

3500/40

3500

Keyphasor Module

Proximito Monitor

Future Expansion

OK TX/RX 1

1

OK

OK TX/RX CH 1 ALARM CH 2 ALARM CH 3 ALARM CH 4 ALARM

1 2 2

RUN

3

3

PROGRAM

4

4

3500/32 4 Channel Relay Module

TX/RX BYPASS

2

RACK ADDR

26

27 28

3500/64M Dynamic Pressure Monitor

29

30

31

32

33

34

3500

3500

3500

3500

3500

3500

3500

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

BUFFER TRANSDUCERS

Future Expansion

3500

CONFIG PORT

G-29-03

Termination Cubicle

5-20

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Termination Cubicle (Cont) Item

Control/Indicator

15 (Cont)

Release Module

Function PSW (power) – Flashes when Inhibit mode is active. Abort – Not used in this configuration. Three-position, momentary Inhibit/Reset switch: Inhibit – Controls release signals to allow module tests without risk of CO2 gas activation. Operates only when panel is in normal operating mode. Center – Off. Reset – Resets module conditions after all alarms have been cleared.

16

Manual Pull Module

Responds to activation of manual pull stations and activates Alarm and Release Modules. The module has two LEDs and an Inhibit/Reset switch: Fire – Illuminates red when any manual pull switch in the turbine and generator enclosures has been activated. Fault – Illuminates yellow when internal diagnostic fault has occurred in the system. Three-position, momentary Inhibit/Reset switch: Inhibit – Controls release signals to allow module tests without risk of primary and reserve CO2 gas cylinder bank activation (Inhibit LED flashes). Testing can only be done in the normal operating mode. Center – Off. Reset – Resets module conditions after all alarms have been cleared.

17

Fault Module

Announces any malfunction in the fire and gas system. Faults displayed locally on the respective modules are transferred to this module. This module also identifies fault categories and provides the mechanism for resetting the audible fault horn. There are three LEDs and a Reset switch in this module: System – Illuminates when a fault is detected in the system. Power – Illuminates when battery supply voltage is low. Aux – Not used in this configuration. Two-position, momentary Reset switch: Reset – Resets module conditions after all alarms have been cleared. Center – Off.

2262533TR

PLTG Kaji Power Station

5-21

LM2000 50HZ GENERATOR PACKAGE 2

BASIC OPERATORS COURSE 5

4

3

6

7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 1 FAULT 2

FAULT 2 FAULT 3

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

S I L E N C E

AUX =

E S E

FAULT 2

FAULT

SET RESET

STEP

FAULT 3 FAULT 3

FAULT 3

I N H I B I T

R E S E

4

R E

HIHI ALARM HI ALARM

I N H I B I T

LO ALARM FAIL

S E

8

HEAT DETS

R

R

E

E

S

S E

E

T

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

T

SYSTEM ALARMS

FIRE

FAULT 1 FAULT 2

FAULT 3

I N H I B I T

R

T

GAS ALARMS

17

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

TERMINATION CUBICLE

1 18

20

19 35

3500/20 Rack Interface Module

3500/100 Low Voltage DC Power Supply

3500

3500/92 Comm Gateway Module

OK

OK

TX/RX

TX/RX

TM CONFIG OK R E S E T

22 23 24 25

21

3500/44M Aero DT Vibration Monitor OK

3500/40

3500

Proximito Monitor

Future Expansion

OK

TX/RX BYPASS

3500/25 Keyphasor Module

TX/RX 1

1

OK

OK TX/RX CH 1 ALARM CH 2 ALARM CH 3 ALARM CH 4 ALARM

2 2

RUN

3

3

PROGRAM

4

4

3500/32 4 Channel Relay Module

TX/RX BYPASS 1

2

RACK ADDR

26

27 28

3500/64M Dynamic Pressure Monitor

29

30

31

32

33

34

3500

3500

3500

3500

3500

3500

3500

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

BUFFER TRANSDUCERS

Future Expansion

3500

CONFIG PORT

G-29-03

Termination Cubicle

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Termination Cubicle (Cont) Item

Control/Indicator

Function

18

Vibration Monitoring System (Bently Nevada)

Monitors the turbine engine vibration levels at the compressor rear frame (CRF), turbine rear frame (TRF), and the generator vibration at drive and exciter ends. For detailed information on this system, refer to the Bently Nevada Manual in Chapter 5 of this manual.

19

Operates under fully loaded conditions with a single power supply. Low Voltage DC Power Supply / Future Expansion When two power supplies are installed in a rack, the supply in the lower slot acts as the primary supply and the supply in the upper slot acts as the backup supply. If the primary supply fails, the backup supply will provide power to the rack without interrupting rack operation.

20

Rack Interface Module

Primary interface that supports Bently-Nevada proprietary protocol used to configure the rack and retrieve machinery information. The rack interface module provides the connections needed to support current Bently-Nevada Communications Processors and Dynamic Data Interface External.

21

Communications Gateway Module

Provides serial communications between the 3500 Monitor System and a plant information system such as a distributed control system (DCS) or a programmable logic controller (PLC). Collects data from the modules in the rack over a high-speed internal network and sends this data to the information system upon request. The module is able to establish communications with up to six hosts over Ethernet.

22

Aero GT Vibration Monitor

4-channel monitor that accepts input from four Velocity Transducers and uses these inputs to drive alarms. The monitor can be programmed using the 3500 Rack Configuration Software to execute any filter options.

23

Keyphasor Module

2-channel module used to provide Keyphasor signals to the monitor modules. The module receives input signals from proximity probes or magnetic pickups and converts the signals to digital Keyphasor signals that indicate when the Keyphasor mark on the shaft is under the Keyphasor Probe. A Keyphasor signal is a digital timing signal that is used by monitor modules and external diagnostic equipment to measure vector parameters like 1x amplitude and phase.

24

Proximitor Monitor

4-channel module that accepts input from proximity transducers, linear variable differential transformers (DC & AC LVDTs), and rotary potentiometers and uses this input to drive alarms. It is programmed by using the 3500 Rack Configuration Software to perform any of the following functions: Thrust Position, Differential Expansion, Ramp Differential Expansion, Complementary Input Differential Expansion, Case Expansion, and Valve Position.

25

Future Expansion

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4

3

6

7

8

9

GEN.

10

11

12

13

GAS & FIRE

GEN. OPTICALS

TURBINE OPTICALS

AGENT RELEASE

AGENT RELEASE

BLOCK VALVE

ALARM MODULE

INPUT MODULE

INPUT MODULE

RELEASE MODULE

MANUAL PULL

FAULT MODULE

TURBINE

GAS MODULE

GAS MODULE

NT420 % LFL

NT420 % LFL

GAS MODULE NT420 % LFL

SET RESET

STEP

SET RESET

STEP

SET RESET

HORN

FIRE 1

FIRE 1

FIRE 2

FIRE 2

STROBE

FIRE 3

FIRE 3

FAULT 1 FAULT 2

FAULT 2 FAULT 3

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

HIHI ALARM HI ALARM

LO ALARM

LO ALARM

LO ALARM

FAIL

FAIL

FAIL

S I L E N C E

AUX =

E S E

FAULT 2

FAULT

SET RESET

STEP

FAULT 3 FAULT 3

FAULT 3

I N H I B I T

R E S E

4

R E

HIHI ALARM HI ALARM

I N H I B I T

LO ALARM FAIL

S E

8

HEAT DETS

R

R

E

E

S

S E

E

T

T

T

TURBINE PRESSURE MANUAL VOTING SWITCH PULL

SYSTEM FAULTS

T

SYSTEM ALARMS

FIRE

FAULT 1 FAULT 2

FAULT 3

I N H I B I T

R

T

GAS ALARMS

17

NT420 % LFL

BELL

FAULT 1 STEP

15 16

14

TERMINATION CUBICLE

1 18

20

19 35

3500/20 Rack Interface Module

3500/100 Low Voltage DC Power Supply

3500

3500/92 Comm Gateway Module

OK

OK

TX/RX

TX/RX

TM CONFIG OK R E S E T

22 23 24 25

21

3500/44M Aero DT Vibration Monitor OK

3500/40

3500

Proximito Monitor

Future Expansion

OK

TX/RX BYPASS

3500/25 Keyphasor Module

TX/RX 1

1

OK

OK TX/RX CH 1 ALARM CH 2 ALARM CH 3 ALARM CH 4 ALARM

2 2

RUN

3

3

PROGRAM

4

4

3500/32 4 Channel Relay Module

TX/RX BYPASS 1

2

RACK ADDR

26

27 28

3500/64M Dynamic Pressure Monitor

29

30

31

32

33

34

3500

3500

3500

3500

3500

3500

3500

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

Future Expansion

BUFFER TRANSDUCERS

Future Expansion

3500

CONFIG PORT

G-29-03

Termination Cubicle

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Termination Cubicle (Cont) Item

Control/Indicator

Function

26

4 Channel Relay Module

Contains four relay outputs. Each relay output is fully programmable using AND and OR voting. The Alarm Drive Logic for each relay channel can use alarming inputs (alerts and dangers) from any monitor channel in the rack. The Alarm Drive Logic is programmed using the Rack Configuration Software.

27

Dynamic Pressure Monitor Single slot, 4- channel monitor that accepts input from various high temperature pressure transducers and uses this input to drive alarms. The monitor has one proportional value per channel, bandpass dynamic pressure. The bandpass corner frequencies are configured using the 3500 Rack Configuration Software along with an additional notch filter.

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AtlasPC Control System

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ATLAS PC PLATFORM (FUEL CONTROL) Overview At the heart of the small and powerful Woodwared AtlasPC Platform is a 32-bit microprocessor. The platform is based on the industry standard PC/104 bus structure. The SmartCore board is the back plane of the system. The platform can be expanded with a total of 5 PC/104 modules such as the AtlasPC Analog Combo board. Each PC/104 based board on the platform has a unique address set by an onboard DIP switch. A Woodward proprietary "Power Bus" provides power from the AtlasPC Power Supply board to all the other boards and modules, which, in some cases may use this to power their own, isolated power supplies. The "Power Bus" also acts as a data bus for the non-PC/104 based power supply, relay, and actuator boards. Based on the power requirements of the AtlasPC system, the package may include a fan. The AtlasPC platform implements Woodward's real time operating system, based on a 5 millisecond interrupt (the Minor Frame Timer or MFT). The operating system schedules application tasks and control algorithms at the beginning of each MFT. The tool used to develop the application program is the Graphical Application Program (GAP). GAP is a Woodward developed Windows based program that uses standard blocks to develop an application. 2262533TR

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ATLAS PC POWER SUPPLIES

General Description The AtlasPC power supply contains the power supply and twelve discrete output driver channels. The discrete outputs are low-side drivers having short circuit and thermal shutdown protection. The discrete output drivers are not isolated from each other, and are powered by an external +24 Vdc. They are isolated from the internal power supplies of the AtlasPC Control platform. Input power connections are made to the power supply through terminals on the front of the power supply.

XXX143 Excerpt for the Power Supply Module

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Specifications Power Supply Input (Power Supply Board) Range Input Current

18-32 Vdc 2.7 A @ 24 Vdc 3.61A@18Vdc

Input Wiring Constraints

The AtlasPC control platform shall be wired such that no other device receives power from the wiring between the AtlasPC Control Platform and the power supply source.

Power Supply Module Discrete Output Drivers (Power Supply Board) Number of channels

12

Type

Low-side driver with short circuit and overvoltage protection

Current drive rating

200 mA

Discrete Output Supply Voltage

9-32 V

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ATLAS PC SMARTCORE BOARD WITH ACTUATORS General Description This board includes no potentiometers and requires no calibration. A SmartCore board may be replaced with another board of the same part number without any adjustment. Each SmartCore board contains circuitry for: • Two speed sensor inputs o Each speed sensor input is from a magnetic pick-up • Six analog inputs, six analog outputs o Analog input may be 4-20 mA or 0-5 V • Two (2) proportional actuator drivers • Three (3) serial ports o Two of the serial ports, may be RS-232, RS-422, or RS-485. The other serial port is a dedicated RS-232 port • Twenty four (24) discrete inputs.

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Speed Sensor Inputs The Magnetic Pick Up (MPU) inputs are read and the speed is provided to the application program. The speed sensor inputs are filtered by the SmartCore board, and the filter time constant is selectable at 8 milliseconds or 16 milliseconds. The SmartCore board uses speed sensing probes mounted on the accessory gearbox (NGG, N1) and the turbine rear frame (NPT, N2).

MPU Interface to Smartcore Configuration: • Refer to figures above for speed sensor wiring. • Each speed input channel can only accept one MPU. ANALOG INPUTS The analog inputs may be current or voltage type. If a current input is used, a jumper is installed on the terminal block, and the software must be selected for current. This allows the SmartCore card to use the applicable hardware calibration values. If a voltage input is needed, the jumper must be removed, and the software must be selected for voltage. See Figure below for jumper locations. All Analog inputs may be used with two-wire ungrounded (*loop powered) transducers or isolated (self-powered) transducers. For a 4-20 mA input signal, the SmartCore board uses a 200 S2 resistor across the input.

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Configuration Notes •

Refer to Figures above for analog input wiring.

•

A11 4-20 mA inputs have an input impedance of 200 ohms.

•

When a 4-20 mA input is used, a terminal block jumper must be installed, per above Figure.

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• The application software must be configured for a 4-20 mA type input, or a 0-5 V type input. •

Loop power is NOT provided by the Atlas control, it must be sourced externally.

ANALOG OUTPUTS The analog outputs are 4-20 mA with a full scale range of 0-24 mA. The SmartCore board has four analog outputs.

Configuration Notes •

Refer to Figure above for analog output wiring.

•

Only 4-20 mA signals are output.

•

The output does not contain fault detection. If it is necessary to detect failures, then the device that is driven by the Analog output, for example an actuator driver, must contain reference failure detection.

•

The analog outputs have a 15 V common mode voltage, with respect to AtlasPC control common.

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Actuator Outputs The proportional actuator driver outputs are 4-20 mA or 20-160 mA with a full scale range of 0-24 mA or 0-200 mA. The SmartCore board has two proportional actuator driver outputs, each output with source and return current readbacks.

Configuration Notes •

Refer to Figure above for actuator output wiring.

•

4-20 mA or 20-160 mA signals are output.

•

Application software selects the actuator type, the output range, and the dither amount.

•

The readbacks can be used in the application software for fault detection.

Discrete Inputs The SmartCore board accepts 16 discrete inputs. Contact wetting voltage may be supplied by the SmartCore card. Optionally, an external 18-28 Vdc power source can be used to source the circuit wetting voltage.

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Smartcore Board Fault Detection Board Hardware Each SmartCore board has a red fault LED that is turned on when the system is reset. During initialization of a board, which occurs after every CPU reset, the CPU turns the Fault LED on. The CPU then tests the board using diagnostic routines built into the software. If the diagnostic test is not passed, the LED remains on or blinks. If the test is successful, the LED goes off. If the fault LED on a board is illuminated after the diagnostics and initialization have been completed, the SmartCore board may be faulty or may have the address DIP switches configured incorrectly. The DIP switch setting must match the module address set in the GAP application program. Number of LED Flashes Failure 1

Microprocessor failure

2

Bus, address, any unexpected exception error

3

Failure during RAM test

4

Local watchdog timeout

5

Failure during EE test

6

Failure during FLASH programming or erasing

7

Kernel software watchdog count error

10

Failure during 68302 test

11

Failure during RTC test

Fault Detection (I/O) In addition to detecting board hardware faults, the application program may detect I/O faults. • Analog Input Faults-The application software may set a high and low latch set point to detect input faults. •

Speed Sensor Input Faults-The application software may set a high and low latch set point to detect input faults.

•

Serial Port Faults-The system monitors the serial communications on the three serial ports, for various communication errors.

•

Microcontroller Faults-The system monitors a software watchdog, a hardware watchdog, and a software watchdog on the PC 104 bus communications. All outputs are shutdown in the event of a microcontroller fault.

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XXX143 Excerpt for Smartcore Board Analog Input

XXX143 Excerpt for Smartcore Board Discrete Input

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ATLAS PC ANALOG COMBO BOARD Description The AtlasPC Analog Combo board connects to the CPU board through the PC104 bus. It does not connect to the AtlasPC power bus directly, it requires a SmartCore board. Each Analog Combo board contains circuitry for: •

Two (2) speed sensor inputs

•

Fifteen (15) analog inputs o The first eleven analog inputs may be 4-20 mA inputs or thermocouple inputs, and the remaining four analog inputs may be 4-20 mA inputs or RTD inputs.

•

One (1) cold junction

•

Two (2) Analog outputs.

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Features •

On-board processor for automatic calibration of the I/O channels

•

First 11 analog inputs are software configurable 4-20 mA or thermocouple

•

Last 4 analog inputs are software configurable 4-20 mA or RTD

•

First 11 analog inputs are isolated as a group, from the other inputs, and from control common

•

Last 4 analog inputs are isolated as a group, from the other inputs, and from control common

•

A cold junction measurement is provided on the board

Speed Sensor Inputs The MPU inputs are read and the speed is provided to the application program. A derivative output is also provided. The speed sensor inputs are filtered by the Analog Combo board, and the filter time constant is selectable at 8 milliseconds or 16 milliseconds. The Analog Combo board uses speed sensing probes mounted on the accessory gearbox (NGG, N1) and the turbine rear frame (NPT, N2). Any of the board's speed channels accept passive magnetic pickup units (MPUs).

Analog Inputs The Analog inputs may be current, or temperature inputs. The first 11 inputs can be thermocouple inputs, and the other 4 inputs can be RTD inputs. The software must be configured for the correct input type. This allows the Analog Combo card to use the applicable hardware calibration values, and to configure the appropriate hardware gains. The first 10 inputs must be configured in pairs, that is, channels 1 and 2 must both be thermocouples or must both be 4-20 mA inputs. Channels 11-15 may be configured individually. The RTD source current is 2 mA, and the RTD sense input should be tied to the negative side of the RTD, at the RTD. The cold junction sensor is provided on the AtlasPC Analog Combo board. If the actual cold junction in the field wiring occurs elsewhere, the temperature of that junction must be brought into the control as a thermocouple, RTD, or 4-20 mA input, and the application software must be configured to use the appropriate cold junction temperature. 5-40

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The first 11 analog inputs are isolated as a group from control common, earth ground, and the other 4 analog inputs. The last 4 analog inputs are also isolated as a group from control common, earth ground, and the first 11 analog inputs. For a 4-20 mA input signal, the Analog Combo board uses a 100 S2 resistor across the input. AtlasPC Analog Combo board Fault Detection Board Hardware Each Analog Combo board has a red fault LED that is turned on when the system is reset. During initialization of a board, which occurs after every CPU reset, the CPU turns the Fault LED on. The CPU then tests the board using diagnostic routines built into the software. If the diagnostic test is not passed, the LED remains on or blinks. If the test is successful, the LED goes off. If the fault LED on a board is illuminated after the diagnostics and initialization have been completed, the Analog Combo board may be faulty or may have the address DIP switches configured incorrectly. The DIP switch setting must match the module address set in the GAP application program. Number of LED Flashes

Failure

1

Microprocessor failure

2

Bus, address, any unexpected exception error

5

Failure during EE test or erasing

7

Kernel software Watchdog count error

12

Failure during CPU Internal RAM test

13

Dual port RAM error

Detection (I/O) In addition to detecting board hardware faults, the application program may detect I/O faults. •

Analog Input Faults-The application software may set a high and low latch set point to detect input faults. For thermocouple inputs, open wire detection is provided.

•

Speed Sensor Input Faults-The application software may set a high and low latch set point to detect input faults.

•

Microcontroller Faults-The system monitors a software watchdog, a hardware watchdog, and a software watchdog on the PC 104 bus communications. All outputs are shutdown in the event of a microcontroller fault.

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XXX143 Excerpt for Analog Combo Board #1 (Analog I/O)

XXX143 Excerpt for Analog Combo Board #2 (Analog I/O)

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PC104 DeviceNet Interface DeviceNet protocol uses CAN (Controller Area Network).

DeviceNet Module The DeviceNet hardware module used on the AtlasPC control system is a PC/104 board, equipped with one DeviceNet port capable of handling DeviceNet protocol. This module operates on the PC 104 bus and has a PC 104 pass-through connector to allow use with other PC 104 modules depending on the Atlas configuration. Network Wiring CAN networks are multi-drop networks arranged with two physical ends and up to 64 nodes connected between the ends. Many limitations work together to define the total end-to-end length of the network. This section will help define those. Shielding Shielded cable must be used between the AtlasPC control and any other devices. Unshielded cables and improperly shielded cables will very likely lead to communication problems and unreliable control operation.

24 Volt Power Supply The DeviceNet network is different from many others in that a 24 Vdc power supply is distributed with the network. The AtIasPC system does not provide this supply, and all customers using DeviceNet will have to provide a separate and isolated supply to ensure proper network operation.

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XXX143 Excerpt for Device Net, Address 2

XXX143 Excerpt for Device Net, Address 6

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FANUC 90/70 Sequencer The series 90 – 70 Programmable Logic Controller (PLC) provides full function controller that is easy to configure, offers advanced programming features, and is designed for compatibility with other PLC’s in the series 90 family.

FANUC 90/70 SEQUENCER Sequencer G.E. Fanuc 90-70 PLC with rack mounted I/O and Field Control I/O. Provides monitoring and/or automatic control of: -Turbine Ventilation System. -Turbine Fuel Distribution System. -Turbine Lubrication System. -Turbine Starting System. -Turbine Washing System. -Turbine Sequence. -Generator Ventilation System. 2262533TR

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-Generator Lubrication System. -Generator Output. -Fire System. -Vibration System. Provides System Data for communications link to: -Atlas PC Fuel Control -Remote HMI. -Customer BOP Control System. Basic Theory of a Programmable Logic Controller A PLC is a device that is designed to perform logic functions. A PLC is similar to a computer; it is an assembly of digital logic elements that are designed to make logical decisions based on input status compared to a user program. These logic decision are used to provide output to field devices. A basic PLC is divided into three parts. The first is the CPU (Central Processing Unit). The CPU is the brain of the PLC. The second part is the Input/Output Section. It is designed to communicate signals to and from field devices. The third part is the Programming device. This allows the user to tell the PLC how to react to input signals. PLC’s are designed to be programmed by a method that most engineers are familiar with. This method is based on Relay Logic and is called Ladder Logic. Example: Monitoring enclosure air temperature • An input signal (I/O) from the enclosure temperature sensor is continuously updated to the CPU through the genius bus. • A cycle (scan) is where the CPU steps through all line of the ladder logic and compares the appropriate input (I/O) data to each corresponding line in the ladder logic. • The CPU compares the temperature sensor I/O input to a value the user has previously programmed into memory (250º F.) on the related line of the ladder logic. • If the input from the sensor is greater than or equal to 250º F this triggers the CPU to perform a function. In this example, the CPU would then send an output signal to a relay terminal to start the standby cooling fan.

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Typical 90/70 Chassis with 3 Mounted Fans

Typical FANUC 90/70 Rack Layout

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The 90-watt Power supply module is a rack-mounted unit that plugs into a 48pin back plane, mounted in the leftmost slot in the rack. • 3 output voltages, 90 watt total o +5 VDC output to 18 amps. o +12 VDC output up to 1.5 amps. o –12 VDC output up to 1 amp. • Electronic short circuit overcurrent protection provided on 5-volt bus. The power supply output will ride through a 10msec total loss of input power at full load.

Central Processor Unit

A single slot programmable controller CPU that allows floating point calculations. The unit is programmed and configured by MS-DOS or windows programming software to perform real time control of machines, processes and material handling system. The unit communicates with I/O and modules over the rack-mounted backplane by the way of VME standard format. A memory board with 512 Kbytes of battery-backed CMOS RAM provides program and data memory.

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Ethernet interface providing high-speed communication for the 90/70 CPU. The Ethernet interface plugs into a single slot in the rack. Three Ethernet interface Cards are installed in this application. • Data Highway • Customer DCS and HMI • Atlas PC Fuel Control Each Ethernet interface contains three types of network ports. Only one network port may be used at a time. • 10Base-T (like high speed internet cable) • 10Base-2 (Co-axial Cable) • AUI Connector (Like a printer cable)

Genius I/O Bus Controller Modules This module utilizes I/O data via the genius bus. The bus controller occupies a single VME rack slot. • 30 drops per channel The bus controller scans I/O Versamax blocks asynchronously1 and then the I/O data is transferred to the CPU once per scan over the backplane of the VME rack. During the scan, once per sweep the bus controller: • Makes available to the CPU all discrete inputs and analog inputs •

1

Receives current outputs and new commands from the CPU.

Operating at a speed determined by the circuit function rather than by timing signals.

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RTU Master Slave Communication Module The RTU Master Salve Communication Module provides the 90/70 with a flexible communications interface to RTU/Modbus networks. This module functions as the master that allows data to be read/written to one or more slave devices. This module provides two RTU/Modbus master channels, which may be controlled by the 90/70. In this configuration the module has two slave devices: • Bentley Nevada Vibration Monitoring System • Customer DCS System

VERSAMAX DISTRIBUTIVE I/O The VersaMax Distributive I/O bus is an Controller-Area-Network (CAN). It passes I/O control data and background information between the remote VersaMax I/O sensors and a Genius bus controller mounted in the FANUC 90/70 rack. The bus utilizes the Fanuc 90/70 sequencer as the operational CPU and the bus controller. The bus controller manages data transfer between the CPU and the bus. The FANUC program utilizes data received from the bus controller, and provides any data that should be sent back to the bus. For the application in the Turbine Control Panel where communication between the controller and I/O blocks must be maintained even if a cable break should occur, a dual redundant bus is used.

VersaMax Field Unit

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Network Interface Unit (NIU) The VersaMax Genius Network Interface Unit (IC200GBI001) interfaces a VersaMax I/O Station to a Genius I/O bus. The NIU’s on the bus takes all the I/O data and transfers the information to the Genius bus controller card (located in the 90/70 chassis) through a primary and redundant secondary cable. In the event of loss of the primary cable the secondary cable will be used. • •

NIU (Network Interface Unit)

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A VersaMax power supply module mounts directly on the right hand side of the NIU. LEDs on the left hand side indicate the presence of power and show the operating mode and status of the NIU. Three rotary dials beneath a clear protective door are used to configure the NIU's address on the Genius bus and to set its communications baud rate.

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BASIC OPERATORS COURSE Power Supply 24VDC Expanded 3.3V Power Supply IC200PWR002 provides backplane power for the NIU, and I/O modules. It supplies up to: •

1.5 Amps output current via 3.3 volt

•

5 volt outputs, with up to 1.0 Amp on the 3.3 Volt output.

Additional power supplies are installed on special booster carriers for systems where the number of modules creates the need for a booster. No booster supply is needed to power conventional UO modules.

I/O Modules VersaMax I/O and option modules are approximately 110mm (4.3in) by 66.8mm (2.63in) in size. Modules can be mounted either horizontally or vertically on several types of available I/O Carriers. This application utilizes the following I/O modules: • 16 bit RTD input, 4 Channel • Analog input,16 bit voltage/current, 8 channel isolated • Analog input,16 bit voltage/current, 4 channel, 1500volt isolation • Discrete input 24vdc 16 channel • Relay Output, 2.0 amp 16 channel • Discrete output, 16 channel

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Carriers Carriers provide mounting, backplane communications, and field wiring connections for all types of VersaMax modules. I/O modules can be installed on carriers or removed without disturbing field wiring. There are three basic I/O Carrier types: •

Terminal-style UO carriers. Modules mount parallel to the DIN rail.

•

Compact Terminal-style UO Carriers. Modules mount perpendicular to the DIN rail. Connector-style I/O Carriers. Modules mount perpendicular to the DIN rail.

•

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OPERATOR SCREENS

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Screens The CRT/CPU segment of the control system allows the operator to gain insight into the operational trends of the GTG set and its ancillary equipment systems. The screens displayed by the system software show critical-operating parameters and system set points. Each screen and the information that it contains may be accessed by pressing its corresponding function, or “F,” key. The following WonderWare system screens are typical for an LM2500 unit.

Menu Screen Display

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Unit Start Permissives Screen Display

Turbine Control Overview Screen Display 5-58

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Turbine Lube Oil System Screen # 1 Display

Turbine Lube Oil System # 2 Screen Display

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Turbine Gas Fuel System Screen Display

Turbine Ventilation and Combustion Air System Screen Display

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Generator Ventilation and Combustion Air System Screen Display

Fire Protection System Screen Display

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Starter System Screen Display

Generator Lube Oil System Screen Display

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Water Wash System Screen Display

Unit Control Panel Screen Display

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Alarms and Shutdowns Screen Display

Historical Screen Display

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Vibration Monitor System Screen Display

Real Time Screen Display

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Performance Screen Display

Security Screen Display

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FUEL MANAGEMENT SYSTEM

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FUEL MANAGEMENT SYSTEM VALVE ACTUATOR INTERFACE

FUEL MANAGEMENT SYSTEM VALVE ACTUATOR INTERFACE The fuel management system senses engine and generator parameters, and regulates fuel flow into the engine under sequencing logic and operator control. Water injection to the engine is operator regulated as limited by safe operating conditions. Fuel valves are positioned by voltages applied from the fuel management system to electrohydraulic actuators. Fuel valves and flow is discussed in another section of this manual. The illustration above is a functional block diagram, illustrating the fuel valve interface with the valve actuators. The process controller (1) sends commands through transfer functional controls and digital-to-analog (D-to-A) converter (2), to position the servovalve (3). Actual valve position is transmitted back to the controller through a linear variable-differential transformer (LVDT) (4) and signal conditioner (5). After analog-to-digital (A-to-D) conversion (6), a negating error signal is presented to the process controller output closing the control loop.

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N1 SPEED

(-)

N1 SPEED REFERENCE

(+)

N2 SPEED

(-)

N2 SPEED REFERENCE

(+)

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LSS BUS

SEE START LOGIC FUEL VALVE POSITION SEE START LOGIC TEMPERATURE CONTROL

HSS BUS TO FUEL VALVE CONTROL

T 54 LIMITING o - 1520 F LIQUID FUEL o - 1545o F GAS FUEL ABSOLUTE MAX- 1550 F

N1 DECEL CONTROL

R.O.C.

SEE CDP N1 LIMITING

CDP TOPPING 281 PSIA SEE FUEL INITIALIZATION CDP LIMITING

N1 ACCEL CONTROL

R.O.C.

SEE EMERGENCY SHUTDOWN LOGIC T01395.DWG

FUEL CONTROL SYSTEM SCHEMATIC The figure above is a simplified diagram of the fuel control system scheme. The fuel valve position is driven by the output of two signal select buses, a Low Signal Select (LSS) bus and a High Signal Select (HSS) bus. The LSS bus output is the lowest of the input signal levels. The HSS bus output is the higher of its inputs. For example, if the start logic temperature control signal at the LSS is at a lower value than the CDP topping signal, it will appear at the bus output. The higher value signal will prevail at the output of the HSS bus to control the fuel valve. Typical of the inputs to the LSS bus is the N1 control signal. The N1 speed and reference signals are illustrated as inputs to an operational amplifier configured as a comparator. The comparator output will remain positive unless the N1 speed signal increases above the reference value. The N2 speed control operates identically and will control the LSS if its output is lower than the output of the N1 control signal. Absolute maximum turbine inlet temperatures have been established for fuel types, as illustrated. A maximum limit for compressor discharge pressure (CDP) has also been established, and limits have been established for N1 acceleration and N1 deceleration.

Reference signal biases and limiting functions are discussed in the following paragraphs.

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100%

TO START FUEL VALVE POSITION LSS INPUT

F U E L

V A L V E

P O S I T I O N

START ENABLE

0%

TIME

16 Sec.

T01396.DWG

RAMP SLOPE = 6% V. P. / Sec.

START LOGIC FUEL VALVE POSITION CONTROL

START LOGIC FUEL VALVE POSITION CONTROL When START is initiated by a system operator, the fuel valve opening rate is limited to avoid overfueling. Regardless of other limits, the fuel valve cannot open from0 to 100% in less than 16 seconds.

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o

1200 F

o

600 F

T5.4 o > 600 F

SET

N.C.

N.O.

LATCH

RESET

T5.4

(-)

TO START TEMP. CONTROL LSS BUS INPUT

(+)

T01397.DWG

R.O.C. LIMIT o 1 F/Sec.

START LOGIC TEMPERATURE CONTROL START LOGIC TEMPERATURE CONTROL At Turbine Inlet Temperatures (T5.4) less than or equal to 600 °F, T5.4 is allowed to increase no faster than 1 °F/sec until 600 °F is reached. At that point, the limit is raised to 1200 ° F at 1 °F/sec. Temperature rate of increase limiting increases engine life and stabilizes acceleration.

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CDP Po

C D P N1 CORRECTED (N1c) N

T

Po

I

N1

E T

P

O

T 2 + 459.9 518.9

S

(-)

D

P

(+)

TO CDP N1 LIMITING LSS BUS INPUT

C

N1c =

T2 N1c T01398.DWG

COMPRESSOR DISCHARGE PRESSURE N1 LIMITING

COMPRESSOR DISCHARGE PRESSURE N1 LIMITING Engine inlet temperature (T2), high-pressure compressor (HPC) speed (N1), and atmospheric pressure (Po) determine CDP. To avoid overfueling and subsequent compressor stall, and to improve efficiency, fuel is limited as illustrated above. HPC speed (N1) is corrected (N1c) by application of the square-root expression relating T2 and N1. A CDP set point is derived from T2 and the N1 correction factor. The set point is compared with CDP/Po to obtain a voltage value-limiting fuel.

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100%

60%

TO FUEL INITIALIZATION CDP LIMITING LSS BUS INPUT

30%

0% 78 PSIG 79 PSIG

300 PSIG

P S I G T01399.DWG

FUEL INITIALIZATION CDP LIMITING

FUEL INITIALIZATION CDP LIMITING Fuel is limited as a function of CDP to avoid overfueling as startup progresses. The valve opening is restricted to a ramp rate not exceeding 60%, until CDP is 78 psig. Between 78 and 79 psig, the limit is raised to 100%.

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0% VALVE POSITION 101% VALVE POSITION

SET N.C.

LATCH

N.O.

RESET

RESET BUS SHUTDOWN BUS T01400.DWG

TO EMERGENCY SHUTDOWN CONTROL LSS BUS INPUT

EMERGENCY SHUTDOWN CONTROL

EMERGENCY SHUTDOWN CONTROL When emergency shutdown is commanded, a latch is set forcing the fuel valve to close. Resetting the latch releases the “hold-closed” signal and allows the valve to reach 101%.

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SEQUENCE LOGIC The normal start sequence is illustrated on the following 10 pages (sheets) using Boolean logic. Sheet 1 gives the two basic requirements for startup of the gas turbine engine: (1) start permissives which must be satisfied, and (2) operator selection of an operational mode. The sequence illustrations show system requirements, status and current conditions (or Mode of Operation). The Boolean logic helps to show how the different system interrelate with one another throughout the “Normal Start” and “Normal Stop” process. Not to fear the sequence can be followed without prior understanding of the logic symbols, and by referencing the following descriptions and illustration of each logic symbol. All logic circuits may be described in terms of three fundamental elements, shown graphically in the illustration. Along with the symbols are Truth Tables which relate to the input/output signal state. All signals are interpreted to be of only two values, denoted as 0 and 1. For our purposes, the 0 will always represent a FALSE logic state, as an example where a pump or motor is not operating or has not been turned on. The 1 will represent a TRUE logic state, in this case the pump or motor is operating or has been turned on.

LOGIC SYMBOLS

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The NOT element has one input and one output; as its name suggests, the output generated is the opposite of the input in binary. In other words, a 0 (FALSE) input value causes a 1 (TRUE) to appear at the output. The AND and OR logic state are shown with only two inputs, and one output, when in fact they both can have an arbitrary amount of inputs. As you will see navigating through the sequence logic illustrations many times more than three or four inputs are required for the sequence to continue. In the AND logic state, the output becomes 1(TRUE) if and only if, all of the inputs are 1(TRUE), otherwise, the output is 0(FALSE). The third logic state, the OR element, its output is 1 (TRUE) as long as 1 or more of its inputs are 1(TRUE). The illustration also showed two other states that are possible, the NAND and NOR logic states. A NAND may be described as an AND element driving a NOT element. Similarly, a NOR is equivalent to an OR element driving a NOT element. If we compare the Truth Tables of a AND element and a NAND element we see that for the output (C), the results are opposite. The same is the case for a OR and NOR logic state.

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NORMAL START SEQUENCE

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NORMAL START SEQUENCE A 10-page logic flow diagram following this discussion illustrates a normal start sequence. At power-on, one pair of generator fans and one turbine enclosure ventilation fan are turned on. At each power-up, the opposite ventilation fans are turned on to equalize running time on the fans. If after 30 seconds turbine enclosure ventilation airflow is not detected, a Low Enclosure Differential Pressure alarm is activated, the originally energized ventilation fans are deenergized, and the opposite ventilation fans are energized. Following airflow verification, the start permissives listed on logic diagram Sheet 1 of 10 are verified. When the operator selects an operational mode, a READY TO START message is activated by the system. To begin the start sequence, the operator must activate the Start command from the turbine-control panel switch. After operator selection of start, the generator alternating-current (AC) lube oil pump is energized. Five seconds later, the AC lube oil pump pressure is verified as greater than 20 psig, and double checks are made of CUSTOMER OK TO START and Fuel Valve at Minimum position. A START SELECT message is then generated by the system, low-speed T5.4 limits and shutdowns are inhibited, and 4- and 30-second timers are started. After 4 seconds, the starter hydraulic pump motor is started and a 10-second timer is started. After the 10-second timer elapses, various hydraulic starter parameters are verified, as indicated on logic flow diagram Sheet 3. If the starter checks are unsatisfactory, a starter system alarm or shutdown is activated. After the 30-second timer elapses, which was started at the same time as the 4-second timer, generator lube oil pressures are verified. If generator lube oil pressure is less than 20 psig, an alarm is generated. If generator lube oil pressure is less than 12 psig, a shutdown occurs. Should none of the shutdown conditions occur following the 30-second timer, the starter is energized in the High-Speed Crank mode. If N1 speed is less than 1700 rpm 1 minute after the starter is energized, an Engine Failed to Crank shutdown occurs. If N1 increases above 1700 rpm before the 1-minute timer elapses, cranking is continued for a purge interval. The length of the purge time is system dependent. For boiler purge, 7.5 minutes is typical; for engine purge, only 2 minutes are necessary. Following the purge interval, the starter should be cranking the engine at approximately 2300 rpm. After the purge timer elapses, the system determines which mode has been selected by the operator. If Low-Speed Crank has been selected, the starter SOV is positioned to the Low-Speed Crank setting. If High-Speed Crank has been selected, the starter SOV will be positioned at the low-speed setting for 1 minute, after which the SOV will be positioned to the High-Speed Crank setting. Four minutes after the starter is commanded to the High-Speed Crank mode, the starter is deenergized to stop the starter, thus ending the High-Speed Crank mode. After the purge timer elapses and run mode has been selected, the starter is de-energized. When N1 speed falls to less than 1700 rpm, the starter is again energized and a 10-second timer is started. When the timer elapses, N1 speed is verified as greater than 1700 rpm. If not, an Engine 2262533TR

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Failed to Crank shutdown occurs. If N1 is greater than 1700 rpm after the 10-second timer elapses, a shutdown occurs if the fuel valve is not at minimum. If the fuel valve is at minimum position, the igniters are turned on, the downstream fuel shutoff valve is opened, the upstream fuel shutoff valve is opened, and a 20-second timer is started. If the fuel valve is not at minimum, a Fuel Valve Not at Minimum shutdown occurs. When the 20-second timer elapses, T5.4 is verified as greater than or less than 400 F. If less than 400 F, a Failed to Ignite shutdown occurs. If greater than 400 F, the engine fired starts counter is energized, engine run meters are energized, flameout shutdown on UV flame detectors is armed, the fuel management system start limiting control is activated, and a 1-minute N1 ramp timer is started. After the 1-minute timer elapses, if N1 speed is less than 5000 rpm, an N1 Failed to Accelerate shutdown occurs. If N1 accelerates to greater than 4500 rpm and the fuel governor is operating on Start or Temperature Control, or on T5.4 control, a Run signal is activated, the igniters are deenergized, the starter hydraulic pump motor is deenergized, the starter is deenergized, the generator space heaters are deenergized, and the AC generator lube oil pump is deenergized. At any time following Run, should the turbine lube oil pressure fall below 6 psig, a Turbine Lube Oil Pressure Low shutdown will occur. As N1 speed increases above 5000 rpm, a shutdown will occur should the turbine lube oil pressure fall below 12 psig. After N1 speed has reached 5000 rpm, the turbine vibration monitor is enabled, low-speed T5.4 limits and shutdowns are released in the fuel governor, and a 5-minute warm-up timer is started. After the 5-minute warm-up period, N2 speed is verified as greater than 1800 rpm. If not, an N2 Failed to Accelerate shutdown occurs. After the 5-minute warm-up timer elapses and Run mode has been selected, the N1 speed reference to the fuel governor is raised to its maximum limit to cause N2 to accelerate to a synchronous idle speed of 3598 rpm in 60-Hz power systems or 2995 rpm in 50-Hz power systems. As N2 speed reaches a Switch 1 Set Point of 2500 rpm, the fuel governor begins to operate on the N2 control reference. After 60 seconds, if N2 is not greater than 2500 rpm in 50-Hz power systems or 3000 rpm in 60-Hz power systems, an N2 Failed to Accelerate shutdown occurs. If Man synchronization mode has been selected, the operator may begin manual synchronization procedures at this point to close the generator output circuit breaker. If, however, the Auto synchronization mode has been selected, N2 will continue to accelerate to a Switch 2 Set Point of 2995 rpm in 50-Hz power systems or 3598 rpm in 60-Hz power syst3ems. After reaching the N2 Switch 2 Set Point, if the fuel governor is operating in N2 control, the automatic circuit breaker close circuit is activated and a 1-minute timer is started. If the generator output circuit breaker has not closed when the 1-minute timer elapses, a CIRCUIT BREAKER FAILED TO CLOSE operator information message is generated. As illustrated on logic flow diagram Sheet 9, the generator is protected from lube oil system failures by logic which generates a Generator Lube Oil Pump Fail alarm if lube oil pressure drops to less than 25 psig. If lube oil pressure continues to drop and falls to less than 20 psig, the AC lube oil pump is energized and an Auxiliary Lube Oil Pump On Unscheduled alarm occurs. Should the AC lube oil pump fail following the pump on unscheduled alarm, the DC lube oil pump is commanded on and an engine shutdown is initiated.

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NORMAL STOP SEQUENCE

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NORMAL STOP SEQUENCE A two-page logic flow diagram following this discussion illustrates a Normal Stop Sequence. A Normal Stop Sequence is initiated when Stop is selected on the control panel. The N1 fuel governor speed reference is then driven to decrease. When CDP decreases to 117 psia (site-dependent), the generator circuit breaker is energized Open. Operators are alerted when the circuit breaker is open. As N1 continues to decelerate, and reaches its idle set point, a Cooldown In Progress message is given and a 5-minute timer is started. The 5-minute cooldown timer will also start should the operator elect to manually decrease the governor speed and manually open the breaker. The operator must then operate the Stop switch to begin cooldown. After the 5-minute cooldown timer elapses, the generator AC lube oil pump is energized, upstream and downstream fuel valves are shut off, the gas vent valve is opened on gas-fueled systems, and 4-minute and 5-minute timers are started. The 4-minute timer is a coastdown timer that produces a Coastdown Complete operator message when it elapses. If there are no shutdown conditions prevailing, a Ready to Start message is generated. If shutdown conditions do exist, a Shutdown Conditions Exist operator message is generated. The 5-minute timer is a Post Shaft Rotation timer. After it elapses and the generator zero shaft speed switch indicates the generator shaft has stopped rotating, the generator space heaters are energized and the AC lube oil pump is deenergized.

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TURBINE CONTROL SYSTEM – FUNCTIONAL DESCRIPTION Doc No: 613034-1200

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Operation INTRODUCTION This section contains instructions and information to safely operate the LM2500 GTG set. The operating procedures for the turbine generator follow later in this section. PRESTART INSPECTION Before starting the LM2500 GTG set, perform the following inspections and initial steps to avoid inadvertent shutdown or possible damage to the equipment. Foreign objects or debris left in the turbine inlet plenum could result in severe damage to the turbine engine. 1.

Check the turbine inlet plenum for foreign objects or debris. Remove any debris.

Note Do not fill the turbine lube oil reservoir past two-thirds full while the turbine is running. Overfilling will result in runover when unit is shut down. 2.

Check the oil level in the turbine and generator lube oil systems’ reservoirs. Fill as required. Use only the approved lube oils listed in Chapter 2 for the turbine and generator lube oil systems. Check lube oil temperatures. Minimum acceptable lube oil temperature is 70 °F.

Note If lube oil temperature is less than 70 °F, ensure that the heaters in the lube oil tanks are turned on. (Refer to One Line Diagram, Motor Control Center.) 3.

Check the fuel pressure. Fuel inlet pressure must be within specifications.

4.

Check fluid level in the reservoir of the hydraulic start unit. Replenish fluid levels as needed. Use approved fluid listed in Chapter 2.

5.

Examine all fluid fittings, piping, flanges, and hoses for evidence of leakage. Check hoses for chafing.

Note Leaks at fuel line fittings are often caused by loose fittings and can be eliminated by simply tightening. If required, lock-wire fittings in accordance with the standard maintenance practices outlined in the GE LM2500 On-Site Operation & Maintenance Manual in Chapter 5.

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6. Check condition of the fire and gas protection system detectors. a. Verify that optical flame detectors are aimed in the desired direction, with a clear field of view. Verify that the flame detectors have been calibrated and tested in accordance with the maintenance schedule. b. Check thermal (heat) spot detectors for clean, undamaged probes. Check maintenance records to verify that the detectors have been properly calibrated and tested in accordance with the maintenance schedule. c. Check combustible gas detector sensors to ensure that the screens are clean. Check the maintenance records to verify that the sensors have been properly calibrated and tested in accordance with the maintenance schedule. Note Gas detector sensors are very sensitive and require frequent calibration. If in doubt, calibrate or replace them with new sensors. 7.

Check the fire-extinguishing system as follows: a. Inspect fire extinguishant discharge nozzles for obstructions or corrosion. b. Check the weight and charge pressure of each fire-extinguishing bottle as outlined in Chapter 2. c. Check the batteries and battery chargers that supply power to the fire suppression and gas detection panel. Verify that connections at the battery terminals are tight and free of dirt and corrosion, the batteries are fully charged, and chargers are operating properly.

Note During the first 30–90 days of operation, monitor the equipment frequently. Record performance trends in order to predict maintenance and instrument set intervals. 8.

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Check and record all instrument readings at regular intervals while the GTG set is in operation. Ensure that all readings are within normal limits.

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OPERATING PROCEDURES Startup Power Requirements Either utility power or a blackstart generator is required to start the turbine. See BOP manuals for blackstart documentation. Operating Procedures The following tables provide operating procedures for the LM2000 GTG set. The operator should perform the action listed in the Operator Action column with corresponding results listed in the System Response column. If two or more operator steps, such as setting two or more switches, are required to obtain a system response, then the response is listed beside the step that actually triggers the response. Initial conditions, operating indicators, and other pertinent information are listed in the Comments column. Note These procedures assume that the bus has been energized from the utility and that 360 VAC is applied to the MCC through the auxiliary transformer. 1.

Table 5.1, AC Power-On. Describes the procedure for applying AC power for system startup and operation.

2.

Table 5.2, DC Power-On. Describes the procedure for applying DC power to the control panels.

3.

Table 5.3, Alarm Acknowledge and Reset. Describes the procedure for acknowledging and resetting alarm and shutdown circuits after alarm conditions have been cleared.

4.

Table 5.4, Manual Turbine Purge. Describes the procedure for verifying that the turbinecranking system is functioning properly and will accelerate the turbine to light-off speed. A turbine purge cycle may also be used:

5.

•

to blow any accumulated fuel out of the exhaust collector after an aborted start;

•

to cool the turbine hot section after a shutdown so that an immediate restart can be attempted; and

•

to blow water out of the turbine after a water wash, as described in Chapter 2.

Table 5.5, Local Start with Automatic Synchronizing and Paralleling. Describes the procedure for starting the LM2000 set from the turbine control panel (TCP), and paralleling by automatic synchronization with the power distribution system, using the Woodward controls. (The Woodward control system functions may also be accessed from the desktop Human Machine Interface (HMI)

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6.

Table 5.6, Local Start with Manual Paralleling. Describes the procedure for starting the LM2000 set from the TCP and paralleling by manual synchronization with the power distribution system, using a synchroscope.

7.

Table 5.7, Auto-to-Manual Voltage Regulator Transfer. Describes the procedure for transferring from auto to manual voltage regulation during operation.

8.

Table 5.8, Generator Unloading. This procedure is used to shift the load from the GTG set to the utility source before opening the applicable circuit breaker.

9.

Table 5.9, Normal Stop. Describes the procedure for bringing the LM2000 unit to a normal stop.

10. Table 5.10, Malfunction Shutdown. This procedure is fully automatic and is initiated by the alarm and shutdown setting of pilot devices. No operator action is required. 11. Table 5.11, Emergency Stop. Describes the procedure for bringing the LM2000 to a quick stop when emergency conditions require immediate shutdown.

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Table 5.1, AC Power-On Operator Action

System Response

Comments

1

At the MCC, set all disconnect handles in On positions; set all Hand-Off-Auto switches to Auto position.

Electronic control system controls application of AC power from MCC cubicles.

On-Off indicators show status of the respective MCC cubicles, as controlled by the electronic control system.

2

Energize the charger(s) for the Battery chargers begin charging batteries powering the TCP circuits batteries. and fire-control system.

3

In the Termination Cubicle, close the circuit breakers that apply battery power to the TCP control circuits and the fire-control system.

Indicator lamps on battery chargers illuminate to indicate energized status, and ammeters indicate charging rate.

END OF SEQUENCE

Table 5.2, DC Power-On Operator Action

System Response

Comments

1

In the Termination Cubicle, close the circuit breakers that apply DC voltage to control circuits and firecontrol system.

2

Set power supply On-Off switches to On position for fuel management controller (located in MTTB) and sequencer (located in TCP).

Resets all timers to zero. Resets all signal outputs to zero or inactive state. Selects and energizes generator and turbine enclosure vent fans and waits 20 sec to verify air flow.

Power On indicator illuminates.

3

Toggle the switches on the circuit boards for the fuel controller and sequencer.

Horn sounds and Critical Path Shutdown message appears on desktop HMI.

Silence horn by selecting ACK from the Alarms screen on the desktop HMI.

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Table 5.2, DC Power-On (Cont) Note The Reset function may have to be pressed more than once to reset the critical-path shutdown relays. The Acknowledge function may have to be selected more than once to silence alarm horn.

Operator Action

System Response

Comments

4

If no Critical Shutdown is active, message terminates.

If a shutdown condition or alarms exist, horn sounds again and appropriate shutdown and/or alarm messages appear on desktop HMI. If required, investigate and clear any active alarms and shutdowns before proceeding.

All timers and signal outputs assume zero or inactive states. One turbine compartment vent fan and one generator compartment vent fan are energized.

At the initiation of startup, the second vent fan for the generator compartment will energize.

Select Reset from the Alarms screen on the desktop HMI to latch critical-path shutdown relays.

The control system waits 30 sec to verify airflow before energizing auxiliary generator lube oil pump for 5 min.

5

At the hydraulic starter skid control panel, press Reset to clear starting system alarm indicators.

Turbine and generator compartments are purged for 3−10 min before starting can be attempted.

When compartment purge is completed, the Master Start Permissive block of the Start Permissive screen will turn green.

Red alarm indicators extinguish.

Turbine control systems and starter skid are now ready for normal operation.

END OF SEQUENCE

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Table 4.3, Alarm Acknowledge and Reset Operator Action

System Response

Comments

1

Select ACK from the Alarms screen.

Silences horn.

System alarm/shutdown message(s) remain until cleared and reset.

2

Select Reset from the Alarms screen.

desktop HMI reflects that alarm has been resetting. Alarm or shutdown messages will terminate when the condition(s) causing them have been cleared.

After the cause of any malfunctions or alarms has been cleared, this procedure ensures that no other fault conditions exist which may prohibit starting.

END OF SEQUENCE

Table 5.4, Manual Turbine Purge Operator Action

System Response

Comments

1

Verify lube oil system pressurizes.

No other start or water wash cycle may be in progress.

Select Maintenance from the Unit Control screen on the HMI. Then select Start.

Hydraulic starter pump starts and runs for 10 sec to verify fluid circulation. Starter engages and cranks the gas generator at approximately 2300 rpm for 5 min. Fuel and ignition are disabled during this time. Starter disengages. When gas generator speed drops below 350 rpm, the 15-min coastdown timer starts.

After turbine is purged, switch to Normal mode and turbine is ready to start.

Turbine is ready to start.

END OF SEQUENCE

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Table 5.5, Local Start with Automatic Synchronizing and Paralleling Operator Action

System Response

1

Set Synchronizing switch to Auto position.

2

Set Voltage Regulator excitation mode switch to Auto position; and set Voltage Regulator On-Off switch to On position.

On the desktop HMI, AVR In Auto message appears on the Generator Data portion of the display. If manual voltage regulation has been selected, the AVR In Manual message replaces AVR In Auto.

3

While in Normal mode, select Start from the Unit Control screen.

The generator auxiliary lube oil pump energizes. Pump discharge pressure is verified. Generator rundown tanks fill.

Comments This is the preferred mode of operation. The switch settings are required for automatic voltage, frequency, and phase matching. This permits automatic synchronizing and paralleling of the applicable breaker.

Compartment vent fans toggle, and vent fan airflow is verified. The hydraulic start pump is energized. 10 sec later, The starter is engaged, and cranks the gas generator.

The GTG set undergoes crank.

The purge ends after 2 min (standard configuration) and approximately 7-8 Min (HRSG). The solenoid valve destrokes the starter swash plate to min position, and the gas generator speed decreases to 0%. When gas generator speed drops below 1200 rpm, the solenoid valve positions starter swash plate angle to max (100%). 4 5

On the desktop HMI, observe the rpm indicated by GG Speed Reference display. Observe power turbine inlet T48 Temp and GG Speed Reference displays.

The starter ramps to 100% and begins to accelerate the gas generator. Fuel flow and ignition start at 1200 rpm. Light-off speed.

Lightoff occurs

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15 sec after fuel ignition, verify T48 is greater than 400°F. If T48 is less than 400°F, then a shutdown and purge sequence occurs for 5 minuts.

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Table 5.5, Local Start with Automatic Synchronizing and Paralleling (Cont) Operator Action

System Response

Comments

5

The fuel system start ramp begins increasing fuel flow to accelerate the gas generator to idle (starter disconnect) speed.

If gas generator speed fails to exceed 4500 rpm within 90 sec after T48 temperature reaches 400 °F, the Fail To Accelerate shutdown is tripped

Observe power turbine inlet T48 Temp and GG Speed Reference displays. (Cont)

If core idle (app. 6800 rpm) is not reached in 120 sec, then a shutdown occurs.. When gas generator speed exceeds 4500 rpm, - starter disengages, - igniters shut off, - Starting Cycle message terminates, - Turbine Running message appears, - Fired Starts Counter advances by one increment, and - Turbine Run Time meter initializes. 6

On the desktop HMI display, obGas generator speed reaches 6800 serve that gas generator speed rpm, starting 5-min warm-up timer. stabilizes at app 6800 rpm and that power turbine speed increases. After 5 min warm up complete, GG ramps up to accelerate power turbine to 3000 rpm.

7

On the desktop HMI’s Gen Power Data screen, observe Generator Voltage data, Exciter Field Voltage data, and Exciter Field Current ampere data.

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As generator shaft speed reaches 3000 rpm, the AC lube oil pump deenergizes and the generatordriven pump assumes lubrication load.

If power turbine speed fails to exceed 350 rpm within the 5-min warmup period, the PT Fail To Accelerate shutdown activates. Excitation increases as the unit accelerates to sync-idle speed.

After an approximate 60-sec delay for voltage to stabilize, paralleling devices are enabled.

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Table 5.5, Local Start with Automatic Synchronizing and Paralleling (Cont) Operator Action

System Response

8

Observe the red and green lamps When paralleling devices match used to indicate the status of the generator frequency, phase angle, and output voltage with those on the circuit breaker. other bus, the circuit breaker closes and Ready To Load appears.

9

On desktop HMI’s Gen Power Data screen, check generator ammeter, varmeter, and wattmeter readings.

10

On the desktop HMI, check T48 Temp, GG Speed, and PT Speed displays.

11

Use the Governor Raise-Lower switch to increase the loading on the generator.

Comments The GTG set is ready to assume its proportional share of the load. The red (breaker closed) lamp illuminates and the green (breaker open) lamp extinguishes.

The unit assumes new load setting by increasing fuel flow. Loading is limited by T48 maximum temperature.

END OF SEQUENCE

Table 5.6, Local Start with Manual Paralleling Manual mode operation of the voltage regulator should only be performed by personnel who are thoroughly familiar with the GTG set. Due to the possibility of load variations causing output voltage fluctuations and possible equipment damage, the unit must be attended to at all times. Operator Action 1

Set Synchronizing switch to Man position, selecting either Gen Man or Utility Man.

2

Set Voltage Regulator excitation mode switch to Auto position (or set to Man if voltage regulator fails).

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System Response

Comments This sequence will only be used during commissioning or if the automatic synchronization system fails.

The AVR In Auto message appears on the desktop HMI’s Generator Data display. (If the Voltage Regulator switch is set to Man, the AVR In Manual message appears.)

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If the automatic voltage regulator fails, the generator may be operated in the Man mode on the excitation mode switch. The operator must adjust the voltage as the load increases or decreases, in manual voltage control mode.

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Table 5.6, Local Start with Manual Paralleling (Cont) Operator Action

System Response

3

Fuel system pressure is verified.

In Normal mode, Select Start from the Unit Control screen.

Comments

The turbine begins accelerating. Accessory systems operate as in Table 4.5. The Master Start Permissive message terminates. The Turbine Running message appears on the desktop HMI when the unit reaches idle speed.

The voltage regulator increases or decreases excitation power as programmed, in order to raise or lower generator output voltage.

4

Using the desktop HMI’s Generator Power Data screen, compare generator and bus voltage levels. Use the Auto Voltage Regulator Adjust switch to match generator voltage to bus voltage.

5

Use the Speed Raise-Lower switch The gas generator accelerates or as necessary, in order to match decelerates slightly to alter the power generator output frequency to bus turbine speed. frequency.

Toggle this switch momentarily and wait for power turbine speed to stabilize after each adjustment. The frequencies must be matched as closely as possible.

Paralleling the generator by continually holding the circuit breaker switch in the closed position, and waiting for the synccheck relay to detect a phase match, could result in serious equipment damage and/or injury to personnel. 6

Observe the needle of the Synchroscope. Adjust the power turbine speed with the Speed Raise-Lower switch to obtain the slowest clockwise rotation possible.

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The synchroscope needle rotates at a rate proportional to the difference in frequency between the generator and the bus voltages. The direction of rotation indicates whether the generator frequency is above or below the bus frequency. The needle position relative to zero indicates the phase angle difference.

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If the difference in frequency is large, the synchroscope needle will not rotate but may stay in place and vibrate.

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Table 5.6, Local Start with Manual Paralleling (Cont) Operator Action

System Response

Comments

7

The sync-check relay blocks the circuit breaker Close command until the frequency, voltage, and phase angle are matched accurately enough to meet its pre-set requirements.

If the generator is synchronized within safe tolerances, the circuit breaker close signal is relayed to the circuit breaker-closing circuit.

Grasp the Generator Circuit Breaker switch and watch the synchroscope needle closely. Set the switch to Close when the needle is between 11 o’clock and 12 o’clock, and rotating slowly in a clockwise rotation.

The LM2000 GTG set is paralleled As the circuit breaker closes, the with the utility and may be loaded. green (breaker open) lamp extinguishes and the red (breaker closed) lamp illuminates. Ready To Load message appears. Also, indicated speed on the PT Reference display moves to the upper limit. 8

Increase the generator loading with The unit assumes the new load setthe Speed Raise-Lower switch. ting by increasing fuel flow.

Loading limited by T48 temperature.

END OF SEQUENCE

Table 5.7, Auto-to-Manual Voltage Regulator Transfer When the voltage regulation switch is in the manual mode, any generator voltage adjustments must be made manually. Note The following procedure may be performed while the GTG set is operating. Operator Action

System Response

Comments

1

On the desktop HMI, the AVR In Auto message changes to AVR In Manual. The null balance indicator may settle at either end of the scale.

The voltage regulation is now under manual control.

Set the Voltage Regulator ManNorm-Auto switch to Man and release.

END OF SEQUENCE

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Table 5.8, Generator Unloading Operator Action

System Response

1

Use the Speed Raise-Lower switch Gas generator speed will drop to high to decrease gas turbine speed until idle. The T48 Temp should also drop. the Generator Watts Total display on desktop HMI Generator Power Data screen indicates minimum watts.

2

Set the applicable Generator Circuit Breaker switch to Trip (open) position and release.

Comments Reducing gas turbine speed forces the utility to reassume the entire load.

The circuit breaker opens. The red The GTG set now operates in the lamp extinguishes and the green lamp unloaded state until further operator illuminates. action is initiated. On the desktop HMI, the Unit Ready To Load message terminates, an alarm sounds, and a Breaker Trip message appears on the desktop HMI.

END OF SEQUENCE

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Table 5.9, Normal Stop Note This procedure assumes that generator unloading has been performed. If not, select Stop to initiate a programmed engine ramp-down that will trip the applicable circuit breaker when the turbine engine CDP reaches a specified value (normally when the generator loading drops below 5 MW).

Operator Action

System Response

Comments

1

Ensure that the synchronizing switch is in the Off position.

Automatic synchronization is disabled. If auto-synchronizer is left “on,” attempts to automatically reclose circuit breaker will continue.

2

From the desktop HMI menu, select Stop.

Stop cycle is initiated. The gas generator decelerates to idle, at approximately 6800 rpm for approximately 5 min in order to cool down. The Ready To Load message terminates.

The cooldown period starts.

When the 5-min cooldown ends, the fuel valves close and the turbine engine begins coasting to a stop. On the desktop HMI, a Stop Cycle message appears and the Turbine Running message terminates. During the cooldown period, the Start Permissive message appears. After the generator shaft speed drops to 350 rpm, the generator auxiliary lube oil pump continues to operate for 15 min before deenergizing.

END OF SEQUENCE

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Table 5.10, Malfunction Shutdown Operator Action

System Response

Comments

1

Depending on the nature of the malfunction, resulting shutdowns could be either a cooldown or faststop type (as in the emergency stop procedure).

Malfunctions must be cleared and shutdown circuits reset, before the turbine can be restarted.

Malfunctions are detected automatically by the control system, and indicated by the lockout relay light.

The desktop HMI monitor annunciates the reason for the shutdown.

Note Lockout shutdowns can only be reset at the TCP. Resets for non-lockout shutdowns, however, can be performed from the desktop HMI. END OF SEQUENCE

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Table 5.11, Emergency Stop

Repeated emergency shutdowns, without a proper cooldown period, can cause undue equipment wear. Whenever possible, use the start and normal stop functions on the desktop HMI menu.

Note Typically, four emergency stop switches are provided: one on the TCP, one in the generator compartment, and two in the turbine compartment. Operating any of these switches will initiate the sequence of events described below. Operator Action

System Response

1

Initiates a fast stop routine. No Fuel valves are commanded to be cooldown period occurs before fuel is closed immediately. The AC lube oil pump turns on immediately. The gas cut off. generator begins to coast down, the Turbine Running message terminates, and a Stop Cycle message appears.

Operate the System Emergency Stop switch on the TCP, or one of the Emergency Stop switches on the main skid.

Comments

Gas generator speed drops to 350 rpm, and coastdown timer is started. 2

Reset systems by resetting the activated Emergency Stop switch (at an appropriate time). Silence and extinguish alarms by selecting Reset from the desktop HMI menu.

END OF SEQUENCE

POST-OPERATION MAINTENANCE After the GTG set is shut down, refer to Chapter 2 for instructions on preventive maintenance and any corrective maintenance required to eliminate deficiencies noted during the last operation.

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APPENDIX

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DEFINITIONS FOR ALARM AND SHUTDOWNS

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DEFINITIONS FOR ALARM AND SHUTDOWNS For Shutdowns the following symbols must be verified for proper sequence of operation to verify Shutdown Conditions: FSLO Fast Stop Lockout Without Motor – Trips breaker, fuel shutoff immediately, chops steam and water. Can only be reset from the Turbine Control Panel. FSWM Fast Stop – Starter motor is engaged for 7.5minutes when NGG goes below 1700 RPM. Can only be reset from the Turbine Control Panel. Note: If T4.8 is 18ºF (10ºC)

P2 - COMPRESSOR INLET PRESSURE Device Nomenclature Tag no. 1. Compressor Inlet Pressure PT-8024 Loss of signal

Setting Loss of signal

T3 - COMPRESSOR DISCHARGE TEMPERATURE Device Nomenclature Tag no. 1. Gas Generator Compressor Discharge Temperature (T3)

APPENDIX-6

Setting

Function Alarm Default to 14.69 PSIA

Function

TE-8038A/C

Loss of 1 signal Remove from avg.

Alarm

TE-8038A/C

Loss of 2 signals

Alarm

TE-8038A/C

> 20ºF between signals (-6.6ºC)

Alarm Select higher signal

P3 - COMPRESSOR DISCHARGE PRESSURE Device Nomenclature Tag no. 1. Gas Generator Compressor Discharge Pressure

Function

Loss of 1 signal

PT-8004A/B

Setting

Function

Loss of 1 signal

Alarm

Loss of both signals

Shutdown FSLO default to last valid value

Difference > 10 PSIA (68.6KPA)

Alarm Select higher sensor

Difference > 15 PSIA For > .1 sec. (103.4KPA)

Shutdown FSLO Default to higher Signal

> 310 PSIA (2585KPA)

Alarm

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P4.8 - POWER TURBINE INLET PRESSURE Device Nomenclature Tag no. 1. Power Turbine Inlet Pressure Loss of Signal

PT-8060

Setting

Function

Loss of signal

Alarm Default to last Valid signal Alarm

Loss of P48 Pressure Tap (0.5 + P2 psia)

Alarm Default to last Valid signal

T4.8 - POWER TURBINE INLET TEMPERATURE Device Nomenclature Tag no.

Setting

Function

1.

Power Turbine Inlet Excessive ring spread

TE-8044A8044K

>200º Spread between valid T48min-T48max

Alarm

2.

Power Turbine Inlet Temperature Loss of signal

TE-8044A8044K

Loss of 1 signal

Alarm & remove from average

Loss of 3 or more Adjacent signals

Shutdown SML & remove from average

Loss of any 4 signals

Shutdown SML & remove from average

3.

Power Turbine Inlet Temperature Fa TE-8044Ato Lite 8044K

< 400ºF (204.4ºC) with Gas fuel on + 10 seconds on Gas Gas Fuel

Shutdown FSLO

4.

Power Turbine Inlet Temperature Over Temperature

TE-8044A8044K

T48 SEL > 1300ºF (704ºC) With NGG, 5000RPM

Shutdown FSLO

TE-8044A8044K TE-8044A8044K

< 400 ºF after being > 400ºF (204.4C) > 1525º F (854ºC)

Shutdown FSLO Alarm

5. Turbine Flame Out 6.

Power Turbine Inlet Temperature Over Temperature

> 1575ºF > 0.1sec. (871ºC)

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Shutdown FSLO

APPENDIX-7

LM2000 50HZ GENERATOR PACKAGE SPEED SENSORS Device Nomenclature

Tag no.

BASIC OPERATORS COURSE

Setting

Function

1. Gas Generator Fails to Accelerate

SE-8000 A/B

< 4500 RPM, 90 seconds after ignition on

Shutdown FSLO

2. Gas Generator Fails to Accelerate

SE-8000 A/B

< 4500 RPM 120 seconds after ignition on

Shutdown FSLO

3. Gas Generator Speed Sensor Differential

SE-8000 A/B

> 37.5 RPM difference between Sensors

Alarm Select Higher Sensor

4. Gas Generator Speed Sensor failure

SE-8000 A/B

Loss of 1 Sensor

Alarm

Loss of Both Sensors

Shutdown FSLO Default to 2000RPM

> 10,100 RPM

Alarm

> 10,200 RPM

Shutdown FSLO

5. Gas Generator Overspeed

SE-8000 A/B

6. Power Turbine Overspeed

SE-8002 A/B

> 3960 RPM

Shutdown FSLO

7. Power Turbine Speed Sensor Failure

SE-8002 A/B

Loss of 1 Sensor

Alarm

Loss of Both Sensors

Shutdown FSLO – Default to 1000 RPM Alarm Select Higher Sensor Shutdown FSLO

8. Power Turbine Speed Sensor Differential

SE-8002A/B

9. Turbine External Overspeed

SSW1

> 40 RPM Difference Between Sensors

SSW2 10. Gas Generator Fails to Crank

APPENDIX-8

SE-8000 A/B

< 1700 RPM After Starter Engagement + 20 Seconds

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Shutdown FSLO Shutdown FSLO

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LM2000 50HZ GENERATOR PACKAGE FLAME SENSORS Device Nomenclature 1. Turbine Flame Detectors

VIBRATION SENSORS Device Nomenclature 1. Gas Generator Vibration

2. Power Turbine Vibration

3. Gas Generator Vibration

4. Power Turbine Vibration

5. Generator Vibration

6. Generator Vibration

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Tag no. BE-8022 A/B

Tag no. XE-8005

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Setting

Function

Loss of 1 signal with Fuel on

Alarm Flame not detected

Loss of 2 signals

Shutdown FSLO

Loss of Flame at Power

Shutdown FSLO

Setting

Function

4 mils. (101.6mm) (75-200Hz)

Alarm

7mils. (177.8mm) (75-200Hz) 4 mils . (101.6mm) (75-200HZ)

Shutdown SDTI Alarm

7 mils > (177.8mm) (75-200HZ)

Shutdown SDTI

7 mils. (177.8mm) (25-200Hz)

Alarm

10mils. (254mm) (25-200Hz) 7mils . (177.8mm) (25-200HZ)

Shutdown SDTI Alarm

10 mils > (254mm) (25-200HZ)

Shutdown SDTI

XE-8007A Right side Non-drive end – ALF

> 3.0 mils (76 mm)

Alarm

> 4.0 mils (101 mm)

Shutdown SDTI

XE-8007B Left side Non-drive end – ALF XE-8009A Right side Non-drive end – ALF

> 3.0 mils (76 mm)

Alarm

> 4.0 mils (101 mm)

Shutdown SDTI Alarm

> 4.0 mils (101 mm)

Shutdown SDTI

XE-8009B Left side Non-drive end – ALF

> 3.0 mils (76 mm)

Alarm

> 4.0 mils (101 mm)

Shutdown SDTI

XE-8006 Mounted on PT

XE-8005

XE-8006 Mounted on PT

> 3.0 mils (76 mm)

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TURBINE LUBE OIL SYSTEM Device Nomenclature

Tag no.

Setting

LT-1002 100%=0 mm from top 0 %=752 mm from top

Low Level – (12”) 83% 127mmFrom Top Low Level – (14”) (138KPA)

Alarm

3. High Turbine Scavenge Oil Filter Differential Pressure

PDT-1007

20 PSID > (138KPA)

Alarm

25 PSID > (172KPA)

Shutdown SDTI

1. Turbine Lube oil Tank Level

Function Alarm Shutdown FSLO

4. High Turbine Scavenge Lube Oil Pressure

PT-1022

110 PSIG > (758.4KPA) Alarm

5. Low Turbine Oil Pressure

PT-1021

< 8 PSIG (55KPA) RPM > 4500 < 8000

Alarm

< 6 PSIG (41.3KPA) RPM > 4500 < 8000

Shutdown FSLO

< 25 PSIG (172.3KPA) Alarm RPM > 8000

6. High Turbine Accessory Gearbox Scavenge Oil Temperature

7. High Turbine Sump A Scavenge Oil Temperature 8. High Turbine Sump B Scavenge Oil Temperature

TE-1023 A/B

TE-1024 A/B

TE-1025 A/B

< 15 PSIG (103.4KPS) RPM > 8000

Shutdown FSLO

Sensor Failure

Shutdown FSLO

300ºF > (149ºC)

Alarm

320º F > (160ºC)

Shutdown SML

300ºF > (149ºC)

Alarm

320º F > (160ºC)

Shutdown SML Alarm

300ºF > (149ºC) 320º F > (160ºC)

9. High Turbine Sump C Scavenge Oil Temperature

TE-1026 A/B

300ºF > (149ºC) 320º F > (160ºC)

APPENDIX-10

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Shutdown SML Alarm Shutdown SML

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TURBINE LUBE OIL SYSTEM (Cont) Device Nomenclature 10.High Turbine Sump D Scavenge Oil Temperature

Tag no. TE-1027A/B

Setting

Function

300ºF > (149ºC)

Alarm

320º F > (160ºC)

Shutdown SML Alarm

11.Turbine Lube Oil Tank Temp. Low

TE-1013

< 70ºF (21.1ºC)

12. Turbine Lube Oil Supply Temperature

TE-1028 A/B

< 20ºF > 190ºF (-6.6ºC – 87.7ºC)

Alarm

> 6800 RPM < 90º > 200ºF (32.2ºC – 93.3ºC) < 75 ohms > 2.5 sec.

Shutdown (SML)

13. Magnetic Chip Detector Accessory Gearbox

MCD-1060

14. Magnetic Chip Detector Sump A

MCD-1061

< 75 ohms > 2.5 sec.

Alarm

15. Magnetic Chip Detector Sump B

MCD-1062

< 75 ohms > 2.5 sec.

Alarm

16. Magnetic Chip Detector Sump C

MCD-1063

< 75 ohms > 2.5 sec.

Alarm

17. Magnetic Chip Detector Sump D

MCD-1064

< 75 ohms > 2.5 sec.

Alarm

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Alarm

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LM2000 50HZ GENERATOR PACKAGE GAS FUEL SYSTEM Device Nomenclature 1. Gas Fuel Supply Pressure

Tag no. PT-2027

BASIC OPERATORS COURSE

Setting

Function

< 195 psig (1344.4 KPA) Alarm with GG < 7000 RPM < 320 psig (2206.3 KPA) Alarm with GG > 7000 RPM < 185 psig (1275.5KPA) Shutdown FSWM

2. Gas Fuel Supply Temperature

APPENDIX-12

TE-2032 A/B

> 600 psi (4137 KPA)

Alarm

> 650psig (4481.6KPA)

Shutdown FSWM

> 275ºF (135ºC)

Alarm

> 300ºF (149ºC)

Shutdown CDLO

> 325ºF (163ºC)

Shutdown FSLO

Loss of 1 sensor

Alarm Remove from avg.

Loss of both sensors

Shutdown FSLO and default to last good value

Difference > 10ºF (5.5ºC) between sensors

Alarm Select higher sensor

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LM2000 50HZ GENERATOR PACKAGE

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COMBUSTION AND VENTILATION Device Nomenclature

Tag no.

Setting

Function

1. Turbine Room Outlet Temperature

TE-4001

200ºF > (93ºC)

Alarm

2. Turbine Room Inlet Temperature

TE-4054

> 140ºF (60ºC)

Alarm

> 150ºF (65.5ºC)

Shutdown CDLO

3.Generator Inlet Differential Pressure

PDT-4008

2.75 “ WC > (69.78 mm) Alarm BSLN (1.75-2.0) + 1”

4.Generator Inlet Differential Pressure

PDT-4009

2.75 “ WC > (69.78 mm) Alarm BSLN (1.75-2.0) + 1”

5. Combustion Air Inlet Differential Pressure

PDT-4005

5.0” WC > (127mm)

Alarm

8.0” WC > (203.2mm)

Shutdown CDLO

6. Turbine Room Pressure Differential

PDT-4007

< .1” WC (2.54mm)

Alarm

7. Air Inlet Filter Temperature

TE-4082

< 43ºF (6ºC) Possible Icing condition

Alarm

8. Generator Exciter Air Outlet Temperature

TE-4031

>194ºF (90ºC)

Alarm

> 212ºF (100ºC)

Shutdown CDLO Alarm

9. MTTB Cabinet Air Temperature

TE-4090

10. MGTB Cabinet Air Temperature

TE-4091

11. Generator Stator Temperature T1 A TE-4021A

12. Generator Stator Temperature T2 A TE-4022A

< 0º or > 125ºF ( 125ºF ( 273ºF (133ºC)

Alarm

> 291ºF (144ºC)

Shutdown FSLO Alarm

> 273ºF (133ºC) > 291ºF (144ºC)

13. Generator Stator Temperature T3 A TE-4023A

> 273ºF (133ºC) > 291ºF (144ºC)

14. Generator Stator Temperature T1 B TE-4021B

> 273ºF (133ºC) > 291ºF (144ºC)

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Alarm

PLTG Kaji Power Station

Shutdown FSLO Alarm Shutdown FSLO Alarm Shutdown FSLO

APPENDIX-13

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

COMBUSTION AND VENTILATION (CONT) Device Nomenclature

Tag no.

15. Generator Stator Temperature T2 B TE-4022B

16. Generator Stator Temperature T3 B TE-4023B

Setting

Function

> 273ºF (133ºC)

Alarm

> 291ºF (144ºC)

Shutdown FSLO Alarm

> 273ºF (133ºC) > 291ºF (144ºC)

17. Generator Stator Temperatures

TE-4021A/B TE-4022A/B TE-4023A/B

< 14ºF (-10ºC)

Shutdown FSLO Start Inhibited Must be above 14ºF f Start premissive

18. Generator Air Outlet Temperature

TE-4030

>194ºF (90ºC)

Alarm

> 212ºF (100ºC)

Shutdown CDLO

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LM2000 50HZ GENERATOR PACKAGE GENERATOR LUBE OIL SYSTEM Device Nomenclature Tag no. 1. Generator Lube Oil Tank Level

LT-1001

BASIC OPERATORS COURSE

Setting

High Level >90% (5” from Top)

2. Generator Run Down Tank Levels

3. Generator Lube Oil Pressure

LT-0041/0042

PT-0026

Function

Low Level Alarm < 63% (10.65” from top) Alarm

Low Level 60 Psig 4. Generator Lube Oil Filter Differential Pressure

PDT-0015

> 20 Psig

Shutdown FSLO Alarm

5. Generator Lube Oil Tank Temperature

TE-0020

< 70ºF (21.1ºC)

Alarm

6. Generator Lube Oil Supply Temperature

TE-0025

> 160ºF (71.1ºC)

Alarm

> 190ºF (87.7ºC)

Shutdown CDLO Alarm

7. Generator Bearing Temperature DE

TE-0021

> 212ºF (100ºC) > 221ºF (105ºC)

8. Generator Bearing Oil Drain DE

TE-0036

> 185ºF (85ºC) > 194ºF (90ºC)

9. Generator Bearing Temperature NDE

TE-0023

>2127ºF (100ºC) > 221ºF (105ºC)

10. Generator Bearing Oil Drain NDE

TE-0035

> 185ºF (85ºC) > 194ºF (90ºC)

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Shutdown FSLO Alarm Shutdown FSLO Alarm Shutdown FSLO Alarm Shutdown FSLO

APPENDIX-15

LM2000 50HZ GENERATOR PACKAGE HYDRAULIC STARTER SYSTEM Device Nomenclature 1. Hydraulic Starter Oil Tank Level

Tag no.

LT-6001

2. Hydraulic Oil Tank Temperature

TE-6003

3. Hydraulic Starter Oil Return Temperature

TE-6002

FIRE PROTECTION SYSTEM Device Nomenclature 1. Gas Monitor Shutdown

Tag no. AE-3004 A/B/C/D

BASIC OPERATORS COURSE

Setting

Function

< 73% (6”from top)

Alarm

> 91% (2” from top)

Alarm

< 69% (7” from top)

Shutdown FSLO

< 70º or > 180ºF (21.1ºC 82.2ºC)

Alarm

> 190ºF (87.7ºC) > 180ºF (82.2ºC)

Shutdown Starter Alarm

Setting

Function

> 10% LEL

Alarm Turn on all Fans

> 25% LEL

Shutdown FSLO

2. Thermal Switch Turbine Enclosure

TS-3003A/B

Shutdown FSLO

3. Manual Suppressant Agent Release

HS-3008/3009

Shutdown FSLO

4. Fire/Gas Alarm Horn

YSA-3006/3006A

Verify Operation

5. Fire /Gas Warning Beacon

YSL-3036/3036A

Verify Operation

6. Horn Acklnowledge Switch

HS-3000

Verify Operation

7. Pressure Switch Fire Suppressant Released

PSHH-3048

8. Fire/Gas Monitor Failure

FPP

Alarm

9. Fire/Gas Monitor Shutdown

FPP

Shutdown FSLO

APPENDIX-16

> 150 Psig

PLTG Kaji Power Station

Shutdown FSLO

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LM2000 50HZ GENERATOR PACKAGE MISCELLANEOUS FAULTS Device Nomenclature

BASIC OPERATORS COURSE

Tag no.

Setting

Function

1. Local Emergency Stop

ES3

2. Remote Emergency Stop 3. Generator 86 Lockout Trip

ESTR-1 ESTR-2 ESGR-3 86G

4. Generator Summary Alarm

AVR

Shutdown FSLO Shutdown FSLO Shutdown FSWM Alarm

5. Generator Excitation Tripped

AVR

Alarm

6. Generator Rotor Ground Fault

GRF

Alarm

7. Battery Charger Failure-DC

Charger

DC output failed

Alarm

8. Battery Charger Failure-AC

Charger

AC Supply failed

Alarm

9. Low Battery Voltage

Charger

< 21 volts

10. IGPS

IGPS

Trip

Shutdown SML Alarm

Fault

Alarm

Power Supply Alarm

Alarm

Failure

Shutdown CDLO

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

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APPENDIX-18

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ABBREVIATIONS AND ACRONYMS

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APPENDIX-20

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TECHNICAL MANUAL ABBREVIATIONS AND ACRONYMS A A Ampere(s) abs Absolute AC Alternating Current acfm Actual Cubic Feet per Minute acmm Actual Cubic Meter per Minute AGB Accessory Gearbox ALF Aft, Looking Forward Assy Assembly ASTM American Society for Testing and Materials atm Atmosphere AUX Auxiliary AVRX Auxiliary Voltage Regulator B β (Beta) Variable Stator Position BEM Brush Electrical Machines bhp Brake Horsepower BOP Balance of Plant Btu British Thermal Unit C °C Degree Celsius (Centigrade) cc Cubic Centimeter CCW Counterclockwise CDLO Cooldown Lockout CDP Compressor Discharge Pressure cfm Cubic Feet per Minute CG Center of Gravity cid Cubic Inch Displacement CIT Compressor Inlet Temperature cm Centimeter cm2 Square Centimeter cm3 Cubic Centimeter Cont Continued CRF Compressor Rear Frame CRT Cathode-Ray Tube (Screen) CT Current Transformer CW Clockwise

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APPENDIX-21

LM2000 50HZ GENERATOR PACKAGE D dB dBA DC DCS

BASIC OPERATORS COURSE

Decibel Decibel (Absolute) Direct Current Digital Control System

DF Diesel Fuel dn/dt Differential Speed/Differential Time (Rate of Change, Speed vs. Time) dp Differential Pressure dp/dt Differential Pressure/Differential Time -dPs3/dt Negative Rate of Change of HighPressure Compressor Static Pressure DSM Digital Synchronizing Module Dwg. Drawing E EMU Engine Maintenance Unit F °F FCV F&ID Fig. FIR FMP FOD FLSO

Degree Fahrenheit Flow Control Valve Flow & Instrument Diagram Figure Full Indicator Reading Fuel Manifold Pressure Foreign-Object Damage Fast Stop Lockout Without Motoring FSWM Fast Stop With Motoring ft Foot (Feet) ft2 Square Feet Cubic Feet ft3 ft-lb Foot-Pound G GA gal GE GG gpm GT GTG

General Arrangement Gallon(s) General Electric Gas Generator Gallons per Minute Gas Turbine Gas Turbine Generator

APPENDIX-22

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BASIC OPERATORS COURSE

H H-O-A HAND-OFF-AUTO (Switch) hp Horsepower HP High Pressure HPC High-Pressure Compressor HPCR High-Pressure Compressor Rotor HPT High-Pressure Turbine HPTR High-Pressure Turbine Rotor h Hour(s) Hz Hertz (Cycles per Second) I ID Inside Diameter IEEE Institute of Electrical and Electronics Engineers IGHP Isentropic Gas Horsepower IGKW Isentropic Gas Kilowatt IGV Inlet Guide Vane in Inch(es) in2 Square Inch Cubic Inch in3 in-Hg Pressure, Inches of Mercury in-lb Inch-Pound in-Wg Pressure, Inches of Water I/O Input/Output IPB Illustrated Parts Breakdown ISA Instrument Society of America K kg cm Kilogram-Centimeter kg m Kilogram-Meter kohm Kilohm kPa KiloPascal kPad KiloPascal Differential kPag KiloPascal Gauge K (CONT) kV Kilovolt kVA Kilovolt Ampere kvar Kilovar kW Kilowatt kWh Kilowatthour kWhm Kilowatthour Meter

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APPENDIX-23

LM2000 50HZ GENERATOR PACKAGE L L lb LEL LFL LP LPC Lpm LPCR LVDT

BASIC OPERATORS COURSE

Liter Pound(s) Lower Explosive Limit Lower Flammable Limit Low Pressure Low-Pressure Compressor Liters Per Minute Low-Pressure Compressor Rotors Linear Variable-Differential Transformer

M m Meter 2 Square Meter m m3 Cubic Meter mA Milliampere Maint. Maintenance MAVR Modular Automatic Voltage Regulator mb Millibar MCC Motor Control Center MGTB Main Generator Terminal Box MHz Megahertz MIL Military MIL-SPEC Military Specification MIL-STD Military Standard min Minute(s) mm Millimeter Mohm Megohm(s) mph Miles Per Hour MTTB Main Turbine Terminal Box Mvar Megavar MW Megawatt N NEMA National Electrical Manufacturers Association Nm Newton Meter NOx Oxides of Nitrogen O OAT Outside Air Temperature OD Outside Diameter O&M Operation and Maintenance

APPENDIX-24

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BASIC OPERATORS COURSE

P P2

Low-Pressure Compressor Inlet Total Pressure P25 High-Pressure Compressor Inlet Total Pressure P48 Low-Pressure Turbine Inlet Total Pressure Pamb Ambient Pressure Para. Paragraph P (CONT) PCB Printed Circuit Board PF Power Factor PMG Permanent Magnet Generator ppm Parts Per Million Ps3 High-Pressure Compressor Discharge Static Pressure Ps25 High-Pressure Compressor Inlet Static Pressure Ps55 Low-Pressure Turbine Discharge Static Pressure psia Pounds per Square Inch Absolute psid Pounds per Square Inch Differential psig Pounds per Square Inch Gauge PT Pressure Transmitter PTO Power Takeoff R rms rpm RTD RTV

Root Mean Square Revolutions Per Minute Resistance Temperature Detector Room Temperature Vulcanizing

S scfm scmm SDTI sec SG shp SML S/O SOV S&S STIG

Standard Cubic Feet per Minute Standard Cubic Meters per Minute Step Decelerate to Idle Second(s) Specific Gravity Shaft Horsepower Slow Decelerate to Minimum Load Shutoff Solenoid-operated Valve Stewart & Stevenson Services, Inc. Steam Injection

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APPENDIX-25

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

T T2 T3 T25 T48 Tamb TAN TBD TGB theta 2

TIT TRF

Low-Pressure Compressor Inlet Total Temperature High-Pressure Compressor Discharge Temperature High-Pressure Compressor Inlet Temperature Low-Pressure Turbine Inlet Temperature Ambient Temperature Total Acid Number To Be Determined Transfer Gearbox Ratio of Measure Absolute Gas Generator Inlet Temperature to Standard Day Absolute Temperature Turbine Inlet Temperature Turbine Rear Frame

V V Volt VAC Volts, Alternating Current var Volt-Ampere Reactive VBV Variable Bypass Valve VDC Volts, Direct Current VG Variable Geometry V (CONT) VIGV Variable Inlet Guide Vane VSV Variable Stator Vane W W W2

Watt Low Pressure Compressor Physical Airflow W25 High Pressure Compressor Physical Airflow Wf Flow, Fuel Wg Pressure, Water Gauge Wh Watt-Hour WHRU Waste Heat Recovery Unit

APPENDIX-26

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LM2000 50HZ GENERATOR PACKAGE X XN2

BASIC OPERATORS COURSE

Low-Pressure Rotor Speed Physical

XN2R Low-Pressure Rotor Speed Corrected XN25 High-Pressure Compressor Speed Physical XN25R High-Pressure Compressor Speed Corrected XNSD Low-Pressure Turbine Speed

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LM2000 50HZ GENERATOR PACKAGE

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APPENDIX-28

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GLOSSARY

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GLOSSARY A A/D Conversion – Analog-to-Digital Conversion: A con-version that takes an analog input in the form of electrical voltage or current and produces a digital output. ABT – Automatic Bus Transfer: For critical loads, normal and alternate, power sources are provided. The power sources are supplied from separate switchboards through separate cable runs. Upon loss of the normal power supply, the transfer switch automatically disconnects this source and shifts the load to the alternate source. AC – Alternating Current: Alternating current is an electric current that flows first in one direction for a given period of time, and then in the reverse direction for an equal period of time, constantly changing in magnitude. A – Ampere: A unit of electrical current or rate of flow of electrons. One volt across one ohm of resistance causes a current flow of one ampere. Analog Signal: An analog signal is a measurable quantity that is variable throughout a given range and is representative of a physical quantity. Annular: In the form of, or forming, a ring. Anti-Icing: A system for preventing the buildup of ice on the gas turbine intake systems. APD – Automatic Paralleling Device: Automatically parallels any two gas turbine-generator sets. B Babbitt: A white alloy of tin, lead, copper, and antimony which is used for lining bearings. BAS – Bleed-Air System: The BAS uses as its source compressed air extracted from the compressor stage of each gas turbine module and gas turbine-generator set. The BAS is used for anti-icing, prairie air, masker air, and low-pressure gas turbine starting for both the gas turbine module and the gas turbine-generator set. Bleed Air: Hot, compressed air bled off the compressor stage of the gas turbine module and gas turbine-generator set. See BAS – Bleed-Air System. Blow-in Doors: The blow-in doors located on the high-hat assembly are designed to open by means of solenoid-operated latch mechanisms if the inlet airflow becomes too restricted for normal engine operation.

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Borescope: A small periscope used to visually inspect internal engine components. BTB – Buss Tie Breaker: A BTB is used to connect one main switchboard to another main switchboard. Buffer: To electronically isolate and filter an electrical signal from its source. Bus: The term used to specify an uninsulated power conductor. C CB – Circuit Breaker: An automatic protective device that, under abnormal conditions, will open a current-carrying circuit. CIT – Compressor Inlet Temperature (T2): CIT is the temperature of the air entering the gas turbine compressor as measured at the front frame. CIT is one of the parameters used for calculating engine power output (torque) and scheduling fuel flow and variable stator vane angle. Coalesce: To grow together, unite, or fuse, as uniting small liquid particles into large droplets. This principle is used to remove water from fuel in the filter/separator. Condensate: The product of reducing steam (gas) to a liquid; (water). For example, as used in the distilling process. D D/A Conversion – Digital-to-Analog Conversion: A con-version that produces an analog output in the form of voltage or current from a digital input. DC – Direct Current: Direct current is an electric current that flows in one direction. A pure direct current is one that will continuously flow at a constant rate. Deaerator: A deaerator is a device that removes air from oil as in the LS&C tank (gas turbine module) which separates air from scavenged oil. Delta P – Differential Pressure: The pressure drop across a fixed device. Demisters: A moisture-removal device that separates water from air. Dessicant: A substance having a great affinity for water and used as a drying agent. Diffuser: A device that reduces the velocity and increases the static pressure of a fluid passing through a system. Digital Signal: A signal, in the form of a series of discrete quantities, that has two distinct levels.

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BASIC OPERATORS COURSE E

Eductor: The eductor is a mixing tube which is used in the gas turbine module exhaust system. It is physically positioned at the top of the stack so that the gas flow from the gas turbine module exhaust nozzles will draw outside air into the exhaust stream as it enters the mixing tube. EG – Electronic Governor: An electronic governor is a system that uses an electronic control unit, in conjunction with an electrohydraulic governor actuator, to control the position of the liquid fuel valve on the gas turbine-generator set and regulate engine speed. F Fault Alarm: This type of alarm is used in the Fuel Oil Control System and Damage Control Console. It indicates that a sensor circuit has opened. FO System – Fuel Oil System: The FO system provides a continuous supply of clean fuel to the gas turbine module and to the gas turbine-generator set. The gas turbine module and gas turbinegenerator set can operate on DFM, ND, and JP-5. FOD – Foreign-Object Damage: Damage as a result of entry of foreign objects into a gas turbine engine. G GB – Generator Breaker: Circuit breaker used to connect a gas turbine-generator set to its main switchboard. GCU – Generator Control Unit: A static GCU is supplied for each gas turbine-generator set consisting of a static exciter/voltage regulator assembly, field rectifier assembly, motor-driven rheostat, and a mode select rotary switch. It controls the output voltage of the generator. Governor Droop Mode: Droop mode is normally used only for paralleling with shore power. Because shore power is an infinite bus, droop mode is necessary to control the load carried by the gas turbine-generator set. If a gas turbine-generator set is paralleled with shore power, and one attempts to operate in isochronous mode instead of droop mode, the gas turbine-generator set governor speed reference can never be satisfied because the gas turbine-generator set frequency is being held constant by the infinite bus. If the gas turbine-generator set governor speed reference is above the shore power frequency, the load carried by the gas turbine-generator set will increase beyond capacity in an effort to raise the shore power frequency. If the speed reference is below the shore power frequency, the load will decrease and reverse in an effort to lower the shore power frequency. The resulting overload or reverse power will trip the gas turbine-generator set circuit breaker.

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Governor Isochronous Mode: The isochronous mode is normally used for gas turbinegenerator set operation. This mode provides a constant frequency for all load conditions. When operating two gas turbine-generator sets in parallel isochronous mode, it also provides equal load sharing between the units. GTG Set – Gas Turbine-Generator Set: The GTG set consists of a gas turbine engine; a reduction gearbox; and a three-phase, alternating-current generator rated at 2000 kW and 450 VAC. GTM – Gas Turbine Module: The GTM consists of the main propulsion gas turbine unit, including the gas turbine engine, base, enclosure, shock-mounting system, fire detection and extinguishing system, and the enclosure environmental control components. H Header: This is a piping manifold that connects several sub-lines to a major pipeline. Head Tank: A tank located higher than other system components to provide a positive pressure to a system by gravity. Helix: A tube or solid material wrapped like threads on a screw. High-Hat Assembly: A removable housing over the main engine air intake ducts, which contains the moisture-separating system, inlet louvers, and blow-in doors. Hz – Hertz: A unit of frequency equal to one cycle per second. I I/O – Input/Output: The interfacing of incoming and outgoing signals from the computer to the controlled device. IGV – Inlet Guide Vanes: Vanes ahead of the first stage of compressor blades of a gas turbine engine whose function is to guide the inlet air into the gas turbine compressor at the optimum angle. Immiscible: Incapable of being mixed. Impinge: To strike, hit, or be thrown against, as in the case of condensate impinging against the tubes or baffles. Inlet Plenum: That section of the gas turbine inlet air passage that is contained within the engine enclosure. ISO – Isochronous: Governing with steady-state speed regulation of essentially zero magnitude.

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Labyrinth/Windback Seals: The labyrinth/windback seals combine a rotating element with a smooth-surface stationary element to form an oil seal. This type of seal is used in conjunction with an air seal, with a pressurization air cavity between the two seals. Pressure in the pressurization air cavity is always greater than the sump pressure, therefore, flow across the seal is toward the sump, thus preventing oil leakage from the sump. The windback is a course thread on the rotating element of the oil seal which, by screw action, forces any oil which might leak across the seal back into the sump. Latent: Present, but not visible or apparent. LED – Light-emitting Diode: A solid-state device which, when conducting, emits light. The LEDs are used for the digital displays and card fault indicators in the local control panel and other electronic systems. Liquid Fuel Valve: Meters the required amount of fuel for all engine operating conditions for the GTG set engine. Load Shedding: Generator overpower protection by automatically dropping preselected nonvital loads when generator output reaches 100% for 3 seconds, and additional dropping of preselected semivital loads if the overload condition exists for another 5 seconds. Local Control: Startup and operation of equipment by means of manual controls attached to the machinery, or by the electric panel attached to the machinery or located nearby. LOCOP – Local Control Panel: Electronic enclosure containing operating and monitoring equipment used to control the turbine during operation. The control elements of the system are powered by 28 VDC from the switchboard or batteries. M micron: A unit of measure equal to one-millionth of a meter. mil: A unit of measure equal to one-thousandth of an inch. MRG – Main Reduction Gear: The reduction gear is a single-reduction, single-helical (spiral), gear-type speed reducer. N Nozzle: A small jet (hole) at the end of a pipe.

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LM2000 50HZ GENERATOR PACKAGE

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Orifice: A restricted opening used primarily in fluid systems. P PCB – Printed Circuit Board: An electronic assembly mounted on a card using etched conductors. Also called Printed Wiring Board (PWB). PF – Power Factor: The ratio of the average (or active) power to the apparent power (rootmean-square voltage × rms current) of an alternating-current circuit. Pinion: A smaller gear designed to mesh with a larger gear. Pitch: A term applied to the distance a propeller will advance during one revolution. PMA – Permanent Magnet Alternator: PMA is mounted on the generator shaft extension of each GTG set and supplies speed sensing and power to the EG. PMA also supplies initial generator excitation. Poppet-Type Check Valve: A valve that moves into and from its seat to prevent oil from draining into the GTG set when the engine is shut down. ppm – Parts Per Million: Unit of measure. pps – Pulses Per Second: Unit of measure. psi – Pounds per Square Inch: Unit of measure (pressure). psia – Pounds per Square Inch Absolute: Unit of measure (pressure). psid – Pounds per Square Inch Differential: Unit of measure (pressure). psig – Pounds per Square Inch Gage: Unit of measure (pressure). PTO – Power Takeoff: PTO is the drive shaft between the GTG set, gas turbine engine, and the reduction gearbox. Transfers power from the gas turbine to the reduction gearbox to drive the generator. Pushbutton Switch Indicators: A panel-mounted device that contains both switch contacts and indicating lights. The contacts are actuated by depressing the device face. The indicator lights are labeled and wired for indicating alarm or status information.

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Rabbet Fit: A groove, depression, or offset in a member into which the end or edge of another member is fitted, generally so that the two surfaces are flush. Also known as register and spigots. Radio-Frequency Interference: An electrical signal capable of being propagated into, and interfering with, the proper operation of electrical or electronic equipment. RTD – Resistance Temperature Detector: Same as RTE. RTE – Resistance Temperature Element: These temperature sensors work on the principle that as temperature increases, the conductive materials exposed increase their electrical resistance. S Scavenge Pump: Used to remove oil from a sump and return it to the oil supply tank. scfm – Standard Cubic Feet per Minute: Unit of measure. Sensor: A device that responds to a physical stimulus and transmits a result impulse for remote monitoring. Serial Data Bus: The bus is time-shared between the LOCOP and the end device. Control and status information are exchanged in the form of serial data words. Stall: An inherent characteristic of all gas turbine compressors to varying degrees and under certain operating conditions. It occurs whenever the relationship between air pressure, velocity, and compressor rotational speed is altered to such extent that the effective angle of attack of the compressor blades becomes excessive, causing the blades to stall in much the same manner as an aircraft wing. Sync – Synchronize: The state where connected alternating-current systems operate at the same frequency and where the phase-angle displacements between voltages in them are constant or vary about a steady and stable average value. SWBD – SWitchBoarD: A large panel assembly which mounts the control switches, circuit breakers, instruments, and fuses essential to the operation and protection of electrical distribution systems. Switch Indicator: See Pushbutton Switch Indicator.

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T2 – Compressor Inlet Temperature: Same as CIT. TIT – Turbine Inlet Temperature: TIT is the GTG set’s turbine inlet temperature. U Ultraviolet Flame Detectors: Ultraviolet flame detectors sense the presence of fire in the GTM and GTG set and generate an electrical signal to the alarm panel. X XDCR – Transducer: The XDCR is a sensor that converts quantities such as pressure, temperature, and flow rate into electrical signals. XFR – Transfer: The theoretical relationship between measure and output values, as determined by inherent principles of operation.

APPENDIX-38

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GAS TURBINE ENGINE THEORY DEFINITIONS

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LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

GAS TURBINE ENGINE THEORY DEFINITIONS INTRODUCTION This information sheet has been prepared to aid the student in his understanding of the basic principles of physics, the gas laws, thermodynamics, and the Brayton cycle, which are associated with gas turbine engine operation. A thorough knowledge of these principles will greatly aid the student throughout his career in the Gas Turbine field.

REFERENCES Aircraft Gas Turbine Engine Technology Sawyer’s Turbomachinery Maintenance Handbook Modern Marine Engineers Manual Handbook of Physics and Chemistry Basic Thermodynamics

DEFINITIONS

Absolute pressure P The actual pressure applied to a system. Normally found by adding a value of 14.7 to gauge readings. (Normal units are expressed as pounds per square inch, absolute (psia).) Absolute temperature T Temperature that is reckoned form the absolute zero. (Normal units are expressed as either degrees Rankine or degrees Kelvin.) Absolute zero The point at which all molecular activity ceases. Computed to be a temperature of approximately –460 degrees Fahrenheit (−460° F) or –273 degrees Celsius (−273° C). Acceleration a The rate of change of velocity, in either speed or direction. (Normal units are expressed as feet per second squared (ft/sec2).) Adiabatic As applied to thermodynamics, applies to a process or cycle that occurs with no net loss or gain of heat. Ambient pressure Pamb For our uses while studying marine gas turbine engines, the pressure felt directly outside the ship (atmospheric pressure). DEFINITIONS (CONT) 2262533TR

PLTG Kaji Power Station

APPENDIX-41

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

Ambient temperature Tamb For our uses while studying marine gas turbine engines, the temperature felt directly outside the ship (atmospheric temperature). Bernoulli theorem As a fluid flows through a restricted area such as a nozzle, the velocity of the fluid will increase with a corresponding decrease in pressure and a slight decrease in temperature. The inverse is true for fluid flow through a diffuser. Boyle’s law If the absolute temperature of a given quantity of gas is held constant, the absolute pressure of the gas is inversely proportional to the volume the gas is allowed to occupy. Brayton cycle The thermodynamic cycle on which all gas turbine engines operate, considered to be a constant pressure cycle (combustion occurs at a constant pressure). British thermal unit Btu Defined as the quantity of heat required to raise the temperature of a 1-pound mass of water 1 degree Fahrenheit (1° F). (Water is to be pure distilled water, and the temperature change is from 64 degrees Fahrenheit (64° F) to 65 degrees Fahrenheit (65° F).) Cascade effect As related to compressor stall, cascade effect is where turbulence created in the forward stages of the compression section is passed rearward through the compressor, with an increase in the total amount of turbulence with each successive stage. Celsius (centigrade) °C Normally used by scientists, a temperature scale in which the temperature θc in degrees Celsius (°C) is related to the temperature Tk in kelvins by the formula: θc = Tk − 273.15. Charles’ law If the absolute pressure of a given quantity of gas is held constant, the volume the gas is allowed to occupy is directly proportional to the absolute temperature of the gas. Compound blading A blending of both reaction and impulse turbine blading such that the actual blades are impulse at the root and reaction at the tip. It is the most common type of blading used in the turbine and power turbine sections of modern gas turbine engines. Compressor discharge pressure CDP The actual pressure of the air exiting the compressor section, after having passed through all stages of compression and the diffuser, and passing on to the combustion section. Compressor discharge temperature CDT The temperature of the compressed air that has passed through all compression stages and the diffuser, and is being passed to the combustor. Compressor inlet pressure CIP The pressure of the air at the inlet to the inlet guide vanes of the compressor. Normally slightly less than atmospheric pressure.

APPENDIX-42

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

DEFINITIONS (CONT) Compressor inlet temperature CIT The temperature of the air which actually enters the compressor. Normally measured at the inlet bellmouth. Compressor stall When turbulence across the stages of the compressor becomes severe enough (owing to the cascade effect), the actual airflow through the compressor is disrupted and decreases. During compressor stall, it is not common to see a reduction in the rpm of the compressor section, only a reduction in the actual air- flow through the compressor. Compressor ratio C/R compressor inlet pressure.

A ratio of the compressor discharge pressure divided by the

Compressor ratio per stage CR/STG The pressure rise that each individual stage in the compressor can handle. It has been determined that in an axial-flow compressor, the maximum CR/STG is approximately 1.2-to-1. Conduction A method of heat transfer in which one area of a substance is heated, causing an increase in the molecular vibrations at that point. These increased vibrations are transmitted from atom to atom throughout the length of the substance. Configuration

How something is put together.

Conservation of momentum During an elastic collision with no losses owing to heat or friction, the total momentum of Object 1 must equal the total momentum of Object 2. Convection A method of heat transfer in which one area of a fluid is heated, causing a current to be set up that transfers the heat throughout the fluid. Cycle

A process that begins with certain conditions and ends at the original conditions.

Cycle efficiency The output horsepower of the engine divided by the input energy used. In the case of all gas turbine engines, efficiency is equal to work rate brake divided by heat rate of addition (the units for both must be the same). (Normal units are expressed as percent (%).) Delta δ

Pressure correction factor.

Distance

d

The amount of linear separation between two or more objects or points.

Diameter D The length of a straight line through the center of an object. (Normal units are expressed as feet (ft) or inches (in).) Dovetail A type of blade attachment normally used to attach the rotating blades in the compressor section of an axial-flow compressor to the disk.

2262533TR

PLTG Kaji Power Station

APPENDIX-43

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

DEFINITIONS (CONT) Elastic collision In physics, a collision in which there are no losses owing to friction or heat, and no plastic deformation occurs. Energy lb.).)

E

The capacity to do work. (Normal units are expressed as foot pounds (ft-

Exhaust gas temperature EGT The temperature of the gases that are exhausted from the engine. (Normal units are expressed as degrees Fahrenheit (°F).) Exit guide vanes EGV Used in most axial-flow compressors to reduce the total amount of turbulence that is passed from the compressor section to the combustion section of the engine. Fahrenheit °F Degrees Fahrenheit. A temperature scale normally used by engineers (not an absolute temperature scale). First law of thermodynamics Energy is indestructible and interconvertible. Three main points: (1) Energy cannot be created or destroyed; (2) energy can change forms; and (3) energy is conserved for any system, open or closed. Fir tree A type of blade attachment normally used to hold the rotating blades of an axial-flow turbine to the turbine disk or wheel. Fluid or gas).

Any substance which conforms to the shape of its container (may be either liquid

Force F A vector quantity that tends to produce, modify, or retard motion. (Normal units are expressed as pounds (lb).) The amount of fuel an engine is using at any given time. (Normal units are Fuel flow Wf expressed as gallons per hour (gal/hr).) Function

How something is accomplished.

Gas constant R A number derived for any gas by use of the perfect gas equation. This constant for atmospheric air is 53.345. Gas generator G/G The section of a split-shaft engine that is composed of the compressor, combustor, and turbine. Gas turbine engine GTE A form of internal combustion heat engine that operates on the Brayton cycle, and in which all events occur continuously during normal engine operation. Gauge pressure psig to read absolute pressure.

APPENDIX-44

The actual pressure readings taken from gauges that are calibrated

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

DEFINITIONS (CONT) General gas law

A combination of both Boyle’s law and Charles’ law.

Gravity g The gravitational attraction of the mass of the earth, the moon, or a planet for bodies at or near its surface. On earth, the acceleration owing to gravity is 32.174 ft/sec2. Heat Q The energy associated with the random motion of atoms, molecules, and smaller structural units of which matter is composed. .

Heat rate of addition Qa The amount of energy (in Btu/min) which is added during the combustion process in the gas turbine engine. DEFINITIONS (CONT) .

Heat rate of rejection Qr A loss for a gas turbine engine. The amount of energy that was added during the gas turbine engine cycle, but was not extracted in the turbine section and was exhausted to the atmosphere. (Normal units are expressed in British thermal units per minute (Btu/min).) Heat transfer Height hgt

The transfer of thermal energy between two or more bodies or substances. The extent of elevation above a level. (Normal units are expressed as feet (ft).)

Horsepower hp The unit of power in the British engineering system, equal to 550 footpounds per second, approximately 745.7 watts. Impulse blading A type of turbine or power turbine blading which operates principally by the conservation of momentum. Inlet guide vanes IGV A set of vanes located in the forward part of the axial-flow compressor which are used to direct the incoming air at a predetermined angle toward the direction of rotation of the first-stage blades. Kelvin K scale.

A temperature scale which is absolute and is related to the Celsius temperature

Kinetic energy (ft-lb).)

EK

Local sound of speed CS temperature.

The energy of motion. (Normal units are expressed as foot-pounds Speed of sound is directly related to the ambient or local

Mass m The quantity of fundamental matter of which an object is composed. Mass of an object does not change with location.

2262533TR

PLTG Kaji Power Station

APPENDIX-45

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

DEFINITIONS (CONT) Matter

Anything having weight and occupying space.

Momentum M A property of a moving body that determines the length of time required to bring it to rest when under the action of a constant force. Newton’s laws

Three laws which encompass a large amount of classical physics:

Every body or substance will continue in its state of rest or uniform motion in a 1st straight line, unless acted upon by some external force. 2nd A force is required to accelerate a body; the magnitude of this force is directly proportional to the mass of the body and to the acceleration produced. Mathematically written as: F = m · a. 3rd

For every action, there is an equal and opposite reaction.

Open cycle A cycle in which the operating medium is drawn in at atmospheric conditions, undergoes some process or processes, and is then returned to atmospheric conditions. Potential energy

Ep

Stored energy.

pi π The ratio of the circumference of any circle to its diameter. A constant with no units; an approximation is 3.1416. Power p

The time rate of doing work. (Normal units are expressed as horsepower (hp).)

Power turbine extracted.

P/T

Pound(s)

A unit of measure used to denote either an amount of weight or force.

lb

Pound mass lbm weight).

The section of split-shaft engines in which work rate brake is

A unit of measure used to denote the mass of an object (the object’s

Pressure The force or thrust exerted over a surface divided by its area. (Normal units are expressed as pounds per square inch (psi).) Primary air CDP air.

The CDP air which is actually used for combustion in a GTE; 25% of all

Radiation One type of heat transfer in which the thermal energy is transferred from one body or substance which is not in physical contact with a second body or substance by random wave motion.

APPENDIX-46

PLTG Kaji Power Station

2262533TR

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

DEFINITIONS (CONT) Rankine °R Degrees Rankine. An absolute temperature scale that is directly related to the Fahrenheit temperature scale. Reaction blading of action and reaction.

The type of turbine blading which operates mainly on the principle

Revolutions per minute

rpm

A measure of the speed of rotation of a rotating body.

Secondary air The portion of CDP air which is used to cool and center the flame of combustion, 75% of all CDP air. Second law of thermodynamics Heat cannot, on its own accord, be made to flow from a body or substance of lower temperature to a body or substance of higher temperature in a continuous, self-sustaining process. More simply stated, heat transfer is from hot to cold. Single-shaft engine One of the simplest forms of GTE which has only one shaft and three major components: (1) a compressor, (2) a combustor, and (3) a turbine. Specific enthalpy

h

The total energy content of a mass of gas.

Specific heat c The quantity of heat required to raise the temperature of a 1-pound mass of a substance at 1 degree Fahrenheit (1° F). cv

Specific heat at constant volume

cp

Specific heat at constant pressure

Speed N Distance traveled per unit time. (Common units are expressed as feet per second (ft/sec), miles per hour (mph), and revolutions per minute (rpm).) Temperature T A measure of the intensity of heat. (Normal units are expressed as Fahrenheit (°F) or Rankine (°R) (where an absolute unit is required).) Theta Θ

The temperature correction factor.

Thermodynamics reaction of heat.

The branch of physics which deals with the mechanical action or

Time t A measured or measurable period during which an action, process, or condition exists or continues.

2262533TR

PLTG Kaji Power Station

APPENDIX-47

LM2000 50HZ GENERATOR PACKAGE

BASIC OPERATORS COURSE

DEFINITIONS (CONT) Tip clang The actual bending of the rotating blades used in an axial-flow compressor when the pressures across the blades become excessive because of the turbulence of stall. When these have enough pressure to cause them to physically bend, they can actually contact the stationary vanes; when this occurs, the condition is known as tip clang. Turbine inlet temperature TIT The temperature of the gases exiting the combustion section of the engine and entering the turbine section. Total energy

Et

The algebraic sum of the potential and kinetic energy of a body or substance.

Velocity vel Speed in a given direction; a vector quantity. (Normal units are expressed as feet per second (ft/sec) or revolutions per minute (rpm).) Vector quantity Volume V 3 inches (in ).)

A quantity that has both magnitude and direction. Cubic capacity. (Normal units are expressed as cubic feet (ft3) or cubic

Weight wt A measure of the pull of gravity on a quantity of matter. (Normal units are expressed as pound(s) (lb).) Work W Work is equal to the product of the force applied to an object, multiplied by the distance through which the force acts. Work rate brake

Wb

The actual output horsepower that is produced by an engine.

Work rate of compression Wc compressor sections of a GTE.

The calculated value of power required to drive the

Work rate turbine Wt The amount of work extracted from the hot gases in the turbine section. This work must be utilized to drive both the compressor section and the engine’s load in the single-shaft engine, and the value of work rate turbine is used only to drive the compressor in the split-shaft engines. (Normal units are expressed as horsepower (hp).

APPENDIX-48

PLTG Kaji Power Station

2262533TR

DRAWING TITLE

DRAWING NUMBER

P AND I DIAGRAM

GB-00016609

JUNCTION BOX LAYOUT

GB-00016610

WIRING DIAGRAM

GB-00016611

CABLE SCHEDULE AND TEST RECORD

GB-00016612

ELECTRICAL INSTALLATION

GB-00016613

FC 1

ITEM

KAJI POWER ATLAS PC - 90/70 CONTROL R WITH VERSAMAX DISTRIBUTIVE I/O E V FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL

SIGNAL

IN/

SOURCE

OUT

TYPE

FUEL CONTROL - A N A L O G I/O

DISPLAY

RANGE

FAULT

RANGE

FAULT LIM

ACTION

UNIT

ALM

ALM

AL

S/P

UNIT

R/F

ACTION

S/D

S/D

S/D

S/P

UNIT

R/F

ACTION

CONTROL

COMMENTS

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

ADDRESS

TERMINAL

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS. © Copyright 2003 GE Packaged Power, L.P. All rights reserved. This drawing is the proprietary and/or confidential property of GE Packaged Power, L.P. and is loaned in strict confidence with the understanding that will not be reproduced nor used for any purpose except that for which it is loaned. It shall be immediately returned on demand and is subject to all other terms and conditions of any written agreement or purchase order that incorporates or relates to this drawing.

ATLAS PC - SMARTCORE BOARD (SMC) 1-- 1 1-- 2

GAS GEN ROTOR SPEED (NGGA)

1-1-1-1-1-1--

3 4 5 6 7 8

DELTA12

1-1-1-1-1-1--

9 10 11 12 13 14

POWER TURB ROTOR SPEED (NPTA)

DELTA12 TURB COMB FLAME DETECTOR NO.1 (RIGHT) TURB COMB FLAME DETECTOR NO.1 (LEFT) GEN MW SIGNAL MW

SE-8000A SE-8002A

IN IN

MAG MAG

0-12000

NOTE 1

RPM

0-5000

NOTE 5

RPM

ZC-2018 ZC-2019 BE-8022A BE-8022B WX

IN IN IN IN IN IN

4-20S 4-20S 4-20 4-20 4-20 4-20

0-100 0-100

-2/102 -2/102

2700-3992

2646/4072

NOTE 7

DEG.F

NOTE 7

NOTE 7

SMC_AI_03

2700-3992

2646/4072

NOTE 7

DEG.F

NOTE 7

NOTE 7

SMC_AI_04

0-30

-2/28

ALARM

MW

OUT OUT OUT OUT OUT OUT

4-20S 4-20S 4-20S 4-20S 4-20S 4-20S

SE-8000B SE-8002B

IN IN

MAG MAG

0-12000

NOTE 1

RPM

0-5000

NOTE 5

RPM

TE-8044A TE-8044B TE-8044C TE-8044D TE- 8044E TE- 8044F TE- 8038A TE-2034 PT-8024 PT-8060 PT-8004A

IN IN IN IN IN IN IN IN IN IN IN

T/C T/C T/C T/C T/C T/C T/C T/C 4-20 4-20 4-20

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

-40/1000

0-800

-16/816

0-16

8/16

NOTE14

PSIA

0-100

10/90

NOTE 19

PSIA

0-500

10/390

PT-2070 PT-2029 TE-8015A TE-2032A

IN IN IN IN

4-20 4-20 *RTD2 RTD

0-1300

-26/1326

ALARM

PSIG

0-1000

-20/1020

ALARM

PSIG

-65/130

-70/140

NOTE 22

DEG F

NOTE 22

-40/400

-40/380

NOTE 23

DEG F

NOTE 23

(SPARE) (SPARE) ZC-2018 ZC-2019

DELTA12 DELTA12

(SPARE) (SPARE) (SPARE)

SML ALARM

10100 RPM

% %

↑ ALARM

NOTE4

* 10200 RPM

↑ FSLO

Rat* SEE NOTE 2&3, Ratio 1 RPM = 0.783294 HZ

SMC_DSS_01

3960 RPM

↑ FSLO

RatRatio 1 RPM = 1.38333 HZ

SMC_DSS_02

NOTE4

SMC_AI_01 SMC_AI_02

SEE NOTE 8

SMC_AI_05 SMC_AI_06

SMC_AO_01

0-100 0-100

---------

---------

% %

SMC_AO_02 SMC_AO_03 SMC_AO_04 SMC_AO_05 SMC_AO_06

MAIN- 51/53/54 MAIN- 55/57/58

+ / - / SHLD

MAINMAINMAINMAINMAINMAIN-

27/29/30 31/33/34 35/37/38 39/41/42 43/45/46 47/49/50

+ / - / SHLD

MAINMAINMAINMAINMAINMAIN-

65/66/67 68/69/70 71/72/73 74/75/76 77/78/79 80/81/82

+ / - / SHLD

ANA1- 57/58/59 ANA1- 60/61/62

+ / - / SHLD

ANA1ANA1ANA1ANA1ANA1ANA1ANA1ANA1ANA1ANA1ANA1-

1/2/3 4/5/6 7/8/9 10/11/12 13/14/15 16/17/18 19/20/21 22/23/24 26/27/28 29/30/31 32/33/34

+ / - / SHLD

ANA1ANA1ANA1ANA1-

35/37/38 39/41/42 45/44/43/46 49/48/47/50

- / 24VDC(-) / SHLD

+ / - / SHLD

+ / - / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD

+ / - / SHLD + / - / SHLD + / - / SHLD + / - / SHLD + / - / SHLD

ATLAS PC - ANALOG COMBO BOARD (EBX1) 2-- 1 2-- 2

GAS GEN ROTOR SPEED (NGGB)

2-2-2-2-2-2-2-2-2-2-2--

3 4 5 6 7 8 9 10 11 12 13

POWER TURBINE INLET TEMP (TOP RT,T48-A)

2-2-2-2--

14 15 16 17

DELTA12

2-- 18 2-- 19

POWER TURB ROTOR SPEED (NPTB)

POWER TURBINE INLET TEMP (TOP RT,T48-B) POWER TURBINE INLET TEMP (TOP RT,T48-C) POWER TURBINE INLET TEMP (BOTTOM RT,T48-D) POWER TURBINE INLET TEMP (BOTTOM RT,T48-E) POWER TURBINE INLET TEMP (BOTTOM RT,T48-F) GAS GEN COMP DISCH TEMP (T3A) DELTA12 GAS GEN COMPRESSOR INLET PRESS (P2) POWER TURBINE INLET PRESSURE (P48) GAS GEN COMP DISCH PRESS (PS3A) (CDP)

DELTA12 GAS GEN COMPRESSOR INLET TEMP (T2A) TURB GAS FUEL SUPPLY TEMP A

(SPARE) (SPARE)

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

ALARM

10100 RPM

↑ ALARM

10200 RPM

↑ FSLO

3960 RPM

↑ FSLO

Ra Ratio 1 RPM = 0.783294 HZ Ra Ratio 1 RPM = 1.38333 HZ

EBX1_DSS_01

SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16

EBX1_AI_01

DEG F

EBX1_DSS_02

EBX1_AI_02 EBX1_AI_03 EBX1_AI_04 EBX1_AI_05 EBX1_AI_06 EBX1_AI_07

DEG F

400 DEG F

↑ ALARM

700 DEG F

↑ FSWM

EBX1_AI_08 EBX1_AI_09

NOTE 19 PSIA

EBX1_AI_10

PSIA

310 DEG F 1200

PSIG

↑ ALARM

1250 PSIG

↑ FSLO

NOTE 17

EBX1_AI_11

↑ FSWM

50 PSIG START TRANSFER PERMISSIVE

EBX1_AI_12 EBX1_AI_13

NOTE 22 DEG.F

↑ ALARM

OUT 4-20 OUT 4-20

NOTE 23

* RTD2 = 200 OHM RTD, CHANNEL CONFIGURED FOR 20EBX1_AI_14

DEG.F

↑

EBX1_AI_15

EBX1_AO_1 EBX1_AO_2

FUEL CONTROL ANALOG I / O

ANA1- 51/52/53 ANA1- 54/55/16

+ / - / SHLD

+ / - / SHLD + / - / SHLD + / - / SHLD + / - / SHLD + / - / SHLD - / 24VDC(-) / SHLD + / - / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD

- / 24VDC(-) / SHLD + / - / SENSE/SHLD + / - / SENSE/SHLD

+ / - / SHLD + / - / SHLD

DWG NO: 20063-01-683143 REV: A SHEET 1 of 6 PAGE 1 OF 13

FC 1

ITEM

KAJI POWER ATLAS PC - 90/70 CONTROL R WITH VERSAMAX DISTRIBUTIVE I/O E V FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL

SIGNAL

IN/

SOURCE

OUT

TYPE

FUEL CONTROL - A N A L O G I/O

DISPLAY

RANGE

FAULT

RANGE

FAULT LIM

ACTION

UNIT

ALM

ALM

AL

S/P

UNIT

R/F

ACTION

S/D

S/D

S/D

S/P

UNIT

R/F

ACTION

CONTROL

COMMENTS

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

ADDRESS

TERMINAL

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS.

ATLAS PC - ANALOG COMBO BOARD (EBX2) 3-- 1 3-- 2

(SPARE) (SPARE)

3-3-3-3-3-3-3-3-3-3-3--

3 4 5 6 7 8 9 10 11 12 13

POWER TURBINE INLET TEMP (BOTTOM LT,T48-G)

GAS GEN COMP DISCH PRESS (PS3B) (CDP)

PT-2027 PT-2028 PT-8004B

3-3-3-3--

14 15 16 17

DELTA12

PT-2030

3-- 18 3-- 19

POWER TURBINE INLET TEMP (BOTTOM LT,T48-H) POWER TURBINE INLET TEMP (TOP LT,T48-I) POWER TURBINE INLET TEMP (TOP LT,T48-J) POWER TURBINE INLET TEMP (TOP LT,T48-K) GAS GEN COMP DISCH TEMP (T3C) DELTA12

TE-8044G TE-8044H TE-8044I TE-8044J TE-8044K TE-8038C TE-2035

(SPARE) TURB GAS FUEL SUPPLY PRESSURE TURBINE GAS FUEL MANIFOLD PRESS

(SPARE) GAS GEN COMPRESSOR INLET TEMP (T2B) TURB GAS FUEL SUPPLY TEMP B

(SPARE) (SPARE)

TE-8015B TE-2032B

IN IN

MAG MAG

IN IN IN IN IN IN IN IN IN IN IN

T/C T/C T/C T/C T/C T/C T/C T/C 4-20 4-20 4-20

IN IN IN IN

4-20 4-20 *RTD2 RTD

EBX2_DSS_1 EBX2_DSS_2

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

NOTE 9

DEG F

NOTE 10

DEG F

> ALARM

NOTE 10

DEG F

>

FSLO

-40/2000

-40/1000

0-800

-16/816

ALARM

DEG F

NOTE 12

DEG F

SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16 SEE NOTES 14,15,& 16

NOTE 12

400 DEG F

↑ ALARM

EBX2_AI_1 EBX2_AI_2 EBX2_AI_3 EBX2_AI_4 EBX2_AI_5 EBX2_AI_6

700 DEG F

↑ FSWM

EBX2_AI_7 EBX2_AI_8

0-750

10/740

NOTE 18

PSIG

0-800

-16/816

ALARM

PSIG

0-500

10/480

NOTE 17

PSIA

0-1000

-20/1020

ALARM

PSIG

NOTE 18 PSIG

ALARM

NOTE 18

EBX2_AI_9 EBX2_AI_10

NOTE 17

NOTE 17

EBX2_AI_11

EBX2_AI_12 EBX2_AI_13

-65/130

-70/140

NOTE 22

DEG F

NOTE 22

-40/400

-40/380

NOTE 23

DEG F

NOTE 23

NOTE 22 DEG.F

↑ ALARM

NOTE 23

* RTD2 = 200 OHM RTD, CHANNEL CONFIGURED FOR 20EBX2_AI_14

DEG.F

↑

OUT 4-20 OUT 4-20

EBX2_AI_15

EBX2_AO_1 EBX2_AO_2

ANA2- 57/58/59 ANA2- 60/61/62

+ / - / SHLD

ANA2ANA2ANA2ANA2ANA2ANA2ANA2ANA2ANA2ANA2ANA2-

1/2/3 4/5/6 7/8/9 10/11/12 13/14/15 16/17/18 19/20/21 22/23/24 26/27/28 29/30/31 32/33/34

+ / - / SHLD

ANA2ANA2ANA2ANA2-

35/37/38 39/41/42 45/44/43/46 49/48/47/50

- / 24VDC(-) / SHLD

ANA2- 51/52/53 ANA2- 54/55/16

+ / - / SHLD

+ / - / SHLD + / - / SHLD + / - / SHLD + / - / SHLD + / - / SHLD + / - / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD

- / 24VDC(-) / SHLD + / - / SENSE/SHLD + / - / SENSE/SHLD

+ / - / SHLD + / - / SHLD

NOTE FOR ANALOG SHEETS :---(A1) - "S" AFTER 4-20 IN TYPE COLUMN INDICATES 4-20 IS SOURCED FROM ANOTHER DEVICE. ALL OTHER INPUTS HAVE LOOP POWERED DEVICES. (A2) - ALL OTHER INPUTS HAVE LOOP POWERED DEVICES AND REQUIRES EXTERNAL POWER SUPPLY FOR LOOP POWER. FOR SMARTCORE BOARD (SMC): (A3) - ANALOG INPUTS (SMC_AI_1 THRU AI_6) CAN BE USED AS EITHER CURRENT OR VOLTAGE INPUT. (A4) - TYPICAL LOOP POWER CHANNEL 1 CONNECTION (4-20 IN): XMTR(+) = 24VDC(+), XMTR(-) = 27, 24VDC(-) = 29, SHIELD = 30, JUMPER 27 (VIN+) & 28 (IIN+). (A5) - TYPICAL SOURCE POWER CHANNEL 1 CONNECTION (4-20S IN): XMTR(+) = 27, XMTR(-) = 29, SHIELD = 30, JUMPER 27 (VIN+) & 28 (IIN+). (A6) - TYPICAL SOURCE POWER CHANNEL 1 CONNECTION (4-20S & 0-200S OUT): LOAD(+) = 65, LOAD(-) = 66, SHIELD = 67. FOR ANALOG COMBO BOARDS (EBX1 & EBX2 ): (A7) - FIRST 11 ANALOG INPUTS (EBX_AI_1 THRU AI_11) ARE SOFTWARE CONFIGURABLE 4-20mA OR THERMOCOUPLE. (A8) - LAST 4 ANALOG INPUTS (EBX_AI_12 THRU AI_15) ARE SOFTWARE CONFIGURABLE 4-20mA OR RTD. (A9) - CHANNELS 1 THRU 10 MUST BE CONFIGURED IN PAIRS (CHANNELS 1 & 2, 3 & 4, …) AND MUST BOTH BE CONFIGURED AS 4-20 mA INPUTS OR MUST BOTH BE CONFIGURED AS THERMOCOUPLE INPUTS; ANY UNUSED CHANNEL OF A PAIR, CHANNELS 1 THRU 10, MUST HAVE ITS INPUT SHORTED. (A10) - TYPICAL LOOP POWER CHANNEL 1 THRU 11 CONNECTION (4-20 IN): XMTR(+) = 24VDC(+), XMTR(-) = 1, 24VDC(-) = 2, SHIELD = 3. (A11) - TYPICAL SOURCE POWER CHANNEL 1 THRU 11 CONNECTION (4-20S IN): XMTR(+) = 1, XMTR(-) = 2, SHIELD = 3. (A12) - TYPICAL CHANNEL 12 THRU 15 RTD CONNECTION: (+) = 37, (-) = 36, RETURN(-) = 35, SHIELD = 38. (A13) - FOR 2-WIRE RTD CONNECTION, JUMPER (-) TO RETURN(-). (A14) - TYPICAL LOOP POWER CHANNEL 12 THRU 15 CONNECTION (4-20 IN): XMTR(+) = 24VDC(+), XMTR(-) = 35, 24VDC(-) = 37, SHIELD = 38. (A15) - TYPICAL SOURCE POWER CHANNEL 12 THRU 15 CONNECTION (4-20S IN): XMTR(+) = 35, XMTR(-) = 37, SHIELD = 38. (A16) - TYPICAL SOURCE POWER CHANNEL 1 CONNECTION (4-20S OUT): LOAD(+) = 51, LOAD(-) = 52, SHIELD = 53.

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

FUEL CONTROL ANALOG I / O

DWG NO: 20063-01-683143 REV: A SHEET 1 of 6 PAGE 2 OF 13

FC 1

ITEM

KAJI POWER ATLAS PC - 90/70 CONTROL R WITH VERSAMAX DISTRIBUTIVE I/O E V FUNCTION

SIGNAL

IN/

SOURCE

OUT

TYPE

FUEL CONTROL - A N A L O G I/O REVISION LIST ============== A INITIAL REVISION, REV.A 1-- 3 GAS FUEL HEATING VALUE AE-2015 IN 4-20S 1-- 4 GAS FUEL SPECIFIC GRAVITY AE-2014 IN 4-20S 3-- 10 TURB GAS FUEL SUPPLY PRESSURE PT-2027 IN 4-20 3-- 11 TURBINE GAS FUEL MANIFOLD PRESS PT-2028 IN 4-20 3-- 12 (SPARE) IN 4-20 2-- 16 ADDED COMMENTS TO CLARIFY THAT CHANNEL IS CONFIGURED FOR 200 OHM RTD 3-- 16 ADDED COMMENTS TO CLARIFY THAT CHANNEL IS CONFIGURED FOR 200 OHM RTD 1-- 7 MODIFY THE RANGE 4-20MA = 0-30 MW. 1-6-03 JTN 2-- 17 TURB GAS FUEL SUPPLY TEMP TE-2032 IN RTD 3-- 17 (SPARE) ===== END ====================

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL

DISPLAY

RANGE

FAULT

RANGE

FAULT LIM

ACTION

UNIT

ALM

ALM

AL

S/P

UNIT

R/F

ACTION

S/D

S/D

S/D

S/P

UNIT

R/F

ACTION

CONTROL

COMMENTS

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

ADDRESS

TERMINAL

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS.

DATE ===== 800-1100

820/1080

NOTE 6

0.2 / 2.2

-0.05 / 2.15

NOTE 6

0-750

10/740

NOTE 18

BTU/SCF

OPT-PART OF FUEL FLOW CALC. OPT-PART OF FUEL FLOW CALC.

PSIG

NOTE 18 PSIG

ALARM

NOTE 18

??? (T2A, TE-8015A) (T2B, TE-8015B) -40/400

-40/380

NOTE 23

DEG F

275 DEG.F

↑ ALARM

FUEL CONTROL ANALOG I / O

300 /325

DEG.F

↑

*

* 300 DEG.F =CDLO, 325 DEG.F = FSLO

6/3/02 RSP 6/3/02 RSP 7/19/02 RSP 7/19/02 RSP 7/19/02 RSP 8/20/02 RSP 8/20/02 RSP ???? 4/25/03RRK 4/25/03RRK

MAINMAINANA2ANA2ANA2-

27/29/30 31/33/34 22/23/24 26/27/28 29/30/31

ANA1- 49/48/47/50 ANA2- 49/48/47/50

+ / - / SHLD + / - / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD - / 24VDC(-) / SHLD

+ / - / SENSE/SHLD + / - / SENSE/SHLD

DWG NO: 20063-01-683143 REV: A SHEET 1 of 6 PAGE 3 OF 13

FC 2 R

KAJI POWER ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

E ITEM

SIGNAL

V

FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL

SOURCE

TRIP ACTION

FUEL CONTROL - D I S C R E T E I N P U T S

POINT

UNIT

ALM

ACTIVE

SWITCH

R/F

SIGNAL

WIRED

CONTROL

COMMENTS

CHANNEL

MTTB

TERMINAL

TERMINAL

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

ATLAS PC - SMARTCORE BOARD (SMC) 1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1--

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24

DELTA12 DELTA12 DELTA12 DELTA12 (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) SHUTDOWN FUEL AND NOX SUPPRESSION GEN BREAKER CLOSED (SPARE) ISOC./DROOP CONTROL SEQUENCER POWER SUPPLY FAILURE WATCH DOG TIMER STATUS FOR SEQUENCER (SPARE) TUR GAS FUEL UPSTREAM BLOCK VALVE CLOSED TUR GAS FUEL DOWNSTREAM BLOCK VALVE CLOSED (SPARE) (SPARE) (SPARE)

ZC- 2018 ZC- 2019 ZSC-2012 ZSC-2018

SD LIQ SD WATER STATUS/AL STATUS/AL

0 0 1 1

N.O. N.O. N.O. N.O.

SMC_BI_01 SMC_BI_02 1=VLV CLOSED, 0= OPEN - * VLV CLOSED = START OR CRANK PERMISSIVE

SMC_BI_03

1=VLV CLOSED, 0= OPEN - * VLV CLOSED = START OR CRANK PERMISSIVE

SMC_BI_04 SMC_BI_05 SMC_BI_06 SMC_BI_07 SMC_BI_08 SMC_BI_09 SMC_BI_10 SMC_BI_11 SMC_BI_12

K1 K229

FSLO CNTL

0 1

N.O. N.O.

K67 SEQ SH 3, 1-10 TDR1

CNTL FSLO

1 0 1/0

N.O. N.O. N.O.

0= DROOP, 1= ISOC

SMC_BI_16

0 = SEQUENCER POWER SUPPLY FAILURE

SMC_BI_17

0=WATCH DOG TIMER TINED OUT, 1=SEQ NORMAL

SMC_BI_18

1 1

N.O. N.O.

1=VLV CLOSED, 0= OPEN - * VLV CLOSED = START OR CRANK PERMISSIVE

SMC_BI_20

1=VLV CLOSED, 0= OPEN - * VLV CLOSED = START OR CRANK PERMISSIVE

SMC_BI_21

SMC_BI_13 SMC_BI_14

0=OPEN, 1=CLOSED

SMC_BI_15

STATUS/AL

SMC_BI_19

ZSC-2006 ZSC-2007

STATUS/AL STATUS/AL

SMC_BI_22 SMC_BI_23 SMC_BI_24 24VDC(-)

MAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAINMAIN-

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 25

POWER FOR DRY CONTACT 24VDC(+) MUST BE SUPPLIED EXTERNALLY

REVISION LIST ============== A INITIAL REVISION, REV.A CORRECTED ERRO ON TAG , CHANGED TAG FROM ZSC-2011 TO ZSC-2018 - TURB LIQ FUEL DOWNSTREAM BLOCK VALVE CLOSED

DATE ===== 9/13/02

=== END ============

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

FUEL CONTROL DISCRETE INPUTS

DWG NO: 20063-01-683143 REV: A SHEET 2 OF 6 PAGE 4 OF 13

FC 3 R

KAJI POWER ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

E ITEM

V

FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL

EXTERNAL

DEVICE

SIGNAL

CONTROLLED

TO

CNTL VOLTAGE

ACTIVE

CONTACT

SIGNAL

USED

CONTROL

COMMENTS

CHANNEL TERMINAL

EXT. RELAY BOX

CABLE

RELAY

OUTPUT

RELAY

NO.

BOX

TERM NUMBER

DESIG.

FUEL CONTROL - D I S C R E T E O U T P U T S

ATLAS PC - POWER SUPPLY MODULE ( PB_MOD)

1-- 1 1-- 2 1-- 3

+24 VDC INPUT +24 VDC COMMON INPUT EARTH GROUND

BATTERY

PS- 1 PS- 2 PS- 3

1-1-1-1-1-1-1-1-1-1-1-1--

TUR GAS FUEL UPSTREAM BLOCK VLV TUR GAS FUEL DOWNSTREAM BLOCK/VENT VLV (SPARE) SUMMARY CRITICAL SHUTDOWN WATCH DOG TIMER STATUS - FUEL CONTROL FUEL CONTROL POWER SUPPLY "OK" (SPARE) DELTA12 DELTA12 DELTA12 DELTA12 (SPARE)

SOV-2006 SOV-2007

TURB SKID

CRITL PATH SEQ SH 2, 1-13 SEQ SH 2, 1-14

TCP TCP

BATTERY

24VDC(+) POWER SUPPLY INPUT 24VDC(-) POWER SUPPLY COMMON INPUT GROUND COM/ NC/ NO

4 5 6 7 8 9 10 11 12 13 14 15

TURB SKID

24 VDC 24 VDC

1# (1#)

N.O. N.O.

OPT - ENERGIZED OPEN ,

PB_MOD_01

OPT - ENERGIZED OPEN FOR BLOCK , ENERGIZED CLOSEDFOR VENT

PB_MOD_02

24 VDC 24 VDC 24 VDC

0 1/0 0

N.O. N.O. N.O.

DPS3/DT - T45.4OVERTEMP TRIP POINT

PB_MOD_04

1= FC NORMAL, 0 = WATCH DOG TIMER TIMED OUT

PB_MOD_05

0 = FUEL CONTROL POWER SUPPLY FAILURE

PB_MOD_06

1 1 1# (1#)

N.O. N.O. N.O. N.O.

OPT - CONTROLS SOV-2009

PB_MOD_08

OPT - CONTROLS SOV-2010

PB_MOD_09

OPT

PB_MOD_10

OPT

PB_MOD_11

PB_MOD_03

TURB SKID

PB_MOD_07

SOV-2009 SOV-2010 SOV-2012 SOV-2011

TURB SKID TURB SKID TURB SKID TURB SKID

24 VDC 24 VDC 24 VDC 24 VDC

PB_MOD_12 24VDC(+) RELAY POWER 24VDC(-) RELAY POWER

PSPSPSPSPSPSPSPSPSPSPSPSPSPS-

8 9 10 11 12 13 14 15 16 17 18 19 22 23

W101 W101 W101 W101 W101 W101 W101 W101 W101 W101 W101 W101 W101 W101

U101U101U101U101U101U101U101U101U101U101U101U101-

1/ 2/ 3 4/ 5/ 6 7/ 8/ 9 10/ 11/ 12 13/ 14/ 15 16/ 17/ 18 19/ 20/ 21 22/ 23/ 24 25/ 26/ 27 27/ 28/ 29 30/ 31/ 32 34/ 35/ 36

K1 K2 K3 K4 K5 K6 K7 K8 K9 K10 K11 K12

NOTE: # IN ACTIVE SIGNAL COL. = POWER TO RELAY TO BE REMOVED IF CRITICAL SHUTDOWN PATH TRIPPED. ( ) IN ACTIVE SIGNAL COL.= RETURN WIRED THRU A15 SAFETY CIRCUIT.

REVISION LIST ============== A INITIAL REVISION, REV.A 1-- 11 SD/RESET GAS METERING VALVE DRIVER ZC-2001 1-- 12 SD/RESET LIQUID METERING VALVE DRIVER ZC-2018 1-- 13 SD/RESET TURB NOX WTR INJ METERING VLV DRIVER ZC-2019 1-- 14 (SPARE) === END ============

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

DATE ===== TURB SKID TURB SKID TURB SKID

24 VDC 24 VDC 24 VDC

1/0 1/0 1/0

N.O. N.O. N.O.

1=ENABLE 0=SHUTDOWN

1-0-1 = RESET

PB_MOD_08

1=ENABLE 0=SHUTDOWN

1-0-1 = RESET

PB_MOD_09

1=ENABLE 0=SHUTDOWN

1-0-1 = RESET

PB_MOD_10 PB_MOD_11

FUEL CONTROL DISCRETE OUTPUTS

PSPSPSPS-

15 16 17 18

W101 W101 W101 W101

U101U101U101U101-

7/16/02 RSP 7/16/02 RSP 7/16/02 RSP 7/16/02 RSP

K8 K9 K10 K11

DWG NO: 20063-01-683143 REV: A SHEET 3 OF 6 PAGE 5 OF 13

KAJI POWER ATLAS PC - 90/70 CONTROL R WITH VERSAMAX DISTRIBUTIVE I/O

FC 4

ITEM

E V FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL NO./

NETWORK

SIGNAL SOURCE

FUEL CONTROL - DEVICENET COMMUNICATION

SPC VSV BLEED DRIVER: (DEVICENET ADDRESS 2) ACTUATOR/ VALAVE INTERFACE (TOP) 1-- 1

TURB VSV ACT TORQ MOTOR

FCV-8073

SEE NOTE 26 & 27

1-- 2

TURB VSV XDCR EXICIT PWR

ZE-8073A/B

SEE NOTE 26 & 28

1-- 3 1-- 4

TURB VSV LVDT RETURN 1A (LEFT)

ZE-8073A

TURB VSV LVDT RETURN 1B (RIGHT)

ZE-8073B

SEE NOTE 26 & 27 SEE NOTE 26 & 28

1-1-1-1--

5 6 7 8

TURB VSV RESET IN

FROM ATLAS OUT

TURB VSV SHUTDOWN IN

FROM ATLAS OUT

NOT USED (TURB VSV ALARM IN )

FROM ATLAS OUT

TURB VSV SHUTDOWN OUT

TO ATLAS IN

1-1-1-1-1--

9 10 11 12 13

V-

DEVICE NET

CAN LOW

DEVICE NET

ACTUATOR/ VALAVE INTERFACE (BOTTOM)

CONTROL INTERFACE (TOP)

DEVICE NET

SHIELD

DEVICE NET

CAN HIGH

DEVICE NET

V+

DEVICE NET

POWER INPUT 1-- 14 1-- 15 1-- 16

24VDC+

BATTERY

24VDC-

BATTERY

CHASSIS GROUND

BATTERY

NIU DISCRETE OUTPUT (DEVICENET ADDRESS 6)

CONTROL RELAY

2222222222222222-

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

DISCRETE OUTPUT MODULE (SOLID STATE) - IC200MDL741 (I/O CARRIER KEYCODE: C2) SD/RESET GAS METERING VALVE DRIVER ZC-2001 TURB SKID DELTA12 ZC-2018 TURB SKID DELTA12 ZC-2019 TURB SKID (SPARE) (SPARE) DELTA12 K97 TURB SKID (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE)

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

POWER 24 VDC 24 VDC 24 VDC

24 VDC

ACTIVE CONTACT SIGNAL WIRED

ACTION

1/0 1/0 1/0

N.O. N.O. N.O.

1=ENABLE 0=SHUTDOWN

1-0-1 = RESET

1=ENABLE 0=SHUTDOWN

1-0-1 = RESET

1=ENABLE 0=SHUTDOWN

1-0-1 = RESET

1#

N.O.

CONTROLS SOV-2016 & SOV-2017

FUEL CONTROL DISTRIBUTIVE DISCRETE I/O

LOCATION MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB

DWG NO: 20063-01-683143 REV:A SHEET 4 OF 6 PAGE 6 OF 13

KAJI POWER ATLAS PC - 90/70 CONTROL R WITH VERSAMAX DISTRIBUTIVE I/O

FC 4

ITEM

E V FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL NO./

NETWORK

SIGNAL SOURCE

FUEL CONTROL - DEVICENET COMMUNICATION NOTE: N501 THRU N508 ARE RESERVED FOR FUEL CONTROL DISTRIBUTIVE I/O NODES. # IN ACTIVE SIGNAL COL. = POWER TO RELAY TO BE REMOVED IF CRITICAL SHUTDOWN PATH TRIPPED. ( ) IN ACTIVE SIGNAL COL.= RETURN WIRED THRU A15 SAFETY CIRCUIT. ALL RELAY COIL (-) TERMINALS SHOULD BE TIED TO 24VDC(-). PIN NUMBERS SHOWN IN CONTROL TERMINAL COLUMNS = (+) TERMINAL OF RELAY COILS.

1-1-1-1-1--

1 2 3 4 5

REVISION LIST ============== A INITIAL REVISION, REV.A TURB LIQ FUEL PRIMARY MANIFOLD DRAIN VLV TURB LIQ FUEL SECONDARY MANIFOLD DRAIN VLV (SPARE) TURB LIQ FUEL UPSTREAM BLOCK VALVE TURB LIQ FUEL DOWNSTREAM BLOCK VALVE MOVED COMM SKETCH TO LAYOUT DRAWING (683145) === END ============

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

DATE ===== K358 K359 SOV-2012 SOV-2018

TURB SKID TURB SKID TURB SKID TURB SKID

24 VDC 24 VDC 24 VDC 24 VDC

1 1 1# (1#)

N.O. N.O.

CONTROLS SOV-2009 CONTROLS SOV-2010

N.O. N.O.

FUEL CONTROL DISTRIBUTIVE DISCRETE I/O

1/1 1/1 1/1 1/1 1/1

7/16/02 RSP 7/16/02 RSP 7/16/02 RSP 7/16/02 RSP 7/16/02 RSP 3/21/03RRK

N501- A1

MTTB

N501- A2

MTTB

N501- A3

MTTB

N501- A4

MTTB

N501- A5

MTTB

DWG NO: 20063-01-683143 REV:A SHEET 4 OF 6 PAGE 7 OF 13

KAJI POWER FC 5 R ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL

ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

E V FUNCTION

DESTINATION

FUEL CONTROL - C O M M U N I C A T I O N S

COMMENTS

WIRE OR

SOFTWARE

CONTROL

CABLE #

ADDRESS

TERMINALS

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 6

ATLAS PC - SMARTCORE BOARD (SMC) 1-1-1-1-1-1-1-1-1-1--

1 2 3 4 5 6 7 8 9 10

PORT: SMC_SIO#1 ( RS232 OR RS422/485 ) SHIELD 422T (-) 422T (+) 422R (-) / 485(-) TERM RES(-) TERM RES(+) 422R(+) / 485(+) SIG GND 232 RXD 232 TXD

NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED

ATLAS PC - DEVICENET BOARD 2-2-2-2-2--

1 2 3 4 5

SMC_SIO #1 SMC_SIO #1 SMC_SIO #1 SMC_SIO #1 SMC_SIO #1 SMC_SIO #1 SMC_SIO #1 SMC_SIO #1 SMC_SIO #1 SMC_SIO #1

MAINMAINMAINMAINMAINMAINMAINMAINMAINMAIN-

102 101 100 99 98 97 96 95 94 93

DEVICENET-

J1-1 J1-2 J1-3 J1-4 J1-5

SEE SHEET 4 2817 2818

VCAN LOW SHIELD

DEVICENETDEVICENET-

2819 2820

CAN HIGH V+

DEVICENETDEVICENET-

ATLAS PC - COMMUNICATION ON CPU MODULE 3-- 1

ETHERNET #1 CONNECTION TO SEQUENCER

4-- 1

NOT USED ( COM1 )

SEQUENCER, SLOT 8

10 BASE T - CAT 5 CROSSOVER CABLE (CABLE SUPPLIED BY CUSTOMER)

W108

NOT USED

ATLAS PC - COMMUNICATION ON ETHERNET MODULE 5-- 1

ETHERNET #2 CONNECTION TO 4 PORT HUB

ETHHUB1, PORT 1

10 BASE T - CAT 5 CABLE (CABLE SUPPLIED BY CUSTOMER)

W120

REVISION LIST ============== A INITIAL REVISION, REV.A ===== END ====================

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

FUEL CONTROLCOMMUNICATIONS

DWG NO: 20063-01-683143 REV:A SHEET 5 OF 6 PAGE 8 OF 13

KAJI POWER

WORKSHEET, FUEL CONTROL

GE PACKAGED POWER, L.P.

ATLAS PC - 90/70 CONTROL

FC 6 R

WITH VERSAMAX DISTRIBUTIVE I/O

E V

WORKSHEET NOTES

ACTION CODES: FSLO = FAST STOP LOCKOUT WITHOUT MOTOR - IMMEDIATELY SHUTDOWN BY SHUTING OFF FUEL, SHUTDOWN STEAM/WATER, AND TRIP BREAKER (RESET FROM TURBINE CONTROL PANEL ONLY) FSWM = FAST STOP WITH MOTOR - FSLO, THEN ENGAGE STARTER FOR 7.5 MINUTES WHEN NGG REACHES 1700 RPM. (RESET FROM TURBINE CONTROL PANEL ONLY) = IF T48 IS NOT ABOVE 400 DEG F WHEN FSWM IS ACTIVATED THEN ONLY FSLO WILL OCCUR. F-SD = FAST SHUTDOWN (RESET FROM TURBINE CONTROL PANEL ONLY) CDLO = COOLDOWN LOCKOUT - SHED LOAD AND STEAM/WATER, TRIP BKR, IDLE FOR 5 MIN. IF RESET 'CLEARS SD DURING COOL DOWN PERIOD, CDLO IS ABORTED. = STARTER ENGAGED FOR 7.5 MINUTES WHEN XN25 DROPS TO 1700 RPM. (RESET FROM TURBINE CONTROL PANEL ONLY) = IF ON NAPHTHA FUEL, CDLO IS REPLACED WITH FSWM. INTLK = INTERLOCK (REQUIRED TO OPERATE) SD/STSY = SHUTDOWN STEAM SYSTEM ONLY (RESET FROM TURBINE CONTROL PANEL ONLY) SML = SLOW DECEL TO MIN LOAD - FAST LOAD SHED TO MIN LOAD IN 20 SEC (IF PROBLEM STILL EXISTS AFTER 3 MINUTES, DO CDLO) = (RESET FROM TURBINE CONTROL PANEL ONLY) SDTI = STEP DECEL TO IDLE (FUEL FLOW SHALL NOT GO BELOW 1300 PPH) (10 SECONDS AFTER ACHIEVING CORE IDLE FSLO) (RESET FROM TURBINE CONTROL PANEL ONLY) STATUS = STATUS OF I/O POINT CONTROL = INPUT OR OUTPUT REQUIRED TO CONTROL A DEVICE OR FUNCTION. ALARM = AUDIO AND VISUAL INDICATION OF A FAULT CONDITION.

ABBREVIATIONS

METRIC CONVERSIONS

OPT = OPTION - ONLY ITEMS THAT MAYBE DELTA 12

1 PSIG = 6.894757 KILOPASCALS (SAME FOR PSID)

NPOS = NOT PART OF STANDARD ( NOT INSTALLED - COST ADDER TO INSTALL)

1 DEG F = 1.8 DEG C + 32

JS = JOB SPECIFIC - MUST BE SPECIFIED

1 INCH = 25.4 mm

ON THE PDS TO USE

1 INCH/WG = 25.4 mm/WG

DELTA 12 = END DEVICES NOT SUPPLIED, BUT ALL WIRING

1 MIL = 25.4 MICROMETERS

FOR TCP, INTERCONNECTS, AND SKIDS TO

1 PSIG = 0.06894757 BAR

BE SUPPLIED.

1 CUBIC FOOT = 0.02831685 CUBIC METER

RTD = 100 OHM Pt RTD WITH EUROPEAN SPEC. CHAR.:

1 POUND = 0.453924 KILOGRAM

0.00385 OHMS/OHMS DEG C 100 OHMS AT 32 DEG F (0 DEG C).

THIS WORKSHEET BASED ON MID-IDM-2500-9

NOTE: NOTES ABOUT CORE ENGINE OPERATION MAY NOT REFLECT ACTUAL CORE PROGRAM IN USE, DUE TO UNSCHEDULED UPDATES TO THE CORE PROGRAM BY THE ENGINE MANUFACTURER. WHEN CONFLICTS IN NOTE INFORMATION EXIST, REFERENCE LATEST IDM, CONTROL SPEC., AND PERTINENT DOCUMENTS OF SUBJECT FOR RESOLUTION. IF REQUIRED INFORMATION NOT PRESENT IN NOTES, REFER TO ABOVE MENTIONED DOCUMENTS.

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683143 REV: A SHEET 6 OF 6 PAGE 9 OF 13

KAJI POWER

WORKSHEET, FUEL CONTROL

GE PACKAGED POWER, L.P.

ATLAS PC - 90/70 CONTROL

FC 6 R

WITH VERSAMAX DISTRIBUTIVE I/O

E V

WORKSHEET NOTES FUEL CONTROL NOTES: 1. NGG SPEED SENSORS: a. NGG RANGE FAULT LIMIT : Min. 1700 RPM WHEN T48 AVG > 400 DEG.F AND FUEL ON = TRUE; Min. 0 RPM WHEN T48 < 400 DEG.F ; Max. 11500 RPM b. LOSS OF 1 SIGNAL=ALARM ; LOSS OF BOTH SIGNALS = FSLO & DEFAULT TO 2000 RPM c. A DIFFERENCE >37.5 RPM BETWEEN NGG SENSORS = ALARM & SELECT HIGHER SENSOR 2. IF NGG SPEED IS NOT ABOVE 1700 RPM IN 20 SECONDS AFTER STARTER ENGAGEMENT THEN FSLO. 3A. IF NGG SPEED IS NOT ABOVE 4500 RPM 90 SECONDS AFTER IGNITION 'ON', FSLO. 3B. IF NGG SPEED IS NOT ABOVE 6800 RPM 120 SECONDS AFTER IGNITION 'ON', FSLO. 4. LMV FEEDBACK POSITION ERROR A. IF LMV FEED BACK IS > 3% AND NGG >1700RPM, ALARM B. IF LMV FEED BACK IS > 6% AND NGG >1700RPM, SML 5. NPT SPEED SENSORS: a. NPT RANGE FAULT LIMIT : Min. 1000 RPM WHEN NGG > 7000 RPM ; Min. 0 RPM WHEN NGG < 7000 RPM ; Max. 4500 RPM b. LOSS OF 1 SIGNAL=ALARM ; LOSS OF BOTH SIGNALS = FSLO & DEFAULT TO 1000 RPM IF NGG > 7000 RPM c. A DIFFERENCE > 40 RPM BETWEEN NPT SENSORS = ALARM & SELECT HIGHER SENSOR 6. INTENTIONALLY LEFT BLANK 7. TURBINE COMBUSTOR FALME DETECTORS a. IF ENGINE FLAME SENSOR OUTPUT > 2797 DEG F = INDICATION OF FLAME. IF SENSOR OUTPUT < 2781 DEG F (TUNEABLE BETWEEN 2725 TO 2790 DEG F) = LOSS OF FLAME. b. IF FLAME DETECTED OR LOSS OF 1 SENSOR AND FUEL HAS BEEN OFF, FAIL SIGNAL = FSLO c. LOSS OF 1 SIGNAL WITH FUEL ON = ALARM (FLAME NOT DETECTED ) d. LOSS OF 2 SIGNALS = FSLO e. LOSS OF FLAME AT POWER = FSLO 8. WX TRANSDUCER IS USED FOR ENGINE POWER LIMITER PER IDM/CONTROL SPEC. AND ALSO CAN BE ENABLED AS MW CONTROL OF THE UNIT WHEN UNIT IS IN PARALLEL OPERATION. 9. T48 a. T48 RANGE FAULT LIMIT : Min. 350 DEG.F WHEN NGG > 5000 RPM ; Min. -40 DEG.F WHEN NGG = 200 DEG.F = ALARM 10b. UNDER MIN . TEMPERATURE: IF T48AVG. FALLS < 400 DEG.F AFTER LAST T48 AVG. READING WAS > 400 DEG.F = FSLO 10c. UNDER MIN . TEMPERATURE (GAS FUEL) : IF T48AVG. < 400 DEG F FOR 10 SECONDS AFTER ENERGIZING FUEL AND IGNITORS = FSLO 10d. UNDER MIN . TEMPERATURE (LIQUID FUEL) : IF T48AVG. < 400 DEG F FOR 20 SECONDS AFTER ENERGIZING FUEL AND IGNITORS = FSLO 10e. . OVERTEMPERATURE: IF T48SEL > 1300 DEG.F WHEN NGG < 5000 RPM = FSLO

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683143 REV: A SHEET 6 OF 6 PAGE 10 OF 13

KAJI POWER

GE PACKAGED POWER, L.P.

WORKSHEET, FUEL CONTROL

ATLAS PC - 90/70 CONTROL

FC 6 R

WITH VERSAMAX DISTRIBUTIVE I/O

E V

WORKSHEET NOTES 10f. T48 OVERTEMPERATURE : ALARM

SHUTDOWN

ALARM

(FSLO)

SHUTDOWN (FSLO)

GAS FUEL : 3600 RPM POWER TURBINE:

GAS FUEL : 3000 RPM POWER TURBINE: DRY OPERATION : > 1540 DEG.F

> 1575 DEG.F

DRY OPERATION : > 1525 DEG.F

> 1575 DEG.F

T48 GAS FUEL WET TO 42 PPM NOX : > 1530 DEG.F T48 GAS FUEL WET TO 25/ 42 PPM NOX : > 1520 DEG.F

> 1565 DEG.F

T48 GAS FUEL WET TO 42 PPM NOX : > 1515 DEG.F

> 1565 DEG.F

> 1555 DEG.F

T48 GAS FUEL WET TO 25/ 42 PPM NOX : > 1505 DEG.F

> 1555 DEG.F

LIQUID FUEL : 3600 RPM POWER TURBINE:

GAS FUEL : 3000 RPM POWER TURBINE: DRY OPERATION : > 1565 DEG.F

> 1575 DEG.F

DRY OPERATION : > 1550 DEG.F

> 1575 DEG.F

T48 GAS FUEL WET TO 42 PPM NOX : > 1555 DEG.F T48 GAS FUEL WET TO 25/ 42 PPM NOX : > 1545 DEG.F

> 1565 DEG.F

T48 GAS FUEL WET TO 42 PPM NOX : > 1540 DEG.F

> 1565 DEG.F

> 1555 DEG.F

T48 GAS FUEL WET TO 25/ 42 PPM NOX : > 1530 DEG.F

> 1555 DEG.F

11. INTENTIONALLY LEFT BLANK 12. GAS GEN COMP DISCH TEMP (T3): a. LOSS OF 1 SIGNAL = ALARM & REMOVE FROM AVERAGE a. LOSS OF 2 SIGNAL = ALARM & REMOVE FROM AVERAGE c. DIFFERENCE BETWEEN TWO SIGNALS > 20°F = ALARM & SELECT HIGHER SENSOR 13. INTENTIONALLY LEFT BLANK 14. LOSS OF P2 SIGNAL = ALARM & DEFAULT TO 14.69 PSIA 15. INTENTIONALLY LEFT BLANK 16. INTENTIONALLY LEFT BLANK 17. PS3 (COMPRESSOR DISCH. PRESS) SENSORS a. LOSS OF 1 SIGNAL=ALARM ; LOSS OF BOTH SIGNALS = FSLO & DEFAULT TO LAST VALID VALUE

{NEED TO PUT STEAM LIMITS PER IDM (282 PSIA STEAM SD )}

b. IF DIFFERENCE BETWEEN TWO PS3 SENSORS IS > 10 PSIA = ALARM & SELECT HIGHER SENSOR. . c. IF DIFFEREENCE IS >15 PSIA FOR > 0.1 SEC = FSLO & DEFAULT TO HIGHER SENSOR. 18. GAS SUPPLY PRESSURE (PGAS) a. LOSS OF PGAS SIGNAL = DEFAULT TO LAST VALID VALUE AND ALARM. b. LOW SUPPLY PRESSURE ALARM : IF PGAS < 210 PSIG c. LOW SUPPLY PRESSURE SHUTDOWN : IF PGAS < 200 PSIG = FSWM d. HIGH SUPPLY PRESSURE ALARM : IF PGAS > 600 = ALARM e. HIGH SUPPLY PRESSURE SHUTDOWN : IF PGAS > 650 = FSWM 19. POWER TURBINE INLET PRESSURE (P48) a. LOSS OF P48 SIGNAL = ALARM & DEFAULT TO LAST VALID VALUE b. LOSS OF P48 PRESSURE TAP : IF NGG > 7200 RPM & P48SEL 18 DEG.F = ALARM & SELECT HIGHER SENSOR 1 sensor ?

23. FOR GAS FUEL SUPPLY TEMPS (TFUEL) a. LOSS OF 1 SIGNAL = ALARM b. LOSS OF BOTH SENSORS = FSLO & SET DEFAULT TO LAST GOOD VALUE c. DIFFERENCE BETEEN TWO SENSORS > 10 DEG.F = ALARM & SELECT HIGHER VALUE d. If TGAS > 275 deg F = ALARM e. If TGAS > 300 deg F = CDLO f. If TGAS > 325 deg F = FSLO 24. INTENTIONALLY LEFT BLANK 25. INTENTIONALLY LEFT BLANK 26. VSV TORQ MOTOR: a. VSV TORQ MOTOR FAILURE (SHORT OR OPEN) FOR > 0.5 SECONDS = SET VSVMA TO 0.0 mA, ALARM, SDTI, AND CDLO. b. TORQ MOTOR NULL SHIFT > 10 mA FOR > 5.0 SECONDS AND NGG > 4950 RPM AND CHANGE IN NGG < 150 RPM/SEC = ALARM. c. TORQ MOTOR NULL SHIFT > 15 mA FOR > 5.0 SECONDS AND NGG > 4950 RPM AND CHANGE IN NGG < 150 RPM/SEC = ALARM, SML. 27. VSV VALVE : a. VSV POSITION DISPLAY WILL DISPLAY THE AVERAGE OF THE 2 POSITION SENSORS. b. LOSS OF 1 VSV POSITION SIGNAL = REMOVE FROM THE AVERAGE AND ALARM. LOSS OF BOTH POSITION SENSORS = SDTI, ALARM, AND CDLO. c. DIFFERENCE OF > 6% BETWEEN POSITION SENSORS & FOR > 1.0 SECONDS & NGG > 4950 RPM = SDTI AND SELECT LOWER POSITION SENSOR d. WHEN POSITION DEMAND HAS > 10% ERROR FROM POSITION SELECTED FOR MORE THAN 1.0 SECOND AND NGG > 4950 RPM = SET VSVMA TO 0.0 mA AND ALARM, SDTI, AND CDLO. e. WHEN POSITION DEMAND HAS > 6% ERROR FROM POSITION SELECTED FOR MORE THAN 5.0 SECONDS AND NGG > 4950 RPM AND CHANGE IN NGG IS < 150RPM/SEC = ALARM. 28. INTENTIONALLY LEFT BLANK 29. INTENTIONALLY LEFT BLANK 30. INTENTIONALLY LEFT BLANK 31. INTENTIONALLY LEFT BLANK 32. INTENTIONALLY LEFT BLANK

A

REVISION LIST

DATE

=============

=====

INITIAL REVISION, REV.A NOTE 18C - GAS FUEL SUPPLY PRESSURE - CORRECTED LOW SHUTDOWN SETPOINT ACTION FROM SDTI TO SML

8/26/02 RSP

CHANGED NOTE 18b & 18c. - NEW SETPOINTS WERE ADDED AS PER F&ID

9/17/02 RSP

(Old note 18b: LOW SUPPLY PRESSURE ALARM : IF PGAS < 210 PSIA WHEN NGG 7000 RPM = ALARM)

9/17/02 RSP

(Old Note 18c. LOW SUPPLY PRESSURE SHUTDOWN : IF PGAS < 200 PSIA = SML )

9/17/02 RSP

ADD NOTE 4 FOR LMC POSITION ERROR CHANGED NOTE 18 PSIA TO PSIG ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683143 REV: A SHEET 6 OF 6 PAGE 12 OF 13

KAJI POWER

WORKSHEET, FUEL CONTROL

GE PACKAGED POWER, L.P.

ATLAS PC - 90/70 CONTROL

FC 6 R

WITH VERSAMAX DISTRIBUTIVE I/O

E V

WORKSHEET NOTES ========= END =============

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:07 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683143 REV: A SHEET 6 OF 6 PAGE 13 OF 13

GE PACKAGED POWER, L.P.

KAJI POWER

FUEL CONTROL LAYOUT

ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

© Copyright 2003 GE Packaged Power, L.P. All rights reserved. This drawing is the proprietary and/or confidential property of GE Packaged Power, L.P. and is loaned in strict confidence with the understanding that will not be reproduced nor used for any purpose except that for which it is loaned. It shall be immediately returned on demand and is subject to all other terms and conditions of any written agreement or purchase order that incorporates or relates to this drawing.

WOODWARD GOVERNOR ATLAS PC SYSTEM BASED ON THE FOLLOWING OPERATING CONDITIONS:

X -20 C 70 C -40 C

CONTINUOUS DUTY COGENERATION SERVICE OPERATING TEMPERATURE (MIN) OPERATING TEMPERATURE (MAX) STORAGE TEMPERATURE (MIN) (-40 C)

85 C 95 X 4

STORAGE TEMPERATURE (MAX) % HUMIDITY (NON CONDENSING) NON HAZARDOUS AREA SEISMIC ZONE (UBC)

WOODWARD GOVERNOR ATLAS PC SYSTEM PARTS LIST

QTY.

DESCRIPTION

PART NUMBER

1

ATLAS PC WITH SAC FUEL CONTROL (2 X 4) -------------------------------------------------------- 8273-076 24VDC LOW VOLTAGE INPUT SMARTCORE BOARD WITH ACTUATOR OUTPUTS 2 EBX ANALOG COMBO BOARDS DEVICENET COMMUNICATIONS DUAL ETHERNET COMMUNICATIONS

0

SERVO POSITION CONTROLLER DRIVER -------------------------------------------------------------- 8200-220 24VDC LOW VOLTAGE INPUT, SINGLE ACTUATOR / DUAL FEEDBACK, DEVICENET / ANALOG COMMUNICATIONS, SOFTWARE CONFIGURABLE

QTY. 1 1 1 1 1 2

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

FUEL CONTROL LAYOUT

DESCRIPTION

PART NUMBER

RELAY MODULE, ATLAS INTERFACE, 12 CHANNEL ------------------------------------------5441-699 CABLE, ATLAS 12 CHANNEL RELAY MODULE INTERFACE, 10 FT ---------------------- 5417-747 NETWORK INTERFACE UNIT, DEVICENET -------------------------------------------------------IC200DBI001 24VDC POWER SUPPLY (INSALLED ON DEVICENET NIU ----------------------------------- IC200PWR001 MODULE, DISCRETE OUTPUT, 24 VDC, POSITIVE LOGIC, 0.5 AMP, ---------------------- IC200MDL741 w/ESCP 16 CH TERMINATION RESISTOR, 121 OHM 1%, 1/4 WATT -------------------------------------------- RN60D1210F (MFG & PART# : VISHAY)

DRWG NO: 20063-01-683145 REV: A SHEET 1 OF 4

GE PACKAGED POWER, L.P.

KAJI POWER

FUEL CONTROL LAYOUT

ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

WOODWARD GOVERNOR ATLAS PC REMOTE MAIN CHASSIS LAYOUT

TOP OF CONTROLS 1 5 DEVICENET

BOTTOM OF CONTROLS

DB9 COM1

ETHERNET #1 (10/100 BASE-T)

ETHERNET #2 (10/100 BASE-T)

NOT USED

ANALOG COMBO (EBX2)

ANA2

ANALOG COMBO (EBX1)

ANA2 25

34

24

SMC BOARD (SMC)

25

24

51

50

MAIN 58

12

ANA1

ANA1 34

ANA2 13

ANA2 1

ANA1 13

12

39

38

MAIN

1

35 NO FIELD CONNECTIONS 5 4

MAIN

POWER 3 1

MAIN 27

26

POWER SUPPLY

MAIN 17

16

FAN 6 7

PS 8

MAIN 9

8

PS 15

16

MAIN 1

59

23

MAIN 70

71

82

ANA2 42

43

42

43

ANA1 35

SIO#1 DB9

50

ANA2 51 62

50

ANA1 51 62

92

MAIN 93 102

ANA1

MAIN 83

WOODWARD GOVERNOR ATLAS PC CABLE SCHEDULE CABLE NUMBER W108 W120 * W130 W101

CABLE TYPE

FUNCTION

ETHERNET CAT 5 SHIELDED CROSSOVER CABLE WITH RJ-45 CONNECTORS ETHERNET CAT 5 SHIELDED CABLE WITH RJ-45 CONNECTORS 2 PAIRS W/OVERALL SHIELD, 15/18 AWG - LOW CAP ( 12 pf/ft) (BELDEN 3082A OR EQUIV.) 12 CHANNEL RELAY MODULE INTERFACE

ETHERNET COMMUNICATION FROM ATLAS PC ETHERNET #1 TO SEQUENCER SLOT 8 ETHERNET COMMUNICATION FROM ATLAS PC ETHERNET #2 TO 4 PORT ETHERNET HUB PORT 1 (CUSTOMER SUPPLIED) DEVICE NET COMMUNICATION FROM ATLAS PC DEVICE NET TO SPC DRIVER ATLAS PC POWER SUPPLY (PS) TO 12 CHANNEL RELAY MODULE (U101)

* = CUSTOMER SUPPLIED

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

FUEL CONTROL LAYOUT

DRWG NO: 20063-01-683145 REV: A SHEET 2 OF 4

GE PACKAGED POWER, L.P.

KAJI POWER

FUEL CONTROL LAYOUT

ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

DEVICENET COMMUNICATION NETWORK RESERVED SOFTWARE ADRESSES:

AI & AO DI & DO NODE ADDRESS:

2

(1-64) (1-128)

1

6

NOT USED

NIU NO. 11 BUS ADDR. 30

3

4

5 (2)

ATLAS DEVICENET COMM PORT

NOT USED

4-20mA BACKUP 4-20mA BACKUP

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

11/1 DO SOLID ST N501 11/2 NODE NOT SUPPLIED 11/3 NODE NOT SUPPLIED 11/4 NODE NOT SUPPLIED 11/5 NODE NOT SUPPLIED 11/6 NODE NOT SUPPLIED 11/7 NODE NOT SUPPLIED 11/8 NODE NOT SUPPLIED

TERM

GS6 (GAS)

NOT USED

NOT USED RESISTORS

NIU SETUP NOTES: DIALS ARE AS FOLLOWS: OPTIONS DESCRIPTION NAU0123 BUS ADDR. TENS 0123456789 BUS ADDR. ONES N0123 BAUD (SET TO 3) Main Rack 1. PWR (IC200PWR001)

Setting

Default 2. Slot 0 (IC200GBI001) a. Settings - Data Rate bps 19200 - Parity Odd - Stop Bits 1 b. Network - Ser Bus Addr 1 - Baud Rate 153.6 Kbps - Report Faults Enabled - BSM Present No - BSM Contr. No - Out Time Def 2.5 sec - CPU Redund None - Duplex Default Off - BSM Forced Unforced - BSM State Bus A - Series 6 Ref 65535 - Config Protect Disabled c. Memory Default d. Pwr Consum Defaut

FUEL CONTROL LAYOUT

DRWG NO: 20063-01-683145 REV: A SHEET 3 OF 4

GE PACKAGED POWER, L.P.

KAJI POWER ATLAS PC - 90/70 CONTROL

FUEL CONTROL LAYOUT

WITH VERSAMAX DISTRIBUTIVE I/O

REVISION

A

DATE CHANGED

INITIAL REVISION, REV.A

END ================ END =======================

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

FUEL CONTROL LAYOUT

DRWG NO: 20063-01-683145 REV: A SHEET 4 OF 4

TYPE

RANGE

CONFIG

RANGE

RANGE FAULT LIM

SEQUENCER - D I S T R I B U T I V E A N A L O G I N P U T S / O U T P U T S

FAULT ACTION UNIT

ALM

ALM

S/P

UNIT

AL R/F

ACTION

S/D

S/D

S/D

S/P

UNIT

R/F

SOFTWARE

ACTION

COMMENTS

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

ADDRESS

CHANNEL

SOURCE

DISPLAY

NODE

NIU

SIGNAL FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER NETWORK

KAJI POWER ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

NIU/SLOT

ITEM

REVISION

SEQ 1

NODE ADDRESS & TERMINALS

SOURCE TERMINALS

NODE LOCATION

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS.

© Copyright 2003 GE Packaged Power, L.P. All rights reserved. This drawing is the proprietary and/or confidential property of GE Packaged Power, L.P. and is loaned in strict confidence with the understanding that will not be reproduced nor used for any purpose except that for which it is loaned. It shall be immediately returned on demand and is subject to all other terms and conditions of any written agreement or purchase order that incorporates or relates to this drawing.

11111111-

22222222-

33333333-

4444-

5555-

1 2 3 4 5 6 7 8

1 2 3 4 5 6 7 8

1 2 3 4 5 6 7 8

1 2 3 4

1 2 3 4

ANALOG INPUT MODULE - IC200ALG240 (I/O CARRIER KEYCODE: C7) EVAX 4-20S 0-100 EXCITER FIELD AMPS EVAX 4-20S 0-10 BUS VOLTAGE (52G) BVX 4-20S * 0-18 BUS FREQUENCY (52G) BFX 4-20S * 55-65 GEN VOLTAGE GVX 4-20S 0-18 DELTA12 CUSTOMER 4-20S 0-40 DELTA12 AE-2015 4-20 800-1100 DELTA12 AE-2014 4-20 0.2 / 2.2 EXCITER FIELD VOLTS

ANALOG INPUT MODULE - IC200ALG240 (I/O CARRIER KEYCODE: C7) PDT-4005 4-20 0-20 TURB LUBE OIL SCAVENGE FILTER D/P PDT-1007 4-20 0-30 TURBINE LUBE OIL TANK LEVEL LT-1002 4-20 0-100 TURB LUBE OIL SCAVENGE PRESS PT-1022 4-20 0-200 HYDRAULIC STARTER OIL TANK LEVEL LT-6001 4-20 0-100 DELTA12 LT-4064 4-20 0-8 DELTA12 LT-4065 4-20 0-8 DELTA12 GVX1 4-20S * AIR INLET FILTER D/P (COMBUSTION)

ANALOG INPUT MODULE - IC200ALG240 (I/O CARRIER KEYCODE: C7) PT-2021 4-20 0-100 DELTA12 PDT-2020 4-20 0-30 DELTA12 CE-4066 4-20 0-500 DELTA12 CE-4067 4-20 0-500 DELTA12 BVX1 4-20S * 0-18 DELTA12 BFX1 4-20S * 55-65 DELTA12 BVX2 4-20S * 0-18 DELTA12 BFX2 4-20S * 55-65 DELTA12

ANALOG OUTPUT MODULE - IC200ALG331 (I/O CARRIER KEYCODE: D7) SOV-6019 4-20 0-100 (SPARE) 4-20 (SPARE) 4-20 (SPARE) 4-20

HYD. STARTER PUMP PISTON CNTRL VLV

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) TE-1013 RTD -40/400 HYDRAULIC STARTER OIL TANK TEMP TE-6003 RTD -40/400 HYDRAULIC STARTER OIL RETURN TEMP TE-6002 RTD -40/400 (SPARE) RTD TURBINE LUBE OIL TANK TEMP

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

x10 x100 x10 x10 x10 x10 x1 x100

x10 x10 x10 x10 x10 x100 x100 x10

x10 x10 x1 x1 x10 x10 x10 x10

x10

-2/102 -0.2/10.2 * -0.4/18.4 * 53.7/66.3 -0.4/18.4 -0.8/40.8 794/1106 -0.05 / 2.15

-0.4/20.4 -0.6/30.6 -2/102 -4/204 -2/102 -0.2/8.2 -0.2/8.2 *

-2/102 0.6/30.6 -10/510 -10/510 * -0.4/18.4 * 53.7/66.3 * -0.4/18.4 * 53.7/66.3

-----

ALARM ALARM ALARM ALARM ALARM ALARM NOTE 5 NOTE 5

ALARM ALARM ALARM ALARM ALARM ALARM ALARM ALARM

ALARM ALARM ALARM ALARM ALARM ALARM ALARM ALARM

-----

VDC ADC KVAC HZ KVAC MW

NOTE 1

BTU/SCF

IN WC PSID % PSIG % IN IN KVAC

PSIG PSID Uohms Uohms KVAC HZ KVAC HZ

5 2*BSLN 83/59 110 91/73 7.25/1.75 7.25/1.75

10 25 110 110

IN WC PSID % PSIG % IN IN

PSIG PSID Uohms Uohms

↑ ↑ ↑↓ ↑ ↑↓ ↑↓ ↑↓

↓

ALARM ALARM ALARM

8 IN WC ↑ CDLO 2.5*BSLN PSID ↑ STI 53 % ↓ FSLO

ALARM ALARM

*ALARM

69 0.75 0.75

5/60

% IN IN

PSIG

↓ ↓ ↓

*START SD ALM/SD PUMP ALM/SD PUMP

↓↑ FSWM

↑ ALARM ↑ ALARM ↑ ALARM

NOTE 4 NOTE 4

%

-48/408 -48/408 -48/408

ALARM DEG F ALARM DEG F ALARM DEG F

DEG F DEG F DEG F

↓ ALARM ↓↑ ALARM ↑ ALARM

190

SEQUENCER DISTRUBITIVE ANALOG I/O

DEG F

↑ START SD

TCP

N301- B16/B15

-/ 24VDC(-)

01

1

N301- A4/A3

3

01

2

N301- A8/A7

FOR MANUAL SYNC, * 50HZ=0-15 -.3/15.3 KVAC

%AI0003

1/1

3

01

3

N301- A12/A11

FOR MANUAL SYNC, * 50HZ=45-55 44.1/56.1 HZ

%AI0004

1/1

3

01

4

N301- A16/A15

FOR MANUAL SYNC OPT-NPOS-JS- PART OF MW CTRL OPT - DLE ONLY OPT - DLE ONLY

%AI0005

1/1

3

01

5

N301- B4/B3

%AI0006

1/1

3

01

6

%AI0007

1/1

3

01

7

1/1

3

01

8

INIT BSLN = 10, MIN BSLN = 5 SEE NOTE 2 SEE NOTE 3 OPT - EVAP COOLER OPT - EVAP COOLER OPT-NPOS-JS- GSU * RANGE MAY VARY

%AI0008

TCP TCP TCP TCP TCP

TCP

POWER, 24VDC(+)

N301- A18

TCP

POWER, 24VDC(-)

N301- A17

TCP

%AI0009

1/2

3

02

1

N302- A4/A3

-/ 24VDC(-)

%AI0010

1/2

3

02

2

N302- A8/A7

-/ 24VDC(-)

TCP

%AI0011

1/2

3

02

3

N302- A12/A11

-/ 24VDC(-)

TCP

%AI0012

1/2

3

02

4

N302- A16/A15

-/ 24VDC(-)

TCP

%AI0013

1/2

3

02

5

N302- B4/B3

-/ 24VDC(-)

TCP

%AI0014

1/2

3

02

6

N302- B8/B7

-/ 24VDC(-)

TCP

%AI0015

1/2

3

02

7

N302- B12/B11

-/ 24VDC(-)

TCP

1/2

3

02

8

N302- B16/B15

-/ 24VDC(-)

%AI0016

TCP

TCP

POWER, 24VDC(+)

N302- A18

TCP

POWER, 24VDC(-)

N302- A17

TCP

OPT - LIQ * START PERMISSIVE OPT - LIQ OPT - EVAP COOLER OPT - EVAP COOLER

%AI0025

1/3

3

03

1

N303- A4/A3

-/ 24VDC(-)

%AI0026

1/3

3

03

2

N303- A8/A7

-/ 24VDC(-)

TCP

%AI0027

1/3

3

03

3

N303- A12/A11

-/ 24VDC(-)

TCP

%AI0028

1/3

3

03

4

N303- A16/A15

-/ 24VDC(-)

TCP

OPT-NPOS-JS; 52G SYNC, * SCALE CAN VARY

%AI0029

1/3

3

03

5

N303- B4/B3

TCP

OPT-NPOS-JS; 52G SYNC, * 50HZ=45-55 44.1/56.1 HZ

%AI0030

1/3

3

03

6

N303- B8/B7

OPT-NPOS-JS; 52G SYNC, * SCALE CAN VARY

%AI0031

1/3

3

03

7

N303- B12/B11

OPT-NPOS-JS; 52G SYNC, * 50HZ=45-55 44.1/56.1 HZ

%AI0032

1/3

3

03

8

N303- B16/B15

+/+/+/+/-

4 ma = ZERO SPEED, 20 ma = FULL SPEED

70 70/180 180

-/ 24VDC(-)

3

1/1

SEE NOTE 26 SEE NOTE 26 & NOTE 28

TCP

TCP TCP TCP

POWER, 24VDC(+)

N302- A18

TCP

POWER, 24VDC(-)

N302- A17

TCP

%AQ0001

1/4

3

04

1

N304- B1/B2

-/ 24VDC(-)

%AQ0002

1/4

3

04

2

N304- B5/B6

-/ 24VDC(-)

TCP

%AQ0003

1/4

3

04

3

N304- B9/B10

-/ 24VDC(-)

TCP

1/4

3

04

4

N304- B13/B14

-/ 24VDC(-)

%AQ0004

x10 x10 x10 x10

N301- B12/B11

1/1

%AI0002

ALARM ALARM

TCP

N301- B8/B7

+/+/+/+/+/+/-

%AI0001 FOR GEN OVERVOLTAGE PROTECTION SEE NOTE 1

TCP

TCP

POWER, 24VDC(+)

N304- B18

TCP

POWER, 24VDC(-)

N304- B17

TCP

%AI0017

1/5

3

05

1

N305- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

%AI0018

1/5

3

05

2

N305- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

TCP TCP

%AI0019

1/5

3

05

3

N305- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

TCP

%AI0020

1/5

3

05

4

N305- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

TCP

DWG NO: 20063-01-683146 REV: A SHEET 1 PAGE 1 OF 22

TYPE

RANGE

CONFIG

RANGE

RANGE FAULT LIM

SEQUENCER - D I S T R I B U T I V E A N A L O G I N P U T S / O U T P U T S

6666-

1 2 3 4

77777777-

1 2 3 4 5 6 7 8

88888888-

9999-

1 2 3 4 5 6 7 8

1 2 3 4

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) TE-4082 RTD -40/400 DELTA12 TE-4028 RTD -40/400 DELTA12 TE-2024 RTD -40/400 (SPARE) RTD AIR INLET FILTER TEMP (AMBIENT)

A A A A A A A A

ANALOG INPUT MODULE - IC200ALG240 (I/O CARRIER KEYCODE: C7) NODE NOT SUPPLIED CUSTOMER 4-20S 0-32 NODE NOT SUPPLIED CUSTOMER 4-20S -0.5/0.5 NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

ANALOG INPUT MODULE - IC200ALG240 (I/O CARRIER KEYCODE: C7) PDT- 4007 4-20 0-8 TURB LUBE OIL SUPPLY FILTER D/P PDT-1006 4-20 0-30 DELTA12 PDT-7003 4-20 0-35 TURB LUBE OIL SUPPLY PRESSURE PT-1021 4-20 0-100 DELTA12 PT-8061 4-20 0-200 HIGH PRESSURE- RECOUP PT-8064 4-20 0-200 TURB GAS FUEL SUPPLY FLOW RATE FT-2000 4-20 0-345 (SPARE) TURBINE ROOM D/P

FAULT ACTION UNIT

ALM

ALM

S/P

UNIT

x10 x10 x10 x10

-48/408 -48/408 -48/408

x100 x100

-0.6/32.6 -0.52/0.52

x100 x10 x10 x10 x1 x1 x1

-0.16/8.16 -0.6/30.6 -0.7/35.7 -2/102 -4/204 -4/204 -7/352

ALARM DEG F ALARM DEG F ALARM DEG F

43 35/130 140

DEG F

DEG F DEG F

ALARM

IN WC

ALARM

PSID

ALARM

PSID

FSLO

PSIG

ALARM

PSIA

ALARM

PSIA

0.1 IN WC 20 PSID 30 PSID NOTE 6

S/D

UNIT

R/F

SOFTWARE

COMMENTS

ACTION

↓ ALARM ↓↑ ALARM ↑ ALARM

160

DEG F

↓

ADDRESS

BSLN+20

DEG F

DEG F

BSLN+20

DEG F

DEG F

BSLN+20

DEG F

DEG F

BSLN+20

DEG F

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) TE-1027A RTD -40/400 TURB LUBE OIL SUPPLY TEMP (A) TE-1028A RTD -40/400 TURB LUBE OIL ACCY GB SCAV TEMP (B) TE-1023B RTD -40/400 TURB LUBE OIL "A" SUMP SCAV TEMP (B) TE-1024B RTD -40/400

x10 x10 x10 x10

-48/408 -48/408 -48/408 -48/408

ALARM ALARM ALARM ALARM

DEG F

BSLN+20

DEG F

DEG F

20/190

DEG F

DEG F

BSLN+20

DEG F

DEG F

BSLN+20

DEG F

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) TE-1025B RTD -40/400 TURB LUBE OIL "C" SUMP SCAV TEMP (B) TE-1026B RTD -40/400 TURB LUBE OIL "D" SUMP SCAV TEMP (B) TE-1027B RTD -40/400 TURB LUBE OIL SUPPLY TEMP (B) TE-1028B RTD -40/400

x10 x10 x10 x10

-48/408 -48/408 -48/408 -48/408

ALARM ALARM ALARM ALARM

DEG F DEG F DEG F DEG F

BSLN+20

DEG F

BSLN+20

DEG F

BSLN+20

DEG F

20/190

DEG F

NODE ADDRESS & TERMINALS

SOURCE TERMINALS

NODE LOCATION

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS.

↑ SDTI

OPT - AUX SKID - SEE NOTE 34 OPT - LIQ

%AI0021

1/6

3

06

1

N306- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

%AI0022

1/6

3

06

2

N306- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

TCP

%AI0023

1/6

3

06

3

N306- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

TCP

%AI0024

1/6

3

06

4

N306- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

TCP

+/+/+/+/+/+/+/+/-

TCP

NPOS - JS

%AI0129

3/1

3

07

1

N307- A4/A3

NPOS - JS - *4mA = 0.5 LEAD; 20mA = 0.5 LAG

%AI0130

3/1

3

07

2

N307- A8/A7

%AI0131

3/1

3

07

3

N307- A12/A11

%AI0132

3/1

3

07

4

N307- A16/A15

%AI0133

3/1

3

07

5

N307- B4/B3

%AI0134

3/1

3

07

6

N307- B8/B7

%AI0135

3/1

3

07

7

N307- B12/B11

%AI0136

3/1

3

07

8

N307- B16/B15

POWER, 24VDC(+)

N307- A18

POWER, 24VDC(-)

N307- A17

TCP

TCP TCP TCP TCP TCP TCP TCP

ALARM

%AI0193

4/1

1

08

1

N108- A4/A3

-/ 24VDC(-)

↑ ALARM

%AI0194

4/1

1

08

2

N108- A8/A7

-/ 24VDC(-)

MTTB

%AI0195

4/1

1

08

3

N108- A12/A11

-/ 24VDC(-)

MTTB

%AI0196

4/1

1

08

4

N108- A16/A15

-/ 24VDC(-)

MTTB

%AI0197

4/1

1

08

5

N108- B4/B3

-/ 24VDC(-)

MTTB

%AI0198

4/1

1

08

6

N108- B8/B7

-/ 24VDC(-)

MTTB

%AI0199

4/1

1

08

7

N108- B12/B11

-/ 24VDC(-)

MTTB

4/1

1

08

8

N108- B16/B15

-/ 24VDC(-)

OPT - DLE ONLY

↑ ALARM ALARM

NOTE 6

NOTE 6

NOTE 8

CDLO

OPT - DLE+6STAGE ONLY

%AI0200

DEG F

TURB LUBE OIL "B" SUMP SCAV TEMP (B)

S/D

S/P

OPT - SAC ONLY - CRT TO DISPLAY PPH/SCFM

ALARM ALARM ALARM ALARM

11- 1 11- 2 11- 3 11- 4

S/D

ALARM ACFM

-48/408 -48/408 -48/408 -48/408

TURB LUBE OIL "D" SUMP SCAV TEMP (A)

ACTION

ALARM MVAR ALARM *

x10 x10 x10 x10

10- 1 10- 2 10- 3 10- 4

R/F

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) TE-1023A RTD -40/400 TURB LUBE OIL "A" SUMP SCAV TEMP (A) TE-1024A RTD -40/400 TURB LUBE OIL "B" SUMP SCAV TEMP (A) TE-1025A RTD -40/400 TURB LUBE OIL "C" SUMP SCAV TEMP (A) TE-1026A RTD -40/400 TURB LUBE OIL ACCY GB SCAV TEMP (A)

AL

CHANNEL

SOURCE

DISPLAY

NODE

NIU

SIGNAL FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER NETWORK

KAJI POWER ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

NIU/SLOT

ITEM

REVISION

SEQ 1

↑ ↑ ↑ ↑

ALARM

BSLN+40

DEG F

ALARM

BSLN+40

DEG F

ALARM

BSLN+40

DEG F

ALARM

BSLN+40

DEG F

↑ ↓↑ ↑ ↑

ALARM

BSLN+40

DEG F

ALARM

*

DEG F

ALARM

BSLN+40

DEG F

ALARM

BSLN+40

DEG F

↑ ↑ ↑ ↓↑

ALARM

BSLN+40

DEG F

ALARM

BSLN+40

DEG F

ALARM

BSLN+40

DEG F

ALARM

*

DEG F

↑ ↑ ↑ ↑

SML SML SML SML

↑ ↓↑ ↑ ↑

SML SML SML SML

↑ ↑ ↑ ↓↑

SML SML SML SML

INIT BSLN =280, INIT BSLN =280, INIT BSLN =280, INIT BSLN =280,

MTTB

MTTB

POWER, 24VDC(+)

N108- A18

MTTB

POWER, 24VDC(-)

N108- A17

MTTB

MAX BSLN =300 MAX BSLN =300 MAX BSLN =300 MAX BSLN =300

%AI0201

4/2

1

09

1

N109- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

%AI0202

4/2

1

09

2

N109- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MTTB

%AI0203

4/2

1

09

3

N109- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MTTB

%AI0204

4/2

1

09

4

N109- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MTTB

MTTB

MTTB

INIT BSLN =280, MAX BSLN =300

%AI0205

4/3

1

10

1

N110- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

* 6800 RPM OR >200 DEGF

%AI0206

4/3

1

10

2

N110- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MTTB

INIT BSLN =280, MAX BSLN =300 INIT BSLN =280, MAX BSLN =300

%AI0207

4/3

1

10

3

N110- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MTTB

%AI0208

4/3

1

10

4

N110- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MTTB

INIT BSLN =280, MAX BSLN =300 INIT BSLN =280, MAX BSLN =300 INIT BSLN =280, MAX BSLN =300

%AI0209

4/4

1

11

1

N111- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

MTTB

%AI0210

4/4

1

11

2

N111- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MTTB

%AI0211

4/4

1

11

3

N111- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MTTB

* 6800 RPM OR >200 DEGF

%AI0212

4/4

1

11

4

N111- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MTTB

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3)

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

SEQUENCER DISTRUBITIVE ANALOG I/O

DWG NO: 20063-01-683146 REV: A SHEET 1 PAGE 2 OF 22

TYPE

RANGE

CONFIG

RANGE

RANGE FAULT LIM

FAULT ACTION UNIT

ALM

ALM

S/P

UNIT

AL R/F

ACTION

S/D

S/D

S/D

S/P

UNIT

R/F

SEQUENCER - D I S T R I B U T I V E A N A L O G I N P U T S / O U T P U T S 12- 1 MAG CHIP DET-TUR LUBE OIL ACCY GB SCAV MCD-1060 RTD 0-300 12- 2 MAG CHIP DET-TUR LUBE OIL "A" SUMP SCAV MCD-1061 RTD 0-300 12- 3 MAG CHIP DET-TUR LUBE OIL "B" SUMP SCAV MCD-1062 RTD 0-300 12- 4 MAG CHIP DET-TUR LUBE OIL "C" SUMP SCAV MCD-1063 RTD 0-300

x10 x10 x10 x10

-6/306 -6/306 -6/306 -6/306

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5 ALARM OHMS * 75 OHMS ↓ ALARM ALARM OHMS * 75 OHMS ↓ ALARM ALARM OHMS * 75 OHMS ↓ ALARM ALARM OHMS * 75 OHMS ↓ ALARM

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) MCD-1064 RTD 0-300 TURBINE ROOM AIR OUTLET TEMP. TE-4001 RTD -40/400 TURBINE ROOM AIR INLET TEMP. TE-4054 RTD -40/400 DELTA12 TE-2077B RTD -40/400

x10 x10 x10 x10

-6/306 -48/408 -48/408 -48/408

ALARM *ALARM *ALARM ALARM

OHMS DEG F DEG F DEG F

* 75 200 140 140

OHMS DEG F DEG F DEG F

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) TE-4090 RTD -40/400 (SPARE) RTD -40/400

x10 x10

-48/408 -48/408

ALARM DEG F

0/125

DEG F

x10 x10

-48/408

ALARM DEG F

x10 x10 x10

-1.2/61.2 -0.6/30.6 -2/102

13- 1 13- 2 13- 3 13- 4

MAG CHIP DET-TUR LUBE OIL "D" SUMP SCAV

14- 1 14- 2

MTTB CABINET AIR TEMP

14- 3 14- 4

DELTA12

15- 1 15- 2 15- 3 15- 4 15- 5 15- 6 15- 7 15- 8

16- 1 16- 2 16- 3 16- 4 16- 5 16- 6 16- 7 16- 8

TE-2077A

(SPARE)

RTD RTD

-40/400

ANALOG INPUT MODULE - IC200ALG240 (I/O CARRIER KEYCODE: C7) NODE NOT SUPPLIED FT-2002 4-20S 0-60 NODE NOT SUPPLIED PDT-2073B 4-20 0-30 NODE NOT SUPPLIED PT-2074B 4-20 0-100 NODE NOT SUPPLIED 4-20 NODE NOT SUPPLIED FT-2003 4-20S 0-60 NODE NOT SUPPLIED PDT-2073A 4-20 0-30 NODE NOT SUPPLIED PT-2074A 4-20 0-100 NODE NOT SUPPLIED PT-2071 4-20 0-1000

x10 x10 x10 x1

-1.2/61.2 -0.6/30.6 -2/102 -20/1020

ALARM GPM ALARM PSID ALARM PSIG ALARM ALARM ALARM ALARM

GPM PSID PSIG PSIG

140

25 10/55

DEG F

PSID PSIG

NOTE 9 25 PSID 10/55 PSIG 800 PSIG

↓

150 150

↑ ALARM

↑ ALARM ↓↑ ALARM

↑ ALARM ↓↑ ALARM ↑ ALARM

150

5/60

5/60 950

18- 1 18- 2 18- 3 18- 4

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

DEG F

PSIG

PSIG PSIG

-48/408 -48/408 -48/408 -48/408

ALARM ALARM ALARM ALARM

DEG F DEG F DEG F DEG F

SEQUENCER DISTRUBITIVE ANALOG I/O

& TERMINALS

SOURCE TERMINALS

NODE LOCATION

↑ CDLO ↑ SD WTR INJ

%AI0213

4/5

1

12

1

N112- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

* SEE NOTE 7

%AI0214

4/5

1

12

2

N112- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MTTB

* SEE NOTE 7

%AI0215

4/5

1

12

3

N112- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MTTB

* SEE NOTE 7

%AI0216

4/5

1

12

4

N112- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MTTB

* SEE NOTE 7

%AI0217

4/6

1

13

1

N113- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

MTTB

* TURN ENCL VENT FAN B IF APPLICABLE

%AI0218

4/6

1

13

2

N113- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MTTB

* TURN ENCL VENT FAN B IF APPLICABLE

%AI0219

4/6

1

13

3

N113- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MTTB

SAC ONLY

%AI0220

4/6

1

13

4

N113- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MTTB

%AI0221

4/7

1

14

1

N114- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

MTTB

%AI0222

4/7

1

14

2

N114- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

↑

↓↑

↓↑ ↑

SD WTR INJ

MTTB

%AI0223

4/7

1

14

3

N114- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MTTB

%AI0224

4/7

1

14

4

N114- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MTTB

%AI0257

5/1

1

15

1

N115- A4/A3

+/-

MTTB

%AI0258

5/1

1

15

2

N115- A8/A7

-/ 24VDC(-)

MTTB

SD WTR INJ

%AI0259

5/1

1

15

3

N115- A12/A11

-/ 24VDC(-)

MTTB

%AI0260

5/1

1

15

4

N115- A16/A15

-/ 24VDC(-)

MTTB

%AI0261

5/1

1

15

5

N115- B4/B3

+/-

MTTB

%AI0262

5/1

1

15

6

N115- B8/B7

-/ 24VDC(-)

MTTB

SD WTR INJ SD WTR INJ

%AI0263

5/1

1

15

7

N115- B12/B11

-/ 24VDC(-)

MTTB

%AI0264

5/1

1

15

8

N115- B16/B15

-/ 24VDC(-)

MTTB

MTTB

SAC ONLY

OPT-CRT TO DISPLAY GPM & PPH OPT OPT - > 10 PSIG - START PERMISSIVE OPT- CRT TO DISPLAY GPM & PPH OPT OPT - > 10 PSIG - START PERMISSIVE OPT

POWER, 24VDC(+)

N115- A18

POWER, 24VDC(-)

N115- A17

MTTB

%AI0265

5/2

1

16

1

N116- A4/A3

-/ 24VDC(-)

%AI0266

5/2

1

16

2

N116- A8/A7

-/ 24VDC(-)

MTTB

%AI0267

5/2

1

16

3

N116- A12/A11

-/ 24VDC(-)

MTTB

%AI0268

5/2

1

16

4

N116- A16/A15

-/ 24VDC(-)

MTTB

%AI0269

5/2

1

16

5

N116- B4/B3

-/ 24VDC(-)

MTTB

%AI0270

5/2

1

16

6

N116- B8/B7

-/ 24VDC(-)

MTTB

%AI0271

5/2

1

16

7

N116- B12/B11

-/ 24VDC(-)

MTTB

5/2

1

16

8

N116- B16/B15

-/ 24VDC(-)

MTTB

MTTB

%AI0272

x10 x10 x10 x10

NODE ADDRESS

* SEE NOTE 7

↓↑ ALARM

ANALOG INPUT MODULE - IC200ALG240 (I/O CARRIER KEYCODE: C7) 4-20 MODULE NOT SUPPLIED 4-20 MODULE NOT SUPPLIED 4-20 MODULE NOT SUPPLIED 4-20 MODULE NOT SUPPLIED 4-20 MODULE NOT SUPPLIED 4-20 MODULE NOT SUPPLIED 4-20 MODULE NOT SUPPLIED 4-20

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) AC#1 CORE TEMP INTERIOR TE-4016A RTD -40/400 AC#1 CORE TEMP EXTERIOR TE-4015A RTD -40/400 AC#2 CORE TEMP INTERIOR TE-4016B RTD -40/400 AC#2 CORE TEMP EXTERIOR TE-4015B RTD -40/400

DEG F DEG F

ADDRESS

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS.

ALARM

↑ *ALARM ↑ *ALARM ↑ ALARM

MODULE NOT SUPPLIED

17- 1 17- 2 17- 3 17- 4

SOFTWARE

COMMENTS

ACTION

CHANNEL

SOURCE

DISPLAY

NODE

NIU

SIGNAL FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER NETWORK

KAJI POWER ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

NIU/SLOT

ITEM

REVISION

SEQ 1

POWER, 24VDC(+)

N116- A18

POWER, 24VDC(-)

N116- A17

%AI273

5/3

1

17

1

N117- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

%AI274

5/3

1

17

2

N117- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MTTB

%AI275

5/3

1

17

3

N117- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MTTB

%AI276

5/3

1

17

4

N117- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MTTB

5/4

1

18

1

N118-

MTTB

5/4

1

18

2

N118-

MTTB

5/4

1

18

3

N118-

MTTB

5/4

1

18

4

N118-

MTTB

DWG NO: 20063-01-683146 REV: A SHEET 1 PAGE 3 OF 22

TYPE

RANGE

CONFIG

RANGE

RANGE FAULT LIM

SEQUENCER - D I S T R I B U T I V E A N A L O G I N P U T S / O U T P U T S

FAULT ACTION UNIT

ALM

ALM

S/P

UNIT

AL R/F

ACTION

S/D

S/D

S/D

S/P

UNIT

R/F

SOFTWARE

COMMENTS

ACTION

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

ADDRESS

CHANNEL

SOURCE

DISPLAY

NODE

NIU

SIGNAL FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER NETWORK

KAJI POWER ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

NIU/SLOT

ITEM

REVISION

SEQ 1

NODE ADDRESS & TERMINALS

SOURCE TERMINALS

NODE LOCATION

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS.

19- 1 19- 2 19- 3 19- 4

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

5/5

1

19

1

N119-

MTTB

5/5

1

19

2

N119-

MTTB

5/5

1

19

3

N119-

MTTB

5/5

1

19

4

N119-

MTTB

20- 1 20- 2 20- 3 20- 4

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

5/6

1

20

1

N120-

MTTB

5/6

1

20

2

N120-

MTTB

5/6

1

20

3

N120-

MTTB

5/6

1

20

4

N120-

MTTB

21- 1 21- 2 21- 3 21- 4

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

5/7

1

21

1

N121-

MTTB

5/7

1

21

2

N121-

MTTB

5/7

1

21

3

N121-

MTTB

5/7

1

21

4

N121-

MTTB

22- 1 22- 2 22- 3 22- 4

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

5/8

1

29

1

N129-

MTTB

5/8

1

29

2

N129-

MTTB

5/8

1

29

3

N129-

MTTB

5/8

1

29

4

N129-

MTTB

%AI0385

7/1

2

22

1

N222- A4/A3

-/ 24VDC(-)

%AI0386

7/1

2

22

2

N222- A8/A7

-/ 24VDC(-)

MGTB

%AI0387

7/1

2

22

3

N222- A12/A11

-/ 24VDC(-)

MGTB

%AI0388

7/1

2

22

4

N222- A16/A15

-/ 24VDC(-)

MGTB

%AI0389

7/1

2

22

5

N222- B4/B3

-/ 24VDC(-)

MGTB

%AI0390

7/1

2

22

6

N222- B8/B7

-/ 24VDC(-)

MGTB

%AI0391

7/1

2

22

7

N222- B12/B11

-/ 24VDC(-)

MGTB

7/1

2

22

8

N222- B16/B15

-/ 24VDC(-)

MGTB

MGTB

ANALOG INPUT MODULE - IC200ALG240 (I/O CARRIER KEYCODE: C7) 23- 1 GEN AIR INLET FILTER D/P (DE) PDT-4008 4-20 0-10 23- 2 GEN AIR INLET FILTER D/P (NDE) PDT-4009 4-20 0-10 23- 3 GEN LUBE OIL FILTER D/P PDT-0015 4-20 0-30 23- 4 GEN LUBE OIL SUPPLY PRESSURE PT-0026 4-20 0-100 23- 5 GEN LUBE OIL TANK LEVEL LT-0001 4-20 0-100 23- 6 A GEN LUBE OIL RUNDOWN TANK LEVEL (DE) LT-0041 4-20 0-100 23- 7 A GEN LUBE OIL RUNDOWN TANK LEVEL (NDE) LT-0042 4-20 0-100 23- 8 A DELTA12 PT-0050 4-20 0-100

x100 x100 x10 x10 x10 x10 x10 x10

-0.2/10.2 -0.2/10.2 -0.6/30.6 -2/102 -2/102 -2/102 -2/102 -2/102

IN WC BSLN+1.0 IN WC BSLN+1.0 PSID 20 NOTE 10 PSIG NOTE 10 ALARM % 90/63 ALARM % NOTE 13 ALARM % NOTE 13 ALARM PSIG 10

IN WC ↑ IN WC ↑ PSID ↑ PSIG % ↑↓ % ↑ % ↑ PSIG ↓

ALARM ALARM

INTERLK INTERLK

ALARM

x10 x10 x10 x10

-48/408 -48/408 -48/408 -48/408

ALARM ALARM ALARM ALARM

DEG F DEG F DEG F DEG F

270 270 270 270

DEG F DEG F DEG F DEG F

↑ ↑ ↑ ↑

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) TE-4022B RTD -40/400 GEN STATOR WINDING PHASE T3 TEMP (B) TE-4023B RTD -40/400 GEN LUBE OIL TANK TEMP TE-0020 RTD -40/400 GEN LUBE OIL SUPPLY TEMP TE-0025 RTD -40/400

x10 x10 x10 x10

-48/408 -48/408 -48/408 -48/408

ALARM ALARM ALARM ALARM

DEG F DEG F DEG F DEG F

270 270 70 160

DEG F DEG F DEG F DEG F

↑ ALARM ↑ ALARM

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) 26- 1 GEN BEARING TEMP (DE) TE-0021 RTD -40/400 26- 2 A GEN BEARING OIL DRN TEMP (DE) TE-0036 RTD -40/400 26- 3 GEN BEARING TEMP (NDE) TE-0023 RTD -40/400 26- 4 A GEN BEARING OIL DRN TEMP (NDE) TE-0035 RTD -40/400

x10 x10 x10 x10

-48/408 -48/408 -48/408 -48/408

ALARM ALARM ALARM ALARM

DEG F DEG F DEG F DEG F

197 189 197 189

DEG F DEG F DEG F DEG F

GEN STATOR WINDING PHASE T1 TEMP (A)

25- 1 25- 2 25- 3 25- 4

GEN STATOR WINDING PHASE T2 TEMP (B)

↓

PSIG % NOTE 13 % NOTE 13 % 5 PSIG

NOTE 10 ALARM

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) TE-4021A RTD -40/400 GEN STATOR WINDING PHASE T2 TEMP (A) TE-4022A RTD -40/400 GEN STATOR WINDING PHASE T3 TEMP (A) TE-4023A RTD -40/400 GEN STATOR WINDING PHASE T1 TEMP (B) TE-4021B RTD -40/400

24- 1 24- 2 24- 3 24- 4

OPT - INIT BSLN =1.75, MAX BSLN =2.0 OPT - INIT BSLN =1.75, MAX BSLN =2.0

ALARM

ALARM ALARM ALARM ALARM

55

↓ ↓ ↓ ↓

FSLO CDLO CDLO FSLO

SEE NOTE 12 OPT-SEE NOTE 13 OPT-SEE NOTE 13 OPT - NPOS - JS

N222- A17

FSLO FSLO FSLO FSLO

SEE NOTE 11 SEE NOTE 11 SEE NOTE 11 SEE NOTE 11

%AI0393

7/2

2

23

1

N223- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

%AI0394

7/2

2

23

2

N223- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MGTB

%AI0395

7/2

2

23

3

N223- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MGTB

%AI0396

7/2

2

23

4

N223- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MGTB

290 290

DEG F DEG F

↑ FSLO ↑ FSLO

SEE NOTE 11 SEE NOTE 11

%AI0397

7/3

2

24

1

N224- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

MGTB

%AI0398

7/3

2

24

2

N224- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MGTB

%AI0399

7/3

2

24

3

N224- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MGTB

%AI0400

7/3

2

24

4

N224- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MGTB

%AI0401

7/4

2

25

1

N225- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

MGTB

%AI0402

7/4

2

25

2

N225- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MGTB

%AI0403

7/4

2

25

3

N225- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MGTB

%AI0404

7/4

2

25

4

N225- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MGTB

DEG F

↑ CDLO

↑ ↑ ↑ ↑

203 194 203 194

DEG F DEG F DEG F DEG F

↑ ↑ ↑ ↑

ALARM

POWER, 24VDC(-)

↑ ↑ ↑ ↑

190

ALARM

N222- A18

DEG F DEG F DEG F DEG F

↑ ALARM

ALARM

POWER, 24VDC(+)

290 290 290 290

ALARM

ALARM

%AI0392

MGTB

FSLO FSLO FSLO FSLO

SEE NOTE 11 OPT SEE NOTE 11 OPT

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3)

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

SEQUENCER DISTRUBITIVE ANALOG I/O

DWG NO: 20063-01-683146 REV: A SHEET 1 PAGE 4 OF 22

TYPE

RANGE

CONFIG

RANGE

RANGE FAULT LIM

FAULT ACTION UNIT

ALM

ALM

S/P

UNIT

AL R/F

ACTION

S/D

S/D

S/D

S/P

UNIT

R/F

SOFTWARE

SEQUENCER - D I S T R I B U T I V E A N A L O G I N P U T S / O U T P U T S 27- 1 GEN EXHAUST AIR TEMP TE-4030 RTD -40/400 27- 2 GEN EXCITER EXHAUST AIR TEMP TE-4031 RTD -40/400 27- 3 DELTA12 TE-4097 RTD -40/400 27- 4 DELTA12 TE-4098 RTD -40/400

x10 x10 x10 x10

-48/408 -48/408 -48/408 -48/408

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5 ALARM DEG F 200 DEG F ↑ ALARM 220 DEG F ↑ CDLO ALARM DEG F 200 DEG F ↑ ALARM 220 DEG F ↑ CDLO ALARM DEG F ALARM DEG F

28- 1 28- 2 28- 3 28- 4

ANALOG INPUT MODULE - IC200ALG620 (I/O CARRIER KEYCODE: D3) MGTB CABINET AIR TEMP TE-4091 RTD -40/400 (SPARE) RTD (SPARE) RTD (SPARE) RTD

x10 x10 x10 x10

-48/408

ALARM DEG F

29- 1 29- 2 29- 3 29- 4

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

0/125

DEG F

↓↑ ALARM

COMMENTS

ACTION

ADDRESS

CHANNEL

SOURCE

DISPLAY

NODE

NIU

SIGNAL FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER NETWORK

KAJI POWER ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

NIU/SLOT

ITEM

REVISION

SEQ 1

NODE ADDRESS & TERMINALS

SOURCE TERMINALS

NODE LOCATION

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS. %AI0405

7/5

2

26

1

N226- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

%AI0406

7/5

2

26

2

N226- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MGTB MGTB

OPT- TEWAC GEN OPT- TEWAC GEN

%AI0407

7/5

2

26

3

N226- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MGTB

%AI0408

7/5

2

26

4

N226- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MGTB

SEE NOTE 32

%AI0409

7/6

2

27

1

N227- A1/A2/A3/A4

S(+) / +/ -/ RTN(-)

MGTB

%AI0410

7/6

2

27

2

N227- A5/A6/A7/A8

S(+) / +/ -/ RTN(-)

MGTB

%AI0411

7/6

2

27

3

N227- A9/A10/A11/A12

S(+) / +/ -/ RTN(-)

MGTB

%AI0412

7/6

2

27

4

N227- A13/A14/A15/A16

S(+) / +/ -/ RTN(-)

MGTB

7/7

2

28

1

N228-

MGTB

7/7

2

28

2

N228-

MGTB

7/7

2

28

3

N228-

MGTB

7/7

2

28

4

N228-

MGTB

NOTE: FOR ANALOG SHEETS ---FOR ANALOG INPUT 4-20 mA MODULES (IC200ALG240) WITH TERMINAL BLOCKS IC200CHS022 THE FOLLOWING EXISTS: FOR ANALOG INPUT 4-20 mA MODULES (IC200ALG240) WITH I/O CARRIER IC200CHS022 THE FOLLOWING EXISTS: (A1) - "S" AFTER 4-20 IN TYPE COLUMN INDICATES 4-20 IS SOURCED FROM ANOTHER DEVICE. (A2) - ALL OTHER INPUTS HAVE LOOP POWERED DEVICES AND REQUIRE EXTERNAL POWER SUPPLY FOR LOOP POWER. (A3) - BOTH NEGATIVE TERMINALS IINn- & VINn- (A3/A2, A7/A6, A11/A10, A15/A14, B3/B2, B7/B6, B11/B10 & B15/B14) OF THE CHANNEL SHOULD BE CONNETCTED TOGETHER FOR BEST ACCURACY ON CURRENT RANGES. (A4) - TYPICAL LOOP POWER CONNECTION (4-20): XMTR(+) = 24VDC(+), XMTR(-) = A4, 24VDC(-) = A3, SHIELD = IE BAR. (A5) - TYPICAL SOURCE POWER CONNECTION (4-20S): XMTR(+) = A4, XMTR(-) = A3, SHIELD = IE BAR. FOR ALL RTD MODULES (IC200ALG620) WITH TERMINAL BLOCKS IC200CHS022 THE FOLLOWING EXISTS: (A6) - TYPICAL RTD HOOKUP CONNECTION : SOURCE 1(+) = A1, (+) = A2, (-) = A3, RETURN(-) = A4, SHIELD = IE BAR FOR ANALOG OUTPUT 4-20 mA MODULES (IC200ALG331) WITH I/O CARRIER IC200CHS022 THE FOLLOWING EXISTS: (A6) - TYPICAL LOOP POWER CURRENT SOURCE CONNECTION (4-20): LOAD(+) = 24VDC(+), LOAD(-) = B1, 24VDC(-) = B2, SHIELD = IE BAR. FOR RTD MODULES (IC200ALG620) WITH I/O CARRIER IC200CHS022 THE FOLLOWING EXISTS: (A7) - TYPICAL RTD CONNECTION: SOURCE(+) = A1, (+) = A2, (-) = A3, RETURN(-) = A4, SHIELD = IE BAR. (A8) - FOR 3-WIRE RTD CONNECTION, JUMPER SOURCE(+) TO +. (A9) - FOR 2-WIRE RTD CONNECTION, JUMPER SOURCE(+) TO + AND RETURN(-) TO -. (A10) - IF RTD IS NOT INSTALLED, JUMPER SOURCE(+) TO RETURN(-).

NOTE: FOR ALL SHEETS ---NETWORK INTERFACE UNIT (NIU) REQUIRES VERSAMAX POWER SUPPLY MODULE ( IC200PWR002) & NEED THE FOLLOWING: GROUND 24 VDC 11 Watts, Inrush Current : 20 AMP @24VDC, 25A @30VDC 24VDC COM

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

SEQUENCER DISTRUBITIVE ANALOG I/O

DWG NO: 20063-01-683146 REV: A SHEET 1 PAGE 5 OF 22

TYPE

RANGE

CONFIG

RANGE

RANGE FAULT LIM

SEQUENCER - D I S T R I B U T I V E A N A L O G I N P U T S / O U T P U T S SERIAL 1 SERIAL 2 SHIELD IN SHIELD OUT

FAULT ACTION UNIT

ALM

ALM

S/P

UNIT

AL R/F

ACTION

S/D

S/D

S/D

S/P

UNIT

R/F

SOFTWARE

COMMENTS

ACTION

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

ADDRESS

CHANNEL

SOURCE

DISPLAY

NODE

NIU

SIGNAL FUNCTION

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER NETWORK

KAJI POWER ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

NIU/SLOT

ITEM

REVISION

SEQ 1

NODE ADDRESS & TERMINALS

SOURCE TERMINALS

NODE LOCATION

REFER TO NOTE AT THE END OF SHEET FOR DETAILS ON TERMINALS, SENSOR WIRING & SHIELDS.

A1 A2 Ain Aout

NODES 1 THRU 39 = ANALOG NODES 40 THRU 59 = DISCRETE INPUTS NODES 60 THRU 79 = DISCRETE OUTPUTS

REVISION LIST ============= A INITIAL REVISION, REV.A 23- 6 23- 7

DATE =====

ADDED GEN LUBE OIL RUNDOWN TANK LEVEL (DE) LT-0041 (N2-22-6, %AI0390) GEN LUBE OIL RUNDOWN TANKS LOW LOW (NDE) LT-0042 (N2-22-7, %AI0391) CORRECTED ERROR ON POWER TERMINALS FOR ANALOG INPUT MODULE - IC200ALG240 - CHANGED "B18" TO "A18" (24VDC+) & "B17" TO "A17" (24VDC-) ON MODULES N302, N301, N108, N115, N116 & N222

15- 6 15- 1 15- 5

CHANGED SETPOINTS TO 25 PSID ALARM ( WAS 25 PSID WTR INJ SD) - TURB NOX WATER INJ FILTER D/P PDT-2073 ( PER FID CHANGE & MEETING WITH TUY HUYNH ) CHANGED COMMENTS FROM " CRT TO DISPLAY PPH " TO "CRT TO DISPLAY GPM & PPH" FOR TURB LIQ FUEL SUPPLY FLOW RATE FT-2002 ( FID MEETING TUY HUYNH) CHANGED COMMENTS FROM " CRT TO DISPLAY PPH " TO "CRT TO DISPLAY GPM & PPH" FOR TURB NOX WATER INJ SUPPLY FLOW RATE FT-2003 ( FID MEETING TUY HUYNH) MODIFIED SETPOINTS FOR ITEM 2-3, 2-5, 23-5, 23-6 & 23-7 ( TANK LEVELS - ADDED SETPOINTS IN % )

2-- 3 2-- 5 23- 5 23- 6 23- 7 14- 1 28- 1 14- 1 28- 1 2- 2 7- AL A 23- 6 A 23- 7 A 23- 8 A 26- 2 A 26- 4 A

TURBINE LUBE OIL TANK LEVEL

LT-1002

HYDRAULIC STARTER OIL TANK LEVEL

LT-6001

GEN LUBE OIL TANK LEVEL

LT-0001

GEN LUBE OIL RUNDOWN TANK LEVEL (DE)

LT-0041

GEN LUBE OIL RUNDOWN TANK LEVEL (NDE)

LT-0042

4-20 4-20 4-20 4-20 4-20

0-29.6 0-22.6 0-29.1 0-100 0-100

-0.6/30.2 -0.5/23.1 -0.6/29.7 -2/102 -2/102

ALARM ALARM ALARM ??? ???

INCH INCH INCH % %

↑↓ ALARM ↑↓ ALARM ↑↓ ALARM

NOTE 2 INCH NOTE 3 INCH NOTE 12 INCH

NOTE 2 INCH ↓ NOTE 3 INCH ↓ NOTE 12 INCH ↓

FSLO *START SD

FSLO

NOTE 2 NOTE 3 NOTE 12

%AI0011 %AI0013

%AI0389 %AI0390 %AI0391

CHANGED LOWER ALARM SETPOINTS FROM 0 DEG.F TO 32 DEG.F, MTTB CABINET AIR TEMP TE-4090 ( MATCHED WITH VERSAMAX ENVIORMENT SPEC) CHANGED ALARM SETPOINTS FROM 0/135 DEG.F TO 32/125 DEG.F, MGTB CABINET AIR TEMP TE-4091 ( MATCHED WITH VERSAMAX ENVIORMENT SPEC) CHANGED LOWER ALARM SETPOINTS FROM 32 DEG.F TO 0 DEG.F, MTTB CABINET AIR TEMP TE-4090 CHANGED LOWER ALARM SETPOINTS FROM 32 DEG.F TO 0 DEG.F, MGTB CABINET AIR TEMP TE-4091 PDT-1007 MODIFIED CDLO SD TO STI SD PER IDM ADDED NODE AND PF/VAR CONTROL I/O GEN LUBE OIL RUNDOWN TANK LEVEL (DE)

LT-0041

GEN LUBE OIL RUNDOWN TANK LEVEL (NDE)

LT-0042

(SPARE) GEN BEARING OIL DRN TEMP (DE) GEN BEARING OIL DRN TEMP (NDE) ====== END =====================

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

TE-0036 TE-0035

4-20 4-20 4-20 RTD RTD

0-100 0-100

x10 x10

-2/102 -2/102

ALARM ALARM

% %

NOTE 13 NOTE 13

↑ INTERLK ↑ INTERLK

% %

NOTE 13 NOTE 13

% %

↓ ↓

CDLO CDLO

SEE NOTE 13 SEE NOTE 13

%AI0390 %AI0391 %AI0392

-40/400 -40/400

x10 x10

-48/408 -48/408

ALARM DEG F ALARM DEG F

189 189

DEG F DEG F

↑ ALARM ↑ ALARM

194 194

SEQUENCER DISTRUBITIVE ANALOG I/O

DEG F DEG F

↑ FSLO ↑ FSLO

%AI0402 %AI0404

8/28/02 RSP 8/28/02 RSP 9/3/02 RSP 9/13/02 RSP 9/13/02 RSP 9/13/02 RSP 9/17/02 RSP 1/2 9/17/02 RSP A12/A11 1/2 9/17/02 RSP B4/B3 7/1 9/17/02 RSP B4/B3 7/1 9/17/02 RSP B8/B7 7/1 9/17/02 RSP B12/B11 9/19/02 RSP 9/19/02 RSP 10/7/02 RSP 9/19/02 RSP 2/28/03 8/7/03RRK PER LX EMAIL 7/1 8/7/03RRK PER LX EMAIL 7/1 8/7/03RRK PER LX EMAIL 7/1 8/7/03RRK PER LX EMAIL 7/4 8/7/03RRK PER LX EMAIL 7/4 8/7/03RRK PER LX EMAIL

-/ 24VDC(-) -/ 24VDC(-)

-/ 24VDC(-)

TCP TCP

MGTB

-/ 24VDC(-)

MGTB

-/ 24VDC(-)

MGTB

-/ 24VDC(-)

MGTB

-/ 24VDC(-)

MGTB

-/ 24VDC(-)

MGTB

S(+) / +/ -/ RTN(-)

MGTB

S(+) / +/ -/ RTN(-)

MGTB

DWG NO: 20063-01-683146 REV: A SHEET 1 PAGE 6 OF 22

KAJI POWER ATLAS PC - 90/70 CONTROL

SOURCE

ACTION

POINT

UNIT

ALM ACTIVE

SWITCH

R/F

WIRED

SEQUENCER - DISTRIBUTIVE DISCRETE INPUTS (DI MODULE - IC200MDL640 - I/O CARRIER KEYCODE: B4) 1111111111111111-

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 A 16

22222222222222223333333333333333-

FIRE/GAS MONITOR SD FIRE/GAS MONITOR FAILURE ALARM L.E.L. - TURB ROOM SD L.E.L. - TURB ROOM FIRE SUPPRESSANT AGENT RELEASED GEN BREAKER OPEN GEN BREAKER CLOSED BUS/UTILITY BREAKER OPEN BUS/UTILITY BREAKER CLOSED VIBRATION SUMMARY ALARM VIBRATION SUMMARY SD VIB SYS MALFUNCTION

DELTA12 START SKID MOTOR STARTER AUX CONTACT

FPP FPP FPP FPP FPP K230 K229 K232 K231 VIB-SYS VIB-SYS VIB-SYS FSL-4062 FSL-4063 CUSTOMER MCC

FSLO ALARM ALARM FSLO FSLO STATUS STATUS STATUS STATUS ALARM SDTI ALM ALARM (NOTE) ALARM (NOTE) CNTRL CNTRL

1 2 3 4 5 A 6 7 A 8 9 10 11 12 13 14 15 16

GEN AVR SUMMARY ALARM GEN AVR EXCITATION TRIPPED GEN MANUAL EXCIT/AUTO AVR SELECTED GEN EXCITAION LIMITER OPERATION GEN EXCITER DIODE FAILURE GEN AVR FAULT GENERATOR ROTOR GROUND FAULT GEN ZERO SPEED SWITCH BATTERY CHARGER FAILURE - DC (24VDC) BATTERY CHARGER FAILURE - AC (24VDC) LO BATTERY VOLTAGE (24VDC) BATTERY CHARGER GROUND FAULT (24VDC) IGPS 52G TRIP IGPS FAULT ALARM IGPS FAILURE IGPS POWER SUPPLY ALARM

AVR AVR AVR AVR AVR AVR RGF A17 CHG. CHG. CHG. CHG. IGPS IGPS IGPS IGPS

ALARM ALARM STATUS ALARM ALARM ALARM ALARM CNTRL ALARM ALARM SML ALARM ALARM ALARM CDLO ALARM

1 2 3 4 5 6 7 8 9 10 11 12 13 A 14 A 15 16

LOCAL EMERGENCY STOP REMOTE EMERGENCY STOP CRITICAL PATH SHUTDOWN AUTO/MANUAL SYNC * GEN 86 TRIP TURBINE EXTERNAL OVERSPEED LOCAL/ REMOTE CONTROL SELECTION RAISE XNSD SPEED LOWER XNSD SPEED RAISE XNSD SPEED (MANUAL) LOWER XNSD SPEED (MANUAL) LOSS OF DC POWER ON SYSTEM

ES3 ESTR-1,2/ESGR3 CRITICAL PATH SS/K100 86G SSW1,2 LRS DSM DSM SAS/CUSTOMER SAS/CUSTOMER PRC/SW-GR XSH-0043A XSH--0043B

FSLO FSLO FSLO CONTROL FSWM FSLO

DELTA12 DELTA12

TURBINE/ GEN LUBE OIL HEAT EXCHANGER FAN "A" VIBRATION TURBINE/ GEN LUBE OIL HEAT EXCHANGER FAN "B" VIBRATION

DELTA12 DELTA12

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

CALORIMETER

PSS

STATUS/CNTL

CNTRL CNTRL CNTRL CNTRL ALARM ALARM (NOTE) ALARM (NOTE) ALARM ALARM

SIGNAL

CHANNEL

FUNCTION

TRIP

NODE

SIGNAL

NETWORK

WITH VERSAMAX DISTRIBUTIVE I/O NIU/SLOT

REVISION

SEQ 2

ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

%I0001 %I0002 %I0003 %I0004 %I0005 %I0006 %I0007 %I0008 %I0009 %I0010 %I0011 %I0012 %I0013 %I0014 %I0015 %I0016

1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7 1/7

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

40 40 40 40 40 40 40 40 40 40 40 40 40 40 40 40

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

%I0017 %I0018 %I0019 %I0020 %I0021 %I0022 %I0023 %I0024 %I0025 %I0026 %I0027 %I0028 %I0029 %I0030 %I0031 %I0032

1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8 1/8

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

41 41 41 41 41 41 41 41 41 41 41 41 41 41 41 41

%I0129 %I0130 %I0131 %I0132 %I0133 %I0134 %I0135 %I0136 %I0137 %I0138 %I0139 %I0140 %I0141 %I0142 %I0143 %I0144

2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1 2/1

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

42 42 42 42 42 42 42 42 42 42 42 42 42 42 42 42

SOFTWARE

COMMENTS

NAMES

NODE ADDRESS

NODE

& TERMINAL NO.

LOCATION

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

↑ ↑ ↑

10 % LEL 25 % LEL 150 PSIG

NOTE 16 NOTE 16

21 VDC

↓

0 0 0 0 0 1 1 1 1 0 0 0 1 1 1/0 0

N.C. N.O. N.C. N.C. N.C. N.O. N.O. N.O. N.O. N.O. N.O. N.O.

0 0 1/0 0 0 0 0 1 0 0 0 0 0 0 0 1

N.C. N.O. N.O. N.C. N.C. N.C. N.C. N.O. N.O. N.O. N.O. N.C. N.C. N.C. N.O. N.C.

0 0 0 1 0 0 1/0 1 1 1 1 0 0 0 0 1

N.O. N.O. N.O. * N.C. N.O. '--N.O. N.O. N.O. N.O. N.O. N.C. N.C. N.O. N.O.

FIRE DETECTED CONTACT CHANGES STATE ON POWER UP TURN ON ALL FANS SHUTDOWN UNIT-LEAVE FANS ON N.C. = SWITCH IN RESET POSITION CONTACT CLOSE WHEN BREAKER OPEN CONTACT CLOSE WHEN BREAKER CLOSED CONTACT CLOSE WHEN BREAKER OPEN CONTACT CLOSE WHEN BREAKER CLOSED SEE VIBRATION MALFUNCTION CAUSE & EFFECT MATRIX (SHEET 6) SEE VIBRATION MALFUNCTION CAUSE & EFFECT MATRIX (SHEET 6) SEE VIBRATION MALFUNCTION CAUSE & EFFECT MATRIX (SHEET 6)

NOTE: SD EVAP MODULE 'A' WATER PUMP, OPT - EVAP COOLER NOTE: SD EVAP MODULE 'B' WATER PUMP, OPT - EVAP COOLER * N.C.

*1 = VAR CONTROL; 0 = PF CONTROL (ACTIVE ONLY IN REMOTE) - NPOS - JS

0 = MANUAL EXCITER 1 = AVR

OPT-NOT FOR GE GENERATOR

OPT-NOT FOR GE GENERATOR 0 RPM = 1 POWER UP CHANGES RELAY D.C. OUTPUT FAILED A.C. SUPPLY FAILED LOW BATTERY VOLTAGE BATTERY SYSTEM GROUNDED

BLOWN FUSE ETC. = 1

N.O.= SHUTDOWN (PULL) N.O.= SHUTDOWN (PUSH) - NOTE 17

* AUTO = 1, MANUAL = 0 CONTACT OPEN WHEN 86 TRIPPED

1 = REMOTE / 0 = LOCAL ONLY ACTIVE WHEN DSM ENABLED ONLY ACTIVE WHEN DSM ENABLED INHIBITED WHEN DSM ENABLED INHIBITED WHEN DSM ENABLED BLOWN FUSE,ETC.

OPT - SWAP TO FAN 'B' OPT - SWAP TO FAN 'A' OPT-SERIES WIRED SWITCHES OPT-NPOS-JS

SEQUENCER DISTRIBUTIVE DISCRETE INPUTS

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

N340N340N340N340N340N340N340N340N340N340N340N340N340N340N340N340-

A1 A2 A3 A4 A5 A6 A7 A8 A9 A10 A11 A12 A13 A14 A15 A16

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

N341N341N341N341N341N341N341N341N341N341N341N341N341N341N341N341-

A1 A2 A3 A4 A5 A6 A7 A8 A9 A10 A11 A12 A13 A14 A15 A16

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

N342N342N342N342N342N342N342N342N342N342N342N342N342N342N342N342-

A1 A2 A3 A4 A5 A6 A7 A8 A9 A10 A11 A12 A13 A14 A15 A16

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

DWG NO: 20063-01-683146 REV: A SHEET 2 PAGE 7 OF 22

KAJI POWER ATLAS PC - 90/70 CONTROL

SOURCE

ACTION

POINT

SEQUENCER - DISTRIBUTIVE DISCRETE INPUTS (DI MODULE - IC200MDL640 - I/O CARRIER KEYCODE: B4) 4444444444444444-

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

CUSTOMER PERMISSIVE START REMOTE START REMOTE STOP ALARM ACKNOWLEDGE RESET (AL / NLO SD ONLY) SYNC CONTROL CLOCK GENERATOR BREAKER FAILURE 86 TRIP (CUSTOMER) BUS/UTILITY 86 TRIP DELTA12 DELTA12 DELTA12 DELTA12 DELTA12 DELTA12 DELTA12

5555555555555555-

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

6666666666666666-

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

WATER WASH CONTROL STATION WATCH DOG TIMER STATUS - FUEL CONTROL FUEL CONTROL POWER SUPPLY FAILURE (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE)

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER CUSTOMER LSH-4095 LSH-4096

HS-5005 FC SH 3, 1-8 FC SH 3, 1-9

UNIT

ALM ACTIVE

SWITCH

R/F

WIRED

SIGNAL

SOFTWARE

COMMENTS

2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2 2/2

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

43 43 43 43 43 43 43 43 43 43 43 43 43 43 43 43

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

N343N343N343N343N343N343N343N343N343N343N343N343N343N343N343N343-

A1 A2 A3 A4 A5 A6 A7 A8 A9 A10 A11 A12 A13 A14 A15 A16

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

44 44 44 44 44 44 44 44 44 44 44 44 44 44 44 44

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

N344N344N344N344N344N344N344N344N344N344N344N344N344N344N344N344-

A1 A2 A3 A4 A5 A6 A7 A8 A9 A10 A11 A12 A13 A14 A15 A16

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1

45 45 45 45 45 45 45 45 45 45 45 45 45 45 45 45

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

N145N145N145N145N145N145N145N145N145N145N145N145N145N145N145N145-

A1 A2 A3 A4 A5 A6 A7 A8 A9 A10 A11 A12 A13 A14 A15 A16

MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB MTTB

NODE ADDRESS

NODE

& TERMINAL NO.

LOCATION

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

CNTRL CNTRL CNTRL CNTRL RESET SYNC FSWM FSWM ALARM CNTRL CNTRL CNTRL NOX SD CNTRL

1 1 1 1 1 1 0 0 0 1 1 1 0 1

N.O. N.O. N.O. N.O. N.O. N.O. N.C. N.C. N.C. N.O. N.O. N.O. N.O. N.O.

0 = INHIBIT 1 = ENABLE

FROM CUSTOMER'S ZONE CLEAR SIGNAL CONTACT OPEN WHEN 86 TRIPPED CONTACT OPEN WHEN 86 TRIPPED

WATER OR STEAM WATER OR STEAM OPT- NOTE 33 OPT - NPOS - JS PART OF TEWAC OPT - NPOS - JS PART OF TEWAC

CNTRL FSLO FSLO

NAMES

CHANNEL

FUNCTION

TRIP

NODE

SIGNAL

NETWORK

WITH VERSAMAX DISTRIBUTIVE I/O NIU/SLOT

REVISION

SEQ 2

ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

1 1/0 0

N.O. N.O. N.O.

1 = INJECT WASH WATER IF TCP CONTROL ALSO ENABLED 1= FC NORMAL, 0 = WATCH DOG TIMER TIMED OUT 0 = FUEL CONTROL POWER SUPPLY FAILURE

SEQUENCER DISTRIBUTIVE DISCRETE INPUTS

%I0145 %I0146 %I0147 %I0148 %I0149 %I0150 %I0151 %I0152 %I0153 %I0154 %I0155 %I0156 %I0157 %I0158 %I0159 %I0160

%I0385 %I0386 %I0387 %I0388 %I0389 %I0390 %I0391 %I0392 %I0393 %I0394 %I0395 %I0396 %I0397 %I0398 %I0399 %I0400

4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8 4/8

DWG NO: 20063-01-683146 REV: A SHEET 2 PAGE 8 OF 22

KAJI POWER ATLAS PC - 90/70 CONTROL

SOURCE

ACTION

POINT

UNIT

ALM ACTIVE

SWITCH

R/F

WIRED

SEQUENCER - DISTRIBUTIVE DISCRETE INPUTS (DI MODULE - IC200MDL640 - I/O CARRIER KEYCODE: B4) 7-7-7-7-7-7-7-7-7-7-7-7-7-7-7-7--

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

A A A A A A A A A A A A A A A A

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

LSLL-0041A/B LSLL-0042A/B PSH-0086 PSL-0087 RGF/DF

CDLO CDLO INTLK/F-SD ALARM ALARM

NOTE: FOR DISCRETE INPUT SHEETS ---ALL DISCRETE INPUT MODULES ARE WIRED AS A POSITIVE LOGIC INPUTS.

A 1-3-7-7-7-31227-

15 13 1 2

SIGNAL

SOFTWARE

COMMENTS

NAMES

7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8 7/8

2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2

46 46 46 46 46 46 46 46 46 46 46 46 46 46 46 46

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

6 6 20 25

INCH * INCH * PSIG PSIG

↑ ↑ ↑ 1 ↓ 0

0 0

??? ??? N.O. N.O.

* FROM TOP OF TANK NPOS - JS * FROM TOP OF TANK NPOS - JS NPOS - JS ENABLE 30 SECONDS AFTER MOTOR ENERGIZED, 1= PRESSURE OK ( = OR > 20 PSIG ) NPOS - JS ENABLE WHEN XNSD > 3000 RPM

NPOS - JS

%I0769 %I0770 %I0771 %I0772 %I0773 %I0774 %I0775 %I0776 %I0777 %I0778 %I0779 %I0780 %I0781 %I0782 %I0783 %I0784

LOCATION

N246N246N246N246N246N246N246N246N246N246N246N246N246N246N246N246-

MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB MGTB

8/13/02 RSP N340- A15 8/13/02 RSP N342- A13 8/28/02 RSP N246- A1 8/28/02 RSP N246- A2 8/28/02 RSP 3/28/03RRK 1/7 8/7/03RRK PER LX EMAIL 1/8 8/7/03RRK N341- A5 1/8 8/7/03RRK N341- A7 8/7/03RRK PER LX EMAIL

TCP TCP MGTB MGTB

NOTE - ALL DI MODULES NEED: A17 24VDC (-) COMMON (9-16) A18 DATE =====

ESWM1

ALARM

0

N.C.

0 = ETHERNET 10 BASE T SYSTEM DOWN

ETHERNET HUB FAILURE

ETHHUB1

ALARM

0

N.C.

0= FAILURE

GEN LUBE OIL RUNDOWN TANKS LOW LOW (DE)

LSLL-0041 LSLL-0042

CDLO CDLO

0 0

-----

* FROM TOP OF TANK * FROM TOP OF TANK

0 0

N.C. N.C.

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

& TERMINAL NO.

24VDC (-) COMMON (1-8)

ETHERNET SWITCH MODULE FAILURE

PUT SIGNAL BACK... WAS MISSING (SPARE) GEN EXCITER DIODE FAILURE GENERATOR ROTOR GROUND FAULT ADDED NODE AND GE GENERATOR I/O === END ============

NODE

A1 A2 A3 A4 A5 A6 A7 A8 A9 A10 A11 A12 A13 A14 A15 A16

REVISION LIST ============== INITIAL REVISION, REV.A

GEN LUBE OIL RUNDOWN TANKS LOW LOW (NDE)

NODE ADDRESS

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

*6 INCH # *6 INCH #

↓ ↓

%I0015 %I0141 %I0769 %I0770

REMOVED DISCRETE INPUT BLOCK N246 FROM MGTB - (NIU7, POISTION 8) & MADE " NODE NOT SUPPLIED"

15 15 A 5 A 7 A ALLA

CHANNEL

FUNCTION

TRIP

NODE

SIGNAL

NETWORK

WITH VERSAMAX DISTRIBUTIVE I/O NIU/SLOT

REVISION

SEQ 2

ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

AVR RGF

ALARM ALARM

SEQUENCER DISTRIBUTIVE DISCRETE INPUTS

%I0015 %I0021 %I0023

1/7 2/1 7/8 7/8

TCP TCP TCP

DWG NO: 20063-01-683146 REV: A SHEET 2 PAGE 9 OF 22

KAJI POWER ATLAS PC - 90/70 CONTROL

CONTROLLED TO

CNTL VOLTAGE

ACTIVE

CONTACT

SIGNAL

USED

SEQUENCER - D I S T R U B I T I V E D I S C R E T E O U T P U T S

1-1-1-1-1-1-1-1-1-1-1-1-1-1-1-1--

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

DISCRETE OUTPUT MODULE (RELAY) - IC200MDL940 (I/O CARRIER KEYCODE: C8) SUMMARY CRITICAL SHUTDOWN CRITL PATH TCP 24 VDC INHIBIT VIBRATION MONITOR VIB MON TCP CONTACT (SPARE) (SPARE) VOLTAGE REGULATOR RESET AVR TCP 24 VDC RAISE VOLTAGE BY CUST. SERIAL REMOTE AVR TCP 24 VDC LOWER VOLTAGE BY CUST. SERIAL REMOTE AVR TCP 24 VDC VAR SHED CONTROL AVR TCP 24 VDC HORN HORN TCP 24 VDC SEQUENCER POWER SUPPLY "OK" FC SH 2, 1-17 TCP 24 VDC TEST TIMER CRITICAL PATH TRIP TCP 24 VDC TURBINE-GENERATOR SUMMARY SHUTDOWN CUSTOMER CUSTOMCONTACT SYNCHRONIZER ENABLE K28 TCP 24 VDC CIRCUIT BREAKER CONTROL K85 TCP 24 VDC (SPARE) (SPARE)

2-2-2-2-2-2-2-2-2-2-2-2-2-2-2-2--

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

DISCRETE OUTPUT MODULE (SOLID STATE) - IC200MDL741 (I/O CARRIER KEYCODE: C2) SYSTEM RESET (VIB/ESD BUS) K5/K115 TCP 24 VDC IGNITOR CONTROL K83 TCP 24 VDC TURB RUNNING /READY K81 TCP 24 VDC MTTB CABINET COOLING K347 MTTB 24 VDC MTTB CABINET HEATING K348 MTTB 24 VDC SEQUENCER WATCH DOG TIMER PULSE TDR1 TCP 24 VDC (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) (SPARE)

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

CHANNEL

FUNCTION

SIGNAL

NODE

DEVICE

EXTERNAL

NETWORK

WITH VERSAMAX DISTRIBUTIVE I/O NIU/SLOT

REVISION

SEQ 3

ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

%Q0129 %Q0130 %Q0131 %Q0132 1 = RESET VOLTAGE REGULATOR TO PRESET START VOLT %Q0133 ONLY ACTIVE WHEN IN REMOTE CONTROL (PULSE OUT) %Q0134 ONLY ACTIVE WHEN IN REMOTE CONTROL (PULSE OUT) %Q0135 ACTIVATE ON NORMAL STOP %Q0136 %Q0137 0 = SEQUENCER POWER SUPPLY FAILURE %Q0138 NORMAL MODE = 1 %Q0139 %Q0140 %Q0141 0 = TRIP BKR , 1 = BKR CLOSE PERMISSIVE %Q0142 %Q0143 %Q0144

2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3 2/3

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

60 60 60 60 60 60 60 60 60 60 60 60 60 60 60 60

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

N360- A1 / A2

%Q0145 %Q0146 ON = NGG > 4600, CONTROLS HE-4050 & HE-4051 %Q0147 CONTROLS MOT-4019A & 4019B, NOTE 23 FOR SETPOINTS &%Q0148 CONTROLS MOT-4019A & 4019B, NOTE 23 FOR SETPOINTS &%Q0149 PULSE OUTPUT TO WATCH DOG TIMER %Q0150 %Q0151 %Q0152 %Q0153 %Q0154 %Q0155 %Q0156 %Q0157 %Q0158 %Q0159 %Q0160

2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4 2/4

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

61 61 61 61 61 61 61 61 61 61 61 61 61 61 61 61

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

N361- A1

SOFTWARE COMMENTS

NAMES

NODE ADDRESS & TERMINAL NO.

RELAY

TERM

BOX

NUMBER

---------------------------------

---------------------------------

-------------------------------------------------

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

---------------------------------

---------------------------------

-------------------------------------------------

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

CABLE #

NODE LOCATION

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

0 1

1 1 1 1 1 0 0 0 1# 0/1#

1 1# 1 1 1 1/0

N.O. N.O.

N/A N.O. N.O. N.O. N.O. N.O. N.O. N.O. N/A N/A

N.O. N/A N/A N.O. N.O. N/A

NGG < 6000 RPM OR NPT < 1800

FOR BE-8016A & 8016B

SEQUENCER DISTRUBITIVE DISCRETE OUTPUTS

N360- A3 / A4 N360- A5 / A6 N360- A7 / A8 N360- A9 / A10 N360- A11 / A12 N360- A13 / A14 N360- A15 / A16 N360- B1 / B2 N360- B3 / B4 N360- B5 / B6 N360- B7 / B8 N360- B9 / B10 N360- B11 / B12 N360- B13 / B14 N360- B15 / B16

N361- A2 N361- A3 N361- A4 N361- A5 N361- A6 N361- A7 N361- A8 N361- A9 N361- A10 N361- A11 N361- A12 N361- A13 N361- A14 N361- A15 N361- A16

POWER, 24VDC(+)

N361- A18

POWER, 24VDC(-)

N361- A17

DWG NO: 20063-01-683146 REV: A SHEET 3 PAGE 10 OF 22

KAJI POWER ATLAS PC - 90/70 CONTROL

CONTROLLED TO

CNTL VOLTAGE

ACTIVE

CONTACT

SIGNAL

USED

SEQUENCER - D I S T R U B I T I V E D I S C R E T E O U T P U T S

3-3-3-3-3-3-3-3-3-3-3-3-3-3-3-3--

4-4-4-4-4-4-4-4-4-4-4-4-4-4-4-4--

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 A 16

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

DISCRETE OUTPUT MODULE (SOLID STATE) - IC200MDL741 (I/O CARRIER KEYCODE: C2) FUEL SYSTEM INITIALIZE A15 TCP 24 VDC AVR EXCITATION ON AVR TCP 24 VDC MGTB CABINET SPACE HEATER HE-4053 MGTB 24 VDC TURBINE WATER WASH PUMP AIR SUPPLY VLV SOV-5034 MAIN SK24 VDC (SPARE) TURBINE WATER WASH OFF-LINE SUPPLY VLV SOV-5032 MAIN SK24VDC DELTA12 SOV-4068 24VDC DELTA12 SOV-4069 24VDC DELTA12 SOV-4041 24VDC (SPARE) (SPARE) (SPARE) (SPARE) (SPARE) DELTA12 HE-0005B MCC 120 VAC DELTA12 PSS TCP 24VDC

DISCRETE OUTPUT MODULE (SOLID STATE) - IC200MDL741 (I/O CARRIER KEYCODE: C2) GEN LUBE OIL AC PUMP MOT-0033 TCP 120VAC GENERATOR LUBE OIL TANK HEATER HE-0005 MCC 120 VAC TURBINE LUBE OIL TANK HEATER HE-1004 MCC 120 VAC DELTA12 MOT-0032 MCC 120 VAC HYDRAULIC STARTER OIL TANK HEATER HE-6010 MCC 120 VAC HYDRAULIC STARTER PUMP MOT-6015 MCC 120 VAC HYDRAULIC STARTER OIL HEAT EXCH FAN MOT-6016 MCC 120 VAC TURB ENCLOSURE VENT FAN "A" MOT-4017A MCC 120 VAC TURB ENCLOSURE VENT FAN "B" MOT-4017B MCC 120 VAC TURBINE/ GEN LUBE OIL HEAT EXCHANGER FAN "A" MOT-0043A MCC 120 VAC TURBINE/ GEN LUBE OIL HEAT EXCHANGER FAN "B" MOT-0043B MCC 120 VAC DELTA12 MOT-2022 MCC 120 VAC DELTA12 MOT-2075A MCC 120 VAC DELTA12 MOT-2075B MCC 120 VAC DELTA12 MOT-4060 MCC 120 VAC DELTA12 MOT-4061 MCC 120 VAC

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

SOFTWARE COMMENTS

NAMES

CHANNEL

FUNCTION

SIGNAL

NODE

DEVICE

EXTERNAL

NETWORK

WITH VERSAMAX DISTRIBUTIVE I/O NIU/SLOT

REVISION

SEQ 3

ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5 2/5

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

62 62 62 62 62 62 62 62 62 62 62 62 62 62 62 62

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

NODE ADDRESS & TERMINAL NO.

CABLE #

RELAY

TERM

BOX

NUMBER

NODE LOCATION

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

1 1 1 1# 1# 0 0 1

1 0

0 1 1 1 1 1 1 1 1 1 1 1# 1# 1# 1 1

N.O. N.O./N.C. N.O. N.O. N.O. N.O. N.O. N.O.

N.O. N.O.

N.C. N.O. N.O. N.O. N.O. N.O. N.O. N.O. N.O. N.O. N.O. N.O. N.O. N.O. N.O. N.O.

AT FUEL INITIATION ACTIVATE FOR 1 SEC. SEE NOTE 31 SEE NOTE 32 ENERGIZED OPEN

ENERGIZED OPEN ENERGIZE CLOSED , OPT - EVAP COOLER - SEE NOTE 4 ENERGIZE CLOSED , OPT - EVAP COOLER - SEE NOTE 4 ENERGIZE OPEN , OPT - AUX SKID - SEE NOTE 34

OPT-NPOS-JS, 1 = EN HTR, NOTE 26 OPT-NPOS-JS, 0= PSS ON, 1=PSS OFF

%Q0161 %Q0162 %Q0163 %Q0164 %Q0165 %Q0166 %Q0167 %Q0168 %Q0169 %Q0170 %Q0171 %Q0172 %Q0173 %Q0174 %Q0175 %Q0176

%Q0177 %Q0178 1 = ENABLE HEATER (WHEN LEVEL NORMAL BY LT-1002), %Q0179 OPT-NPOS-JS %Q0180 1 = ENABLE HEATER (WHEN LEVEL NORMAL BY LT-6001), %Q0181 SEE NOTE 27 %Q0182 MOTOR ON = IF TANK TEMP > 110 DEG.F, OFF = IF TANK TE %Q0183 %Q0184 OPT-NPOS %Q0185 OPT-NPOS-JS %Q0186 OPT-NPOS-JS %Q0187 OPT - LIQUID FUEL %Q0188 OPT - WATER INJ %Q0189 OPT - WATER INJ %Q0190 OPT - EVAP COOLER %Q0191 OPT - EVAP COOLER %Q0192 0= AC PUMP ON, 1= AC PUMP OFF

1 = ENABLE HEATER (WHEN LEVEL NORMAL BY LT-0001),

SEQUENCER DISTRUBITIVE DISCRETE OUTPUTS

N362- J1

W362

U362-J1

A1- N.C./C/N.O.

N362- J1

W362

U362-J1

A2- N.C./C/N.O.

N362- J1

W362

U362-J1

A3- N.C./C/N.O.

N362- J1

W362

U362-J1

A4- N.C./C/N.O.

N362- J1

W362

U362-J1

A5- N.C./C/N.O.

N362- J1

W362

U362-J1

A6- N.C./C/N.O.

N362- J1

W362

U362-J1

A7- N.C./C/N.O.

N362- J1

W362

U362-J1

A8- N.C./C/N.O.

N362- J1

W362

U362-J1

A9- N.C./C/N.O.

N362- J1

W362

U362-J1

A10- N.C./C/N.O.

N362- J1

W362

U362-J1

A11- N.C./C/N.O.

N362- J1

W362

U362-J1

A12- N.C./C/N.O.

N362- J1

W362

U362-J1

A13- N.C./C/N.O.

N362- J1

W362

U362-J1

A14- N.C./C/N.O.

N362- J1

W362

U362-J1

A15- N.C./C/N.O.

N362- J1

W362

U362-J1

A16- N.C./C/N.O.

POWER, 24VDC(+)

U362-

A18

POWER, 24VDC(-)

U362-

A17

2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6 2/6

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

63 63 63 63 63 63 63 63 63 63 63 63 63 63 63 63

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

N363- J1

W363

U363-J1

A1- N.C./C/N.O.

N363- J1

W363

U363-J1

A2- N.C./C/N.O.

N363- J1

W363

U363-J1

A3- N.C./C/N.O.

N363- J1

W363

U363-J1

A4- N.C./C/N.O.

N363- J1

W363

U363-J1

A5- N.C./C/N.O.

N363- J1

W363

U363-J1

A6- N.C./C/N.O.

N363- J1

W363

U363-J1

A7- N.C./C/N.O.

N363- J1

W363

U363-J1

A8- N.C./C/N.O.

N363- J1

W363

U363-J1

A9- N.C./C/N.O.

N363- J1

W363

U363-J1

A10- N.C./C/N.O.

N363- J1

W363

U363-J1

A11- N.C./C/N.O.

N363- J1

W363

U363-J1

A12- N.C./C/N.O.

N363- J1

W363

U363-J1

A13- N.C./C/N.O.

N363- J1

W363

U363-J1

A14- N.C./C/N.O.

N363- J1

W363

U363-J1

A15- N.C./C/N.O.

N363- J1

W363

U363-J1

A16- N.C./C/N.O.

POWER, 24VDC(+)

U363-

A18

POWER, 24VDC(-)

U363-

A17

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP TCP

DWG NO: 20063-01-683146 REV: A SHEET 3 PAGE 11 OF 22

KAJI POWER ATLAS PC - 90/70 CONTROL

CONTROLLED TO

CNTL VOLTAGE

ACTIVE

CONTACT

SIGNAL

USED

SEQUENCER - D I S T R U B I T I V E D I S C R E T E O U T P U T S 5-5-5-5-5-5-5-5-5-5-5-5-5-5-5-5--

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

SOFTWARE COMMENTS

NAMES

CHANNEL

FUNCTION

SIGNAL

NODE

DEVICE

EXTERNAL

NETWORK

WITH VERSAMAX DISTRIBUTIVE I/O NIU/SLOT

REVISION

SEQ 3

ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7 2/7

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

64 64 64 64 64 64 64 64 64 64 64 64 64 64 64 64

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16

NODE ADDRESS & TERMINAL NO.

CABLE #

RELAY

TERM

BOX

NUMBER

NODE LOCATION

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED NODE NOT SUPPLIED

N364N364N364N364N364N364N364N364N364N364N364N364N364N364N364N364N364N364-

NOTE: FOR DISCRETE OUTPUT SHEETS ---# IN ACTIVE SIGNAL COL. = POWER TO RELAY TO BE REMOVED IF CRITICAL SHUTDOWN PATH TRIPPED. (#1) IN ACTIVE SIGNAL COL.= RETURN WIRED THRU A15 SAFETY CIRCUIT. POWER SUPPLY 6-- 1 6-- 2 6-- 3

+24 VDC INPUT +24 VDC COMMON INPUT EARTH GROUND

A 3-- 6 4-4-3-4--

10 11 15 A 4 A

BATTERY BATTERY

24 VDC POWER SUPPLY INPUT - MAIN CHASSIS 24 VDC POWER SUPPLY INPUT - MAIN CHASSIS

24+L1 24+L1COM GRN/YEL

REVISION LIST ============== INITIAL REVISION, REV.A ADDED TURBINE WATER WASH OFF-LINE SUPPLY VLV SOV-5033, N3-62-6 ( %Q0166) ( FROM SPARE CHANNEL) ADDED LUB OIL HEAT EXCHANGER FAN OPTION ( ITEM 4-10 & 4-11)

DATE =====

TURBINE/ GEN LUBE OIL HEAT EXCHANGER FAN

(SPARE) GENERATOR LUBE OIL TANK HEATER "B" (SPARE)

HE-0005B

MCC

120 VAC

1

N.O.

1 = ENABLE HEATER (WHEN LEVEL NORMAL BY LT-0001),

%Q0186 %Q0187 %Q0175 %Q0180

2/6 2/6 2/5 2/6

8/22/02 RSP 9/18/02 RSP 9/18/02 RSP N363- J1 9/18/02 RSP N363- J1 8/7/03RRK PER LX EMAIL 8/7/03RRK PER LX EMAIL

W363

U363-J1

A10- N.C./C/N.O.

W363

U363-J1

A11- N.C./C/N.O.

W362

U362-J1

A15- N.C./C/N.O.

W363

U363-J1

A4- N.C./C/N.O.

TCP TCP TCP TCP

=== END ============

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

SEQUENCER DISTRUBITIVE DISCRETE OUTPUTS

DWG NO: 20063-01-683146 REV: A SHEET 3 PAGE 12 OF 22

KAJI POWER

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

ATLAS PC - 90/70 CONTROL CHANNEL

CABLE #

1-1-1-1-1-1--

1 2 3 4 5 6

PORT 1 (RS232) RS-232 - CTS (Clear to Send) RS-232 - TXD (Transmit Data) RS-232 - 0 V (Signal Ground) RS-232 - 0 V (Signal Ground) RS-232 - RXD (Receive Data) RS-232 - RTS (Request to Send)

NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED

1 1 1 1 1 1

1 1 1 1 1 1

1 1 1 1 1 1

W1001-1 W1001-1 W1001-1 W1001-1 W1001-1 W1001-1

2-2-2-2-2-2-2-2-2-2-2-2-2-2-2--

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

PORT 2 (RS485) Cable Shield N.C. No Connection N.C. No Connection N.C. No Connection +5 VDC Logic Power (Max. current 100 mA) RTS(A) - Differential request to Send SG - Signal Ground CTS(B') - Differential Clear to Send RT - Resistor Termination RD(A') - Differential Receive Data RD(B') - Differential Receive Data SD(A) - Differential Send Data SD(B) - Differential Send Data RTS(B') - Differential Request to Send CTS(A') - Differential Clear to Send

NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED NOT USED

1 1 1 1 1 1 1 1 1 1 1 1 1 1 1

1 1 1 1 1 1 1 1 1 1 1 1 1 1 1

2 2 2 2 2 2 2 2 2 2 2 2 2 2 2

W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2 W1001-2

3-3-3-3-3-3-3-3-3-3-3-3-3-3-3--

1 2 3 4 5 6 7 8 9 10 11 12 13 14 15

PORT 3 (RS485) Cable Shield N.C. No Connection N.C. No Connection N.C. No Connection +5 VDC Logic Power (Max. current 100 mA) RTS(A) - Differential request to Send SG - Signal Ground CTS(B') - Differential Clear to Send RT - Resistor Termination RD(A') - Differential Receive Data RD(B') - Differential Receive Data SD(A) - Differential Send Data SD(B) - Differential Send Data RTS(B') - Differential Request to Send CTS(A') - Differential Clear to Send

1 1 1 1 1 1 1 1 1 1 1 1 1 1 1

1 1 1 1 1 1 1 1 1 1 1 1 1 1 1

3 3 3 3 3 3 3 3 3 3 3 3 3 3 3

W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3 W1001-3

ITEM

REVISION

SLOT

WITH VERSAMAX DISTRIBUTIVE I/O

CHASSIS

SEQ 4

FUNCTION

SEQUENCER - C O M M U N I C A T I O N S

DESTINATION

COMMENTS

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

90/70 PLC CPU MODULE - IC697CGR935

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV.DATE: N/A

90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER 90/70 PROGRAMMER

SEQUENCERCOMMUNICATIONS

DWG NO:20063-01-683146 REV:A SHEET 4 PAGE 13 OF 22

KAJI POWER ATLAS PC - 90/70 CONTROL

SEQUENCER - C O M M U N I C A T I O N S

CHANNEL

FUNCTION

SLOT

WITH VERSAMAX DISTRIBUTIVE I/O

CHASSIS

REVISION

SEQ 4

ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

CABLE #

ETHHUB1, PORT 2

10 BASE T - CAT 5 CABLE (GREEN)

1

4

1

W1004

ESWM1, PORT 5

10 BASE T - CAT 5 CABLE (RED)

1

5

1

W1005

NIU SERIAL A1 NIU SERIAL A2 NIU SHIELD IN/OUT (A IN/OUT)

2 COND SHIELDED 8.8 pf/ft WIRE 2 COND SHIELDED 8.8 pf/ft WIRE 2 COND SHIELDED 8.8 pf/ft WIRE

1 1 1

6 6 6

1 1 1

W1006-1 & 2 W1006-1 & 2 W1006-1 & 2

NIU SERIAL B1 NIU SERIAL B2 NIU SHIELD IN/OUT (B IN/OUT)

2 COND SHIELDED 8.8 pf/ft WIRE 2 COND SHIELDED 8.8 pf/ft WIRE 2 COND SHIELDED 8.8 pf/ft WIRE

1 1 1

7 7 7

1 1 1

W1007-1 & 2 W1007-1 & 2 W1007-1 & 2

FUEL CONTROL, ETHERNET #1

10 BASE T - CAT 5 CABLE (CABLE SUPPLIED BY CUSTOMER)

1

8

1

W108

DESTINATION

COMMENTS

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

90/70 PLC ETHERNET INTERFACE MODULE - IC697CMM742

4-- 1

10 BASE T PORT ETHERNET CONNECTION TO 4 PORT HUB

90/70 PLC ETHERNET INTERFACE MODULE - IC697CMM742

5-- 1

10 BASE T PORT ETHERNET CONNECTION TO 10 PORT SWITCH ( FOR HMI, DCS, REMOTE WONDERWARE)

90/70 PLC GENIUS I/O BUS CONTROLLER MODULE - IC697BEM731

6-- 1 6-- 1 6-- 1

GENIUS CHANNEL 1 PRIMARY GENIUS BUS SERIAL 1 PRIMARY GENIUS BUS SERIAL 2 PRIMARY GENIUS BUS SHIELD OUT/IN

90/70 PLC GENIUS I/O BUS CONTROLLER MODULE - IC697BEM731

7-- 1 7-- 1 7-- 1

GENIUS CHANNEL 1 SECONDARY GENIUS BUS SERIAL 1 SECONDARY GENIUS BUS SERIAL 2 SECONDARY GENIUS BUS SHIELD OUT/IN

90/70 PLC ETHERNET INTERFACE MODULE - IC697CMM742

8-- 1

10 BASE T PORT ETHERNET CONNECTION TO FUEL CONTROL

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV.DATE: N/A

SEQUENCERCOMMUNICATIONS

DWG NO:20063-01-683146 REV:A SHEET 4 PAGE 14 OF 22

KAJI POWER

SEQUENCER - C O M M U N I C A T I O N S 90/70 PLC MODBUS RTU MASTER/SLAVE MODULE - HE697RTM701

9-9-9-9-9-9-9-9-9-9-9-9-9-9-9-9-9-9-9-9--

PORT 1 MASTER (RS232 OR RS422/485) - CONFIGURED FOR RS485 SHIELD TD - RS-232 (NOT USED) RD - RS-232 (NOT USED) RTS - RS-232 (NOT USED) CTS - RS-232 (NOT USED) NC SIGNAL GROUND DCD - RS-232 (NOT USED) SD (A) - RS-485 (SEND DATA (-)) JMP TO 13 RTS (A) - RS-485 (READY TO SEND (-)) (NOT USED) CTS (A') - RS-485 (CLEAR TO SEND (-)) (NOT USED) TERM. RESISTOR (CTS) - RS-485 (NOT USED) RD (A') - RS-485 (RECEIVE DATA (-)) - JMP TO 9 PINS 14-19 = NC DTR - RS-232 (NOT USED) SD (B) - RS-485 (SEND DATA (+)) JMP TO 24 & 25 RTS (B) - RS-485 ( READY TO SEND (+)) (NOT USED) CTS (B') - RS-485 (CLEAR TO SEND (+)) (NOT USED) TERM. RESISTOR (RD) - RS-485 - JMP TO 25 & 21 RD (B') - RS-485 (RECEIVE DATA (+)) JMP TO 24 & 21

1 2 3 4 5 6 7 8 9 10 11 12 13 14 20 21 22 23 24 25

PORT 2 SLAVE (RS232 OR RS422/485) - CONFIGURED FOR RS485 SHIELD TD - RS-232 (NOT USED) RD - RS-232 (NOT USED) RTS - RS-232 (NOT USED) CTS - RS-232 (NOT USED) NC SIGNAL GROUND DCD - RS-232 (NOT USED) SD (A) - RS-485 (SEND DATA (-)) JMP TO 13 RTS (A) - RS-485 (READY TO SEND (-)) (NOT USED) CTS (A') - RS-485 (CLEAR TO SEND (-)) (NOT USED) TERM. RESISTOR (CTS) - RS-485 (NOT USED) RD (A') - RS-485 (RECEIVE DATA (-)) - JMP TO 9 PINS 14-19 = NC DTR - RS-232 (NOT USED) SD (B) - RS-485 (SEND DATA (+)) JMP TO 24 & 25 RTS (B) - RS-485 ( READY TO SEND (+)) (NOT USED) CTS (B') - RS-485 (CLEAR TO SEND (+)) (NOT USED) TERM. RESISTOR (RD) - RS-485 - JMP TO 25 & 21 RD (B') - RS-485 (RECEIVE DATA (+)) - JMP TO 24 & 21

10- 1 10- 2 10- 3 10- 4 10- 5 10- 6 10- 7 10- 8 10- 9 10- 10 10- 11 10- 12 10- 13 10- 14 10- 20 10- 21 10- 22 10- 23 10- 24 10- 25

A

DESTINATION

COMMENTS

CHANNEL

FUNCTION

SLOT

REVISION

WITH VERSAMAX DISTRIBUTIVE I/O

CHASSIS

ATLAS PC - 90/70 CONTROL

SEQ 4

ITEM

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

CABLE #

1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1

9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9

1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1

W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1 W1009-1

1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1

9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9 9

2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2 2

W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2 W1009-2

FOR METRIC CONVERSION FACTOR, NOTES, AND TABLES SEE SHEET 5

CONN. PIN DMMF/VIBRATION MONITOR

DMMF/VIBRATION MONITOR

5 (SIGNAL GND)

DMMF/VIBRATION MONITOR

8 (TRAN-) ALSO JMP TO 9 (REC-)

DMMF/VIBRATION MONITOR

7 (REC+) ALSO JMP TO 6 (TRAN+)

6 (RXA-) & 9 (TXA-)

3 (TXB+) & 4 (RXB+)

CUSTOMER DCS

CUSTOMER DCS CUSTOMER DCS

CUSTOMER DCS

REVISION LIST ============== INITIAL REVISION, REV.A

DATE =====

=== END ============

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV.DATE: N/A

SEQUENCERCOMMUNICATIONS

DWG NO:20063-01-683146 REV:A SHEET 4 PAGE 15 OF 22

KAJI POWER

WORKSHEET, SEQUENCER

GE PACKAGED POWER, L.P.

ATLAS PC - 90/70 CONTROL REVISION

SEQ 5

WITH VERSAMAX DISTRIBUTIVE I/O

*** PROPRIETARY INFORMATION *** WORKSHEET NOTES

ACTION CODES: FSLO = FAST STOP LOCKOUT WITHOUT MOTOR - IMMEDIATELY SHUTDOWN BY SHUTING OFF FUEL, SHUTDOWN STEAM/WATER, AND TRIP BREAKER (RESET FROM TURBINE CONTROL PANEL ONLY) FSWM = FAST STOP WITH MOTOR - FSLO, THEN ENGAGE STARTER FOR 7.5 MINUTES WHEN NGG REACHES 1700 RPM. (RESET FROM TURBINE CONTROL PANEL ONLY) = IF T48 IS NOT ABOVE 400 DEG F WHEN FSWM IS ACTIVATED THEN ONLY FSLO WILL OCCUR. F-SD = FAST SHUTDOWN (RESET FROM TURBINE CONTROL PANEL ONLY) CDLO = COOLDOWN LOCKOUT - SHED LOAD AND STEAM/WATER, TRIP BKR, IDLE FOR 5 MIN. IF RESET 'CLEARS SD DURING COOL DOWN PERIOD, CDLO IS ABORTED. = STARTER ENGAGED FOR 7.5 MINUTES WHEN XN25 DROPS TO 1700 RPM. (RESET FROM TURBINE CONTROL PANEL ONLY) = IF ON NAPHTHA FUEL, CDLO IS REPLACED WITH FSWM. INTLK = INTERLOCK (REQUIRED TO OPERATE) SD/STSY = SHUTDOWN STEAM SYSTEM ONLY (RESET FROM TURBINE CONTROL PANEL ONLY) SML = SLOW DECEL TO MIN LOAD - FAST LOAD SHED TO MIN LOAD IN 20 SEC (IF PROBLEM STILL EXISTS AFTER 3 MINUTES, DO CDLO) = (RESET FROM TURBINE CONTROL PANEL ONLY) SDTI = STEP DECEL TO IDLE (FUEL FLOW SHALL NOT GO BELOW 1300 PPH) (10 SECONDS AFTER ACHIEVING CORE IDLE FSLO) (RESET FROM TURBINE CONTROL PANEL ONLY) STATUS = STATUS OF I/O POINT CONTROL = INPUT OR OUTPUT REQUIRED TO CONTROL A DEVICE OR FUNCTION. ALARM = AUDIO AND VISUAL INDICATION OF A FAULT CONDITION.

ABBREVIATIONS

METRIC CONVERSIONS

OPT = OPTION - ONLY ITEMS THAT MAYBE DELTA 12

1 PSIG = 6.894757 KILOPASCALS (SAME FOR PSID)

NPOS = NOT PART OF STANDARD ( NOT INSTALLED - COST ADDER TO INSTALL)

1 DEG F = 1.8 DEG C + 32

JS = JOB SPECIFIC - MUST BE SPECIFIED

1 INCH = 25.4 mm

ON THE PDS TO USE DELTA 12 = END DEVICES NOT SUPPLIED, BUT ALL WIRING

1 INCH/WG = 25.4 mm/WG 1 MIL = 25.4 MICROMETERS

FOR TCP, INTERCONNECTS, AND SKIDS TO

1 PSIG = 0.06894757 BAR

BE SUPPLIED.

1 CUBIC FOOT = 0.02831685 CUBIC METER

RTD = 100 OHM Pt RTD WITH EUROPEAN SPEC. CHAR.:

1 POUND = 0.453924 KILOGRAM

0.00385 OHMS/OHMS DEG C 100 OHMS AT 32 DEG F (0 DEG C). BSLN = BASELINE THIS WORKSHEET BASED ON MID-IDM-2500-9 NOTE: NOTES ABOUT CORE ENGINE OPERATION MAY NOT REFLECT ACTUAL CORE PROGRAM IN USE, DUE TO UNSCHEDULED UPDATES TO THE CORE PROGRAM BY THE ENGINE MANUFACTURER. WHEN CONFLICTS IN NOTE INFORMATION EXIST, REFERENCE LATEST IDM, CONTROL SPEC., AND PERTINENT DOCUMENTS OF SUBJECT FOR RESOLUTION. IF REQUIRED INFORMATION NOT PRESENT IN NOTES, REFER TO ABOVE MENTIONED DOCUMENTS.

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683146 REV: A SHEET 5 PAGE 16 OF 22

KAJI POWER

WORKSHEET, SEQUENCER

GE PACKAGED POWER, L.P.

ATLAS PC - 90/70 CONTROL REVISION

SEQ 5

WITH VERSAMAX DISTRIBUTIVE I/O

*** PROPRIETARY INFORMATION *** WORKSHEET NOTES SEQUENCER NOTES: 1. GENERATOR OVER VOLTAGE PROTECTION AT THIS INPUT ( 76 DEVICE) IF EXCITER FIELD AMPS (%AI0002) > 8.0 ADC & IF GEN BREAKER OPEN (%I0006 ) AND CONDITION EXISTS FOR >2.0 SECONDS, THEN TURN OFF "AVR EXCITATION ON" OUPUT ( %Q0162) & ALARM AND ANNUNCIATE " GEN EXCITATION AMPS HIGH " 2 TURBINE LUBE OIL TANK LEVEL: ( FULL TANK 100% = 29.6 INCHES) a. HI LEVEL ALARM: > 83% ( 5.0 INCH DECREASING FROM TANK TOP WALL) b. LO LEVEL ALARM: < 59% ( 12.0 INCH INCREASING FROM TANK TOP WALL ) c. LO LEVEL SHUTDOWN (FSLO) : < 53% ( 14.0 INCH INCREASING FROM TANK TOP WALL ) 3 HYDRAULIC STARTER OIL TANK LEVEL: ( FULL TANK 100% = 22.6 INCHES) a. HI LEVEL ALARM: > 91% ( 2.0 INCH DECREASING FROM TANK TOP WALL ) b. LO LEVEL ALARM: < 73% ( 6.0 INCH INCREASING FROM TANK TOP WALL ) c. LO LEVEL SHUTDOWN (FSLO): < 69% ( 7.0 INCH INCREASING FROM TANK TOP WALL ) 4. OPEN EVAP COOLER BYPASS VALVE IF CONDUCTIVITY > 110 Uohms/CM AND CLOSED IF < 90 Uohms/CM 5. GAS ANALYSIS INPUTS : LHV= GAS FUEL HEATING VALUE, SG= GAS FUEL SPECIFIC GRAVITY a. SIGNAL FAULT : IF (LHV OR SG) FAILS= ALARM & DEFAULT TO LAST HOUR AVERAGED VALUE b. DURING STARTUP, IF (LHV OR SG) FAILS AND NO MANUAL VALUE AVAILABLE = ABORT START c. IF THE SIGNALS FROM THE GAS ANALYSIS EQUIPMENT ARE FAULTED, THEN THE LAST HOUR AVERAGED VALUE SHALL BE USED AS THE DEFAULTS. 6. TURB LUBE OIL SUPPLY PRESSURE SENSOR a. ALARM = IF PRESSURE < 8 PSIG & IF 4500 < NGG < 8000 b. FSLO = IF PRESSURE < 6 PSIG & IF 4500 < NGG < 8000 c. ALARM = IF PRESSURE < 25 PSIG & NGG >= 8000 RPM d. FSLO = IF PRESSURE < 15 PSIG & NGG >= 8000 RPM e. FSLO = IF PRESSURE SENSOR FAIL 7. PER IDM CHIP DETECTORS MUST ALARM WHEN < 100 OHMS. NIU BLOCK HAS 301 OHM ELEVATOR TIED ACROSS INPUTS. 100 // WITH 301 OHM => 75.06 OHMS. MUST MEASURE < 75 OHM FOR 2.5 SEC TO ALARM 8. TURB THRUST BALANCE PISTON PRESSURE (TBP) IS OUTSIDE THE LIMITS IN FIGURE 1 OF TABLE 11-1 OF IDM(TBP V/S P48) = ALARM. LOOK AT b. a. IF TBP < 50 PSIA WHEN P48 > 60 PSIA = CDLO b. IF TBP < (2.5 * P48) - 49 OR TBP > (2.5 * P48) - 37 = ALARM 9. ALARM = IF WATER TO FUEL RATIO (W/F) HIGH - IF W/F > 1.0 FOR GAS FUEL OR IF W/F > 1.2 FOR LIQ FUEL 10. GEN LUBE OIL SUPPLY PRESSURE SENSOR a. ALARM = IF PRESSURE < 25 PSIG b. CDLO & START AC PUMP = IF PRESSURE < 20 PSIG c. FSLO = IF PRESSURE < 12 PSIG OR IF PRESSURE > 60 PSIG d. FSLO = IF PRESSURE SENSOR FAILS 11. a.START ENABLE INHIBITED IF GEN STATOR WINDING TEMP BELOW 14 DEG F - SPACE HEATERS WILL BE USED TO WARM GENERATOR STATOR. b. WARM LUBE OIL WILL BE USED TO WARM UP BEARINGS TO 68 DEG F BEFORE STARTER ENGAGEMENT WILL BE ALLOWED.

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683146 REV: A SHEET 5 PAGE 17 OF 22

KAJI POWER

WORKSHEET, SEQUENCER

GE PACKAGED POWER, L.P.

ATLAS PC - 90/70 CONTROL REVISION

SEQ 5

WITH VERSAMAX DISTRIBUTIVE I/O

*** PROPRIETARY INFORMATION *** WORKSHEET NOTES 12. GENERATOR LUBE OIL TANK LEVEL: ( FULL TANK 100% = 29.1 INCHES ) a. HI LEVEL ALARM: > 90% ( 5.0 INCH DECREASING FROM TANK TOP WALL ) b. LO LEVEL ALARM: < 63% ( 10.65 INCH INCREASING FROM TANK TOP WALL ) c. LO LEVEL SHUTDOWN (FSLO): < 55% ( 13.0 INCH INCREASING FROM TANK TOP WALL ) 13. GEN LUBE OIL RUNDOWN TANK LEVEL TRANSMITTERS ( LT-0040 & LT-0041): RUNDOWN TANK FULL 100% = 27.9 INCHES a. IF RUNNING & LEVEL IS < 78% ( 6.0 INCH DECREASING FROM TANK TOP WALL ) = CDLO b. IF STARTING & LEVEL > 78% ( 6.0 INCH INCREASING FROM TANK TOP WALL ) = REMOVE INTERLK 14. INTENTIONALLY LEFT BLANK 15. INTENTIONALLY LEFT BLANK 16. VIBRATION SETPOINTS ARE: HP ROTOR LEVEL (75 - 200 HZ) > 4 MILS DA (1.75 IN/SEC ) = ALARM HP ROTOR LEVEL (75 - 200 HZ) > 7 MILS DA (3.0 IN/SEC ) = SDTI PT ROTOR LEVEL (25 - 200 HZ) > 7 MILS DA (1.75 IN/SEC ) = ALARM PT ROTOR LEVEL (25 - 200 HZ) > 10 MILS DA (3.0 IN/SEC ) = SDTI GEN ROTOR LEVEL > 3.0 MILS FOR MORE THAN 1.0 SEC = ALARM GEN ROTOR LEVEL > 4.0 MILS FOR MORE THAN 0.1 SEC = SDTI 17. IF REMOTE EMERGENCY STOP IS ACTIVATED FROM TURBINE ROOM, TURBINE ROOM VENT FANS WILL BE TURNED OFF AUTOMATICALLY. 18. INTENTIONALLY LEFT BLANK 19. INTENTIONALLY LEFT BLANK 20. INTENTIONALLY LEFT BLANK 21. INTENTIONALLY LEFT BLANK 22. INTENTIONALLY LEFT BLANK 23. SOFTWARE INTER LOCK MUST BE INSTALLED TO PREVENT FROM TURNING COOLING (%Q0148) & HEATING (%Q01149) OUTPUTS "ON" AT THE SAME TIME. MTTB COOLING OUTPUT = 1 WHEN CABINET AIR TEMP (TE-4090) > 65 DEG.F, OUTPUT = 0 WHEN CABINET AIR TEMP < 60 DEG.F MTTB HEATING OUTPUT = 1 WHEN CABINET AIR TEMP (TE-4090) < 35 DEG.F, OUTPUT = 0 WHEN CABINET AIR TEMP > 40 DEG.F A/C UNIT OUTSIDE FAN IS TURNED ON WHEN MTTB COOLING OUTPUT = ON A/C UNIT INSIDE FAN IS ON ALL THE TIME. 24. INTENTIONALLY LEFT BLANK 25. INTENTIONALLY LEFT BLANK 26. TURBINE, GENERATOR & HYDRAULIC STARTER LUBE OIL TANK HEATERS & TANK TEMPERATURES: a. HEATERS ON (OUTPUT = 1) WHEN TANK TEMP < 90 DEG.F, HEATERS OFF (OUTPUT = 0) WHEN TANK TEMP > 95 DEG.F 27. WHEN STARTER HIGH SPEED START COMMAND IS REMOVED OR NOTED SHUTDOWNS FOR ANY REASON, WAIT 10 SEC. TO ALLOW PUMP TO RESET TO NEUTRAL POSITION BEFORE DE-ENERGIZING HYD START MOTOR. 28. HYDRAULIC STARTER OIL TANK TEMP & HEAT EXCH. FAN MOTOR a. HEAT EXCH. FAN MOTOR ON = IF TANK TEMP > 110 DEG.F, OFF = IF TANK TEMP < 100 DEG.F 29. INTENTIONALLY LEFT BLANK 30. INTENTIONALLY LEFT BLANK

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683146 REV: A SHEET 5 PAGE 18 OF 22

KAJI POWER

WORKSHEET, SEQUENCER

GE PACKAGED POWER, L.P.

ATLAS PC - 90/70 CONTROL REVISION

SEQ 5

WITH VERSAMAX DISTRIBUTIVE I/O

*** PROPRIETARY INFORMATION *** WORKSHEET NOTES 31. IF UNIT IS RUNNING: OUTPUT = 1 AND LATCH, WHEN NPT > 3240 RPM. OUTPUT = 0 AND UNLATCH, WHEN NPT SPEED < 3060 RPM IF FLSO OR FSWM OR STOPPING AND GENERATOR BREAKER OPEN. 32. MGTB CABINET SPACE HEATER & CABINET AIR TEMPERATURE a. HEATER ON (OUTPUT = 1 ) WHEN CABINET AIR TEMP < 35 DEG.F, HEATER OFF (OUTPUT= 0 ) WHEN CABINET AIR TEMP > 40 DEG.F 33. WX TRANSDUCER IS USED FOR ENGINE POWER LIMITER PER IDM/CONTROL SPEC. AND ALSO CAN BE ENABLED AS MW CONTROL OF THE UNIT WHEN UNIT IS IN PARALLEL OPERATION. 34. HYDRAULIC STARTER OIL HEAT EXCHANGE a. FAN 'ON' IF TE-6003 > 110 DEG F OR TE-4028 > 125 DEG F b. FAN 'OFF' IF TE-6003 < 100 DEG F AND TE-4028 < 115 DEG F c. ANYTIME HYDRAULIC MOTOR 'ON' , OPEN EXHAUST DAMPER d. WHILE HYDRAULIN MOTOR 'OFF' AND IF TE-4028 > 65 DEG F - OPEN EXHAUSTDAMPER. IF TE-4028 < 60 DEG F - CLOSED EXHAUST DAMPER

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683146 REV: A SHEET 5 PAGE 19 OF 22

KAJI POWER

GE PACKAGED POWER, L.P.

WORKSHEET, SEQUENCER

ATLAS PC - 90/70 CONTROL REVISION

SEQ 5

WITH VERSAMAX DISTRIBUTIVE I/O

*** PROPRIETARY INFORMATION *** WORKSHEET NOTES REVISION LIST A

DATE

INITIAL REVISION, REV.A CHANGED NOTE 2, 3 & 12 TO REFLECT TANK LEVEL IN %

9/18/02 RSP

OLD NOTE 2: TURBINE LUBE OIL TANK LEVEL:

9/18/02 RSP

a. HI LEVEL ALARM = 5.0 INCH DECREASING FROM TOP OF TANK ( NOTE: TANK LEVEL INCREASING)

9/18/02 RSP

b. LO LEVEL ALARM = 12.0 INCH INCREASING FROM TOP OF TANK ( NOTE: TANK LEVEL DECREASING)

9/18/02 RSP

c. LO LEVEL SHUTDOWN (FSLO) = 14.0 INCH INCREASING FROM TOP OF TANK ( NOTE: TANK LEVEL DECREASING)

9/18/02 RSP

OLD NOTE 3: HYDRAULIC STARTER OIL TANK LEVEL:

9/18/02 RSP

a. HI LEVEL ALARM = 2.0 INCH DECREASING FROM TOP OF TANK ( NOTE: TANK LEVEL INCREASING)

9/18/02 RSP

b. LO LEVEL ALARM = 6.0 INCH INCREASING FROM TOP OF TANK ( NOTE: TANK LEVEL DECREASING)

9/18/02 RSP

c. LO LEVEL SHUTDOWN (START SHUTDOWN) = 7.0 INCH INCREASING FROM TOP OF TANK ( NOTE: TANK LEVEL DECREASING)

9/18/02 RSP

OLD NOTE 12: GENERATOR LUBE OIL TANK LEVEL:

9/18/02 RSP

a. TANK LEVEL TRANSMITTER MUST SHOW TANK LEVEL GOOD ( NO ALARMS OR SD LEVELS ) BEFORE ALLOWING STARTER ENGAGEMENT.

9/18/02 RSP

b. HI LEVEL ALARM = 5.0 INCH DECREASING FROM TOP OF TANK ( NOTE: TANK LEVEL INCREASING)

9/18/02 RSP

c. LO LEVEL ALARM = 10.65 INCH INCREASING FROM TOP OF TANK ( NOTE: TANK LEVEL DECREASING)

9/18/02 RSP

d. LO LEVEL SHUTDOWN (FSLO) = 13.0 INCH INCREASING FROM TOP OF TANK ( NOTE: TANK LEVEL DECREASING)

9/18/02 RSP

ADDED NOTE 13

9/18/02 RSP

NOTE 23 - ADDED NOTE FOR A/C UNIT FANS OPERATION (INSIDE & OUTSIDE FANS)

9/20/02 RSP

CHANGED NOTE 5 BACK TO AE-XXX NOTES WAS TE-4028 NOTE ========= END =============

ORIGINATED: 9/4/03 PRINTED: 2/11/2004 9:08 AM REV DATE: N/A

WORKSHEET NOTES

DWG NO: 20063-01-683146 REV: A SHEET 5 PAGE 20 OF 22

GE PACKAGED POWER, L.P.

KAJI POWER ATLAS PC - 90/70 CONTROL

SEQUENCER LAYOUT

WITH VERSAMAX DISTRIBUTIVE I/O

GE FANUC 90/70 SYSTEM BASED ON THE FOLLOWING OPERATING CONDITIONS:

X 0C 55 .0 C -40 C

CONTINUOUS DUTY COGENERATION SERVICE OPERATING TEMPERATURE (MIN) (0 C) OPERATING TEMPERATURE (MAX) (55 C) ( Above 45.0 C - Requires cooling fan for CPU) STORAGE TEMPERATURE (MIN) (-40 C)

70.0 C 95 X 4

© Copyright 2003 GE Packaged Power, L.P. All rights reserved. This drawing is the proprietary and/or confidential property of GE Packaged Power, L.P. and is loaned in strict confidence with the understanding that will not be reproduced nor used for any purpose except that for which it is loaned. It shall be immediately returned on demand and is subject to all other terms and conditions of any written agreement or purchase order that incorporates or relates to this drawing. STORAGE TEMPERATURE (MAX) (70 C) % HUMIDITY (NON CONDENSING) NON HAZARDOUS AREA SEISMIC ZONE (UBC)

GE FANUC 90/70 LOCAL MAIN RACK

1 1 1 0 1

RACK, 9 SLOT, REAR MOUNT ------------------------------------------------------------HOT STANDBY, FAST USER MEMORY, CPU MODULE ---------------------------POWER SUPPLY, 24 VDC INPUT 160 WATTS; 5 VDC,12 VDC, (-)12 VDC, 90 WATTS ----------------------------------------------------MODULE, BUS TRANSMITTER -----------------------------------------------------------FAN ASSEMBLY, 24 VDC --------------------------------------------------------------------

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:09 AM REV DATE: N/A

P/N P/N

IC697CHS790 IC697CPX935

P/N P/N P/N

IC697PWR724 IC697BEM713 IC697ACC744

3 1 2 0 1 PK 1 PK

MODULE, ETHERNET INTERFACE, 1 PORT -----------------------------MODULE, MODBUS RTU MASTER / SLAVE, 2 PORT -----------------MODULE, GENIUS I/O BUS CONTROLLER, 1 PORT -------------------MODULE, REDUNDANCY COMMUNICATIONS ------------------------JUMPER, BLANK SLOT INTERRUPT JUMPER ( Pk of 6) --------------BLANK SLOT FILLER (SLOT COVER) (Pk of 6) --------------------------

SEQUENCER LAYOUT

P/N P/N P/N P/N P/N P/N

IC697CMM742 HE697RTM701 IC697BEM731 IC697RCM711 IC697ACC722 IC697ACC720

DRWG NO: 20063-01-683147 REV: A SHEET 1 OF 6

GE PACKAGED POWER, L.P.

KAJI POWER

SEQUENCER LAYOUT

ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

GE FANUC 90/70 LOCAL MAIN RACK LAYOUT SLOT 0

SLOT 1 1 RS-232 2 RS-422

CABLE

24VDC POWER SUPPLY

CPU

A0

A1 W1001-1 W1001-2 W1001-3

SLOT 2 (FUTURE) (BTM)

SLOT 3

SLOT 4

SLOT 6

SLOT 7

SLOT 8

SLOT 9

(FUTURE) (RCM)

BLANK BLANK SLOT SLOT INTERRUPT INTERRUPT JUMPER JUMPER INSTALLED INSTALLED

A2

SLOT 5

A3

ETHERNET

ETHERNET

NO 1 10BASE T (TO FUEL CNTRL)

NO 2 10BASE T (DCS/HMI)

GENIUS BUS COMM (PRI.)

GENIUS BUS COMM (SEC.)

A4

A5

A6

A7

A8

A9

W1004

W1005

W1006-1 W1006-2

W1007-1 W1007-2

W108 *

W1009-1 W1009-2 *

ETHERNET

NO 3 10BASE T (TO FUEL CNTRL)

RTU MASTER SLAVE COMM

AFTER AFTER ETHERNET ETHERNET HUB SWITCH W102 - 1 *

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:09 AM REV DATE: N/A

W1005 - 11 * W1005 - 12 *

SEQUENCER LAYOUT

DRWG NO: 20063-01-683147 REV: A SHEET 2 OF 6

GE PACKAGED POWER, L.P.

KAJI POWER ATLAS PC - 90/70 CONTROL

SEQUENCER LAYOUT

WITH VERSAMAX DISTRIBUTIVE I/O

GE FANUC 90/70 CABLE SCHEDULE FOR LOCAL MKVI MAIN CHASSIS

CABLE NUMBER

CABLE TYPE

FUNCTION

W1001-1 W1001-2 W1001-3

NOT USED NOT USED PROGRAMMING CABLE FOR 90/70 PROGRAMMER

CPU PORT 1 - RS-232 COMMUNICATION CPU PORT 2 - RS-485 COMMUNICATION CPU PORT 3 - RS-485 COMMUNICATION - 90/70 PROGRAMMING PORT

W1004 W120-1 *

ETHERNET CAT 5 SHIELDED CABLE WITH RJ-45 CONNECTORS ETHERNET CAT 5 SHIELDED WITH RJ-45 CONNECTORS

ETHERNET COMMUNICATION TO 4 PORT ETHERNET HUB PORT 2 ETHERNET COMMUNICATION FROM 4 PORT ETHERNET HUB PORT 3 TO HMI (CUSTOMER SUPPLIED)

W1005 ETHERNET CAT 5 SHIELDED CABLE WITH RJ-45 CONNECTORS W1005 -11 *ETHERNET CAT 5 SHIELDED CABLE WITH RJ-45 CONNECTORS W1005-12 * ETHERNET CAT 5 SHIELDED WITH RJ-45 CONNECTORS

ETHERNET COMMUNICATION TO 10 PORT ETHERNET SWITCH PORT 5 ETHERNET COMMUNICATION FROM 10 PORT ETHERNET SWITCH PORTS 4 OR 9 TO CUSTOMER DCS (CUSTOMER SUPPLIED) ETHERNET COMMUNICATION FROM 10 PORT ETHERNET SWITCH PORT 1 TO HMI (CUSTOMER SUPPLIED)

W1006-1 W1006-2

1 PAIR SHIELDED, 22 AWG - LOW CAP ( 8.8 pf/ft) (BELDEN 89182 OR EQUIV.) 1 PAIR SHIELDED, 22 AWG - LOW CAP ( 8.8 pf/ft) (BELDEN 89182 OR EQUIV.)

GENIUS BUS PRIMARY LOOP TO DISTRIBUTIVE I/O NIUs GENIUS BUS PRIMARY LOOP TO DISTRIBUTIVE I/O NIUs

W1007-1 W1007-2

1 PAIR SHIELDED, 22 AWG - LOW CAP ( 8.8 pf/ft) (BELDEN 89182 OR EQUIV.) 1 PAIR SHIELDED, 22 AWG - LOW CAP ( 8.8 pf/ft) (BELDEN 89182 OR EQUIV.)

GENIUS BUS SECONDARY LOOP TO DISTRIBUTIVE I/O NIUs GENIUS BUS SECONDARY LOOP TO DISTRIBUTIVE I/O NIUs

W108 *

ETHERNET CAT 5 SHIELDED WITH RJ-45 CONNECTORS

ETHERNET COMMUNICATION TO FUEL CONTROL ETHERNET #1 (CUSTOMER SUPPLIED)

W1009-1 2 PAIRS W/OVERALL SHIELD, 24 AWG - LOW CAP ( 12.5 pf/ft) (BELDEN 8162 OR EQUIV.) W1009-2 * 2 PAIRS W/OVERALL SHIELD, 24 AWG - LOW CAP ( 12.5 pf/ft) (BELDEN 8162 OR EQUIV.)

MODBUS COMMUNICATION FROM RTU MASTER TO DMMF & VIBRATION MONITOR - RS-485 MODBUS COMMUNICATION FROM RTU SLAVE TO CUSTOMER DCS - RS-485 (CUSOMTER SUPPLIED)

* = CUSTOMER SUPPLIED

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:09 AM REV DATE: N/A

SEQUENCER LAYOUT

DRWG NO: 20063-01-683147 REV: A SHEET 3 OF 6

GE PACKAGED POWER, L.P.

KAJI POWER

SEQUENCER LAYOUT

ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

GE FANUC VERSAMAX DISTRIBUTIVE I/O LAYOUT RESERVED SOFTWARE ADRESSES:

AI & AO DI & DO

(1-64) (1-128)

(65-128) (129-256)

TCP

TCP

(2) NIU (RESISTORS NO. 1 BUS ADDR. 29 (TERM)

1/1 AI N301 %AI1-%AI8

NIU NO. 2 BUS ADDR. 28

(129-192) (257-384)

NOTE:

(193-256) (385-512)

(257-320) (513-640)

(321-384) (641-768)

TCP IF BIU 5 MTTB MTTB NOTE: MTTB NIU USED (2) BIU 6 USED NIU NO. 3 MOVE NIU (TERM) NIU MOVE NO. 6 BUS ADDR. 27 TERM NO. 4 (RESISTORS) NO. 5 TERM BUS ADDR. 24 NOT RESISTORS BUS ADDR. 26 BUS ADDR. 25 RESISTORS NOT SUPPLIED FROM BIU 4 FROM BIU 5 SUPPLIED

2/1 DI N342 %I129-%I144

3/1 MODULE NOT SUPPLIED

4/1 AI AUX N108 TERM%AI193-%AI200

1/2 AI AUX N302 TERM %AI9-%AI16 1/3 AI N303 %AI25-%AI32 1/4 AO N304 %AQ1-%AQ4 1/5 RTD N305 %AI17-%AI20

2/2 DI N343 %I145-%I160 2/3 DO REALY N360 %Q129-%Q144 2/4 DO SOLID ST N361 %Q145-%Q160 2/5 DO SOLID ST N362 %Q161-%Q176

3/2 MODULE NOT SUPPLIED 3/3 MODULE NOT SUPPLIED 3/4 MODULE NOT SUPPLIED 3/5 MODULE NOT SUPPLIED

4/2 RTD N109 %AI201-%AI204 4/3 RTD N110 %AI205-%AI208 4/4 RTD N111 %AI209-%AI212 EXPANDED PWR SUPP. NIU NO.4

1/6 RTD N306 %AI21-%AI24 1/7 DI N340 %I1-%I16 1/8 DI N341 %I17-%I32

2/6 DO SOLID ST N363 %Q177-%Q192 2/7 MODULE NOT SUPPLIED N364 2/8 MODULE NOT SUPPLIED N307

3/6 MODULE NOT SUPPLIED 3/7 MODULE NOT SUPPLIED 3/8 MODULE NOT SUPPLIED

4/5 RTD N112 %AI213-%AI216 4/6 RTD N113 %AI217-%AI220 4/7 RTD N114 %AI221-%AI224

TO BIU 5

1-32 (32) 0 1-24 (24) 1-4 (4)

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:09 AM REV DATE: N/A

129-160 (32) 129-192 (64) 0 0

NA NA NA NA

385-400 (16) 0 193-224 (32) 0

(449-512) (897-1024)

MGTB

MGTB NIU NO. 8 BUS ADDR. 22 NOT SUPPLIED

NIU NO. 7 BUS ADDR. 23

NIU SETUP NOTES: DIALS ARE AS FOLLOWS: OPTIONS DESCRIPTION NAU0123 BUS ADDR. TENS

5/1 TO BIU 6 MODULE NOT SUPPLIED N115

6/1 MODULE NOT SUPPLIED

7/1 AUX AI TERM N222 %AI385-%AI392

8/1 MODULE NOT SUPPLIED

0123456789 N0123

BUS ADDR. ONES BAUD (SET TO 3)

Main Rack

Setting

5/2 MODULE NOT SUPPLIED N116 5/3 RTD N117 5/4 MODULE NOT SUPPLIED N118 5/5 MODULE NOT SUPPLIED N119

6/2 MODULE NOT SUPPLIED 6/3 MODULE NOT SUPPLIED 6/4 MODULE NOT SUPPLIED 6/5 MODULE NOT SUPPLIED

7/2 RTD N223 %AI393-%AI396 7/3 RTD N224 %AI397-%AI400 7/4 RTD N225 %AI401-%AI404 EXPANDED PWR SUPP. NIU NO.7

8/2 MODULE NOT SUPPLIED 8/3 MODULE NOT SUPPLIED 8/4 MODULE NOT SUPPLIED 8/5 MODULE NOT SUPPLIED

1. PWR (IC200PWR001) Default 2. Slot 0 (IC200GBI001) a. Settings - Data Rate bps 19200 - Parity Odd - Stop Bits 1 b. Network - Ser Bus Addr 1 - Baud Rate 153.6 Kbps - Report Faults Enabled - BSM Present No - BSM Contr. No - Out Time Def 2.5 sec - CPU Redund None - Duplex Defaul Off

5/6 MODULE NOT SUPPLIED N120 5/7 MODULE NOT SUPPIED N121 5/8 MODULE NOT SUPPIED N129

6/6 MODULE NOT SUPPLIED 6/7 MODULE NOT SUPPLIED 6/8 MODULE NOT SUPPLIED

7/5 RTD N226 %AI405-%AI408 7/6 RTD N227 %AI409-%AI412 7/7 MODULE NOT SUPPIED N228

8/6 MODULE NOT SUPPLIED 8/7 MODULE NOT SUPPLIED 8/8 MODULE NOT SUPPLIED

- BSM Forced - BSM State - Series 6 Ref - Config Protect c. Memory d. Pwr Consum

4/8 DI N145 %I385-%I400 %I %Q %AI %AQ

(385-448) (769-896)

Unforced Bus A 65535 Disabled Default Defaut

7/8 MODULE NOT SUPPIED 0 0 257-272 (16) 0

SEQUENCER LAYOUT

NA NA NA NA

0 0 385-412 (28) 0

NA NA NA NA

DRWG NO: 20063-01-683147 REV: A SHEET 4 OF 6

GE PACKAGED POWER, L.P.

KAJI POWER

SEQUENCER LAYOUT

ATLAS PC - 90/70 CONTROL WITH VERSAMAX DISTRIBUTIVE I/O

GE FANUC 90/70 FIELD CONTROL PARTS LIST TCP

MTTB

MGTB

TOTAL

QTY.

QTY.

QTY.

QTY.

2

2

1

5

IC200GBI001

NETWORK INTERFACE UNIT, GENIUS BUS

2

3

2

7

IC200PWR002

24VDC EXPANDED 3.3V POWER SUPPLY

0

1

1

2

IC200PWB001

POWER SUPPLY BOOSTER CARRIER (24VDC)

2

7

5

14

IC200ALG620

MODULE, 16 BIT RTD INPUT, 4 CHANNEL

3

2

1

5

IC200ALG240

MODULE, ANALOG INPUT, 16BIT VOLTAGE/ CURRENT, 8 CHANNEL ISOLATED

1

0

0

1

IC200ALG331

MODULE, ANALOG OUTPUT, 16 BIT VOLTAGE/CURRENT, 4 CHANNEL, 1500VAC ISOLATION

4

1

0

5

IC200MDL640

MODULE, DISCRETE INPUT 24VDC, POS./NEG. LOGIC, 16 CHANNEL

1

0

0

1

IC200MDL940

MODULE, RELAY OUTPUT, 2.0 AMP 16 CHANNEL ISOLATED, FORM A

3

0

0

3

IC200MDL741

MODULE, DISCRETE OUTPUT, 24VDC POSITIVE LOGIC 0.5 AMP, w/ESCP 16 CHANNEL

11

10

6

27

IC200CHS022

I/O CARRIER, COMPACT BOX-STYLE

2

0

0

2

IC200CHS003

I/O CARRIER, CONNECTOR STYLE

2

0

0

2

IC200CHS111A

MODULE, I/O INTERPOSING RELAY, 10.0 AMP, FUSED, 16 CHANNEL

2

0

0

2

IC200BL110

CABLE, I/O NON-SHEILDED, TWO CONNECTORS 1.0 M LONG

2

2

0

4

SC1A 1% 150

TERMINATION RESISTOR 150 OHM 1%, 1/2 WATT, (MFG & PART# :CLAROSTAT)

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:09 AM REV DATE: N/A

PART NUMBER

DESCRIPTION

SEQUENCER LAYOUT

DRWG NO: 20063-01-683147 REV: A SHEET 5 OF 6

GE PACKAGED POWER, L.P.

KAJI POWER ATLAS PC - 90/70 CONTROL

SEQUENCER LAYOUT

WITH VERSAMAX DISTRIBUTIVE I/O

REVISION A

DATE INITIAL REVISION, REV.A PAGE 1 - CHANGED CPU MODULE PART # FROM "IC697CGR935" TO "IC697CPX935" 8/15/02 RSP PAGE 4 - REMOVED N246 FROM NIU7 POSITION 8, ADDED "MODULE NOT SUPPLIED" AT NIU7 POSITION 8 8/28/02 RSP PAGE 5- CHANGED PARTS LIST, CHANGED MGTB QUANTITY FROM 1 TO 0 ( TOTAL QTY FROM 6 TO 5) , DISCRETE INPUT MODULE P/N IC2008/28/02 RSP

END ================ END =======================

ORIGINATED: 9/5/03 PRINTED: 2/11/2004 9:09 AM REV DATE: N/A

SEQUENCER LAYOUT

DRWG NO: 20063-01-683147 REV: A SHEET 6 OF 6

Ø3/8"-16UNC X 1/2" [13]DEEP (4X)