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Gas Turbines MS 9001 E’ Operation Training Manual
Jamnagar India
2008
GE Power Systems
All rights reserved by the General Electric Company. No copies permitted without the prior written consent of the General Electric Company. The text and the classroom instruction offered with it are designed to acquaint students with generally accepted good practice for the operation or maintenance of equipment and/or systems. They do not purport to be complete nor are they intended to be specific for the products of any manufacturer, including those of the General Electric Company; and the Company will not accept any liability whatsoever for the work undertaken on the basis of the text or classroom instruction. The manufacturer’s operating and maintenance specifications are the only reliable guide in any specific instance; and where they are not complete, the manufacturer should be consulted. © 2003 General Electric Company
MS 9001 EA Gas Turbine Operation Training Manual
Jamnagar, INDIA
Turbine Numbers : 890 123, 124, 129, 130, 131, 142.
Tab 1
Gas Turbine Overview Gas Turbine Functional Description Gas Turbine Fundamentals Cross Section
Tab 2
Gas Turbine Construction Gas Turbine Arrangement (ML 0406) Compressor Rotor Assembly Turbine Rotor Assembly Variable Inlet Guide Vane Arrangement (ML 0811) Gas Turbine Bucket to Wheel Assembly 1st Stage Gas Turbine Bucket to Wheel Assembly 2nd and 3rd Stage First Stage Nozzle Second Stage Nozzle Third Stage Nozzle N° 2 Bearing Arrangement
Tab 3
GFD91ES A 00203 Cross Section
91-104 E 8224 C 9 EA CPSR 9 EA TURB 91-172 D 7245 A BKT ASM1C BKT ASM1B 9 EA NZ1 9 EA NZ2 9 EA NZ3 9 EA BRG2
Piping Reference Drawings Device Summary (ML 0414) Piping Symbols Basic Control Device Function Numbers Glossary of Terminology International Conversion Tables
137 A 3171 F 277 A 2415 H A 00029 B C 00023 GEK 95 149 C
Tab 4
Oil Systems Lube Oil System Description Schematic Diagram – PP Lube Oil (ML 0416) Hydraulic Supply System Description Schematic Diagram – PP Hydraulic Supply (ML 0434) Inlet Guide Vane Description Schematic Diagram – Inlet Guide Vane (ML 0469)
Tab 5
206 D 6971 D
206 D 7308 A 209 D 7645 B
206 D 6972 D 206 D 6600 C
206 D 6208 C
Water Systems Cooling Water System Description Schematic Diagram – PP Cooling Water (ML 0420) Compressor Water Wash System Description Schematic Diagram – PP Compressor Washing (ML 0442) Gas Turbine Compressor Washing Field Performance Testing NOx Water Injection System Description Schematic Diagram – PP Nox Water Injection (ML 0462)
Tab 8
206 D 6828 B
Fuel Systems Fuel Gas System Description Schematic Diagram – PP Fuel Gas (ML 0422) Liquid Fuel System Description Schematic Diagram – PP Liquid Fuel (ML 0424) Moog Servovalve Assembly Additive Injection Skid System Description Schematic Diagram – PP Additive Injection Skid (ML 0494)
Tab 7
209 D 7043 B
Air Systems Cooling and Sealing Air System Description Schematic Diagram – PP Cooling and Sealing Air (ML 0417) Turbine Cooling Arrangement Atomizing & Purge Air System Description Schematic Diagram – PP Atomizing Air (ML 0425) Fuel Purge System Description Schematic Diagram – PP Fuel Purge (ML 0477)
Tab 6
206 D 6970 E
206 D 6786 B 205 D 4265 D GEK 110 220 B GEK 28 166 A 206 D 6293 C
Other Systems Turbine Control Device System Description Schematic Diagram – Turbine Control Devices (ML 0415) Starting Means System Description (Typical) Schematic Diagram – PP Starting Means (ML 0421) Fire Protection System Description Schematic Diagram – PP Fire Protection (ML 0426) Heating and Ventilation System Description Schematic Diagram – PP Heating & Ventilation (ML 0436) Inlet and Exhaust System Description Schematic Diagram – Inlet and Exhaust Flow - Typical (ML 0471) Gas Detection System Description Schematic Diagram – PP Gas Detection (ML 0474) Performance Monitoring System Description Schematic Diagram – PP Performance Monitoring (ML 0492)
214 D 1164 A 205 D 4866 B 206 D 6966 B 206 D 6596 B 206 D 6968 B 206 D 6595 A 214 D 1258 C
Tab 9
Gas Turbine Operations GE Gas Turbine Performance Characteristics Unit Operation, Turbine
Tab 10
SPEEDTRONIC TM Mk VI Control System Network Topology ( 4108 ) Speedtronic TM Mk VI Turbine Control System HMI for Speedtronic TM Turbine Control – Operator’s Guide Mk VI Control - System Guide – Vol. I
Tab 11
Fund Mk VI G1 Alarm Report
Generator Design and Fundamentals
General GE Generator – Overview Elect. & Mechanical features - Description Description of Generator with Brushless Excitation Operation Generator Fundamentals Operation of Generator with Brushless Excitation Lifting Oil System Skid Schematic Skid Outline Skid Electrical Elementary Drawings Mechanical Outline Data Plate Device Summary Load Equipment Schematic
Tab 13
132 B 8218 E GER 4193 A GEH 6126 Vol. I GEH 6421H Vol. I
Mark VI Commands / Control Support Fundamentals of Mk VI Control System Alarm List
Tab 12
GER 3567 H UOGTDLN
GER 3688 B GEK 95 159 C GEK 106 931 D B 00 082 GEK 95 143 B 123 E 2212 B 245 C 2985 A 211 D 6606 B
134 E 5633 252 C 3997 387 A 4748 A 361 B 3233 A
Generator and Exciter Control Diode Fault Detector Instruction manual for Model 9A5 Brushless Exciters
351-02020-01 A 352-56001-06
GFD91ES Reformatted, February 1994
GE Power Systems Gas Turbine
Gas Turbine Functional Description
I. INTRODUCTION A. General The MS9001 is a simple-cycle, single-shaft gas turbine with a 14 combustor, reverse-flow combustion system. The MS9001 gas turbine assembly consists of six major sections or groups: • Air inlet • Compressor • Combustion system • Turbine • Exhaust • Support systems This portion briefly presents a functional description of how the gas turbine operates and the function that each major component performs in the operation of the gas turbine as air and combustion gases flow through the gas path stream from inlet to exhaust. The gas path is the path by which gases flow through the gas turbine from the air inlet through the compressor, combustion section and turbine, to the turbine exhaust, as illustrated in the flow diagram, Figure 1. The location and functional relationships of the major sections of the MS9000 gas turbine assembly are shown in Figure 2. The identification and location of individual turbine components, mentioned in the following description and remaining sections of the book, are shown in relation to the entire turbine assembly in the longitudinal cutaway view, Figure 3. B. Detail Orientation Throughout this manual, reference is made to the forward and aft ends, and to the right and left sides of the gas turbine and its components. By definition, the air inlet of the gas turbine is the forward end, while the exhaust stack is the aft end. The forward and aft ends of each component are determined in
These instructions do not purport to cover all details or variations in equipment nor to provide for every possible contingency to be met in connection with installation, operation or maintenance. Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser’s purposes the matter should be referred to the GE Company. 1996 GENERAL ELECTRIC COMPANY
GFD91ES
Gas Turbine Functional Description
Heat Recovery Steam Generator
Feedwater
Fuel Combustion Chamber
Compressed Air
Compressor
Exhaust Gases
Gas Turbine
Generator
Optional Equipment
Steam
Steam Turbine
Condenser
Boiler Feed Pump
Boiler Feed Booster Pump
Hotwell
Figure 1. Single-Shaft STAG Unit Flow Diagram Air Inlet
Compressor Section
Section
Turbine
Exhaust
Section
Section
Combustion Section
FWD
AFT
Figure 2. Major Sections of the MS9000 Gas Turbine Assembly
2
1
1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18
Item
Component Name
6 7
8
Speed Ring Thrust Bearing No. 1 Bearing Journal Bearing Inlet Casing Compressor Rotor Forward Compressor Casing Aft Compressor Casing Compressor Discharge Casing Fuel Nozzle Spark Plug Inner Compressor Discharge Casing Combustion Liner Rotor Tie Bolt Combustion Wrapper Transition Piece No. 2 Bearing First-Stage Nozzle
2 3 4 5 14 10 1112 13
– – – 24,000 61,700 6,440 4,920 14,000 62 – 2,650 55 – 15,000 75 – 1,500
Weight (Lbs)
9
19 20 21 22 23 24 25 26 27 28 29 30 31 32 33 34
Item
34
31
Component Name
32
Weight (Lbs)
28 29 30
1,800 Support Ring Turbine Casing & Shrouds 10,410 Second-Stage Nozzle & Diaphragm 2,100 Shroud – Third-Stage Nozzle & Diaphragm 2,260 Exhaust Air Cone 151 Turbine Rotor Assembly 47,300 No. 3 Bearing – Exhaust Hood 19,000 Exhaust Diffuser 13,000 Load Coupling 4,500 Turning Valves – Third-Stage Turbine Wheel & Bucket Assembly – Second-Stage Turbine Wheel & Bucket Assembly – First-Stage Turbine Wheel & Bucket Assembly – Rotor Unit 108,300
33
1516 1718 19 20 21 22 23 24 25 26 27
Gas Turbine Functional Description GFD91ES
Figure 3. Gas Turbine Assembly-Component Identification
3
GFD91ES
Gas Turbine Functional Description like manner with respect to its orientation within the complete unit. The right and left sides of the turbine or of a particular component are determined by standing forward and looking aft.
C. Gas Path Description When the turbine starting system is actuated and the clutch is engaged, ambient air is drawn through the air inlet plenum assembly, filtered and compressed in the 17-stage, axial-flow compressor. For pulsation protection during startup, the 11th-stage extraction valves are open and the variable inlet guide vanes are in the closed position. At high-speed, the 11th-stage extraction bleed valve closes automatically and the variable inlet guide vane actuator energizes to open the inlet guide vanes to the normal turbine operating position. Compressed air from the compressor flows into the annular space surrounding the 14 combustion chambers. From there, it flows into the combustion liners and enters the combustion zone through metering holes in each of the combustion liners for proper fuel combustion. Fuel from an off-base source is provided to 14 equal flow lines, each terminating at a fuel nozzle centered in the end plate of a separate combusition chamber. Prior to being distributed to the nozzles, the fuel is accurately controlled to provide an equal flow into the 14 nozzle feed lines at a rate consistent with the speed and load requirements of the gas turbine. The nozzles introduce the fuel into the combustion chambers where it mixes with the combustion air and is ignited by one or both of the spark plugs. At the instant when fuel is ignited in one combustion chamber, flame is propagated through connecting crossfire tubes to all other combustion chambers. After the turbine rotor approximates operating speed, combustion chamber pressure causes the spark plugs to retract to remove their electrodes from the hot flame zone. The hot gases from the combustion chambers expand into the 14 separate transition pieces attached to the aft end of the combustion chamber liners and flow from there to the three-stage turbine section of the machine. Each stage consists of a row of fixed nozzles followed by a row of rotatable turbine buckets. In each nozzle row, the kinetic energy of the jet is increased, with an associated pressure drop, and in each following row of moving buckets, a portion of the kinetic energy of the jet turns the turbine rotor. Resultant rotation is used to turn the generator rotor and generate electrical power. After passing through the third-stage buckets, the gases are directed into the exhaust hood and diffuser which contains a series of turning vanes to turn the gases from an axial direction to a radial direction, thereby minimizing exhaust hood losses. The gases then pass into the exhaust plenum and are introduced to atmosphere through the exhaust stack. II. BASE AND SUPPORTS A. Accessory Base Most of the mechanical and electrical auxiliary equipment necessary for starting and operating the gas turbine is contained within the accessory compartment. There are many systems involved in the operation of the turbine that are described in detail throughout this set of manuals. Several of these systems have accessory devices, or mechanisms, located in the accessory section. These may include the starting, fuel, lubrication, hydraulic, cooling water, and atomizing air systems. Several major components of the accessory compartment include the starting means, the torque converter and the accessory drive gear. Besides being the main link between the starting system drive components and the gas turbine, the accessory drive gear is the gear reduction unit connected directly to the turbine for driving several of the accessory devices of the gas turbine support systems. These systems and their devices are described in detail in subsequent subsections.
4
Gas Turbine Functional Description
GFD91ES
A pressure gauge and switch cabinet located on the side of the accessory compartment contains panelmounted gauges and switches used with the system mentioned above. Fabricated supports and mounting pads are welded to the upper surface of the accessory base for mounting the accessory gear, starting device, pumps, and other accessory components. Lifting trunnions installed on the base and mounting pads are provided on the bottom surface of the base longitudinal I– beams to facilitate mounting of the base assembly to the foundation. B. Turbine Base The base that supports the gas turbine is a structural steel fabrication of welded steel beams and plate. It provides a support upon which to mount the gas turbine. Two lifting trunnions and supports are provided on each side of the base in line with the structural cross members of the base frame. Machined pads, three on each side on the bottom of the base, facilitate its mounting to the site foundation. Two machined pads atop the base frame are provided for mounting the aft turbine supports. C. Turbine Supports The gas turbine is mounted to its base by vertical supports at three locations; the forward support at the lower half vertical flange of the forward compressor casing and the aft two on either side of the turbine exhaust frame. The forward support is a flexible plate that is bolted and doweled to the turbine base, at the forward base cross frame beam, and bolted and doweled to the forward flange of the forward compressor casing. The aft supports, one on each side of the turbine exhaust frame, are leg-type supports. Both vertical support legs rest on machine pads on the base and attach snugly to the turbine exhaust-frame-mounted support pads. The legs provide centerline support and casing alignment. Fabricated to the outer surface of each aft support leg is a water jacket. Cooling water is circulated through the jackets to minimize thermal expansion of the support legs and assist in maintaining alignment between the turbine and the generator. The support legs maintain the axial and vertical positions of the turbine, while a gib key coupled with the turbine support legs maintains its lateral position. D. Gib Key and Guide Block A gib key is machined on the lower half of the turbine shell. The key fits into a guide block which is welded to the aft cross beam of the turbine base. The key is held securely in place in the guide block with bolts that bear against the key on each side. This key-and-block arrangement prevents lateral or rotational movement of the turbine while permitting axial and radial movement resulting from thermal expansion.
5
GFD91ES
Gas Turbine Functional Description
III. COMPRESSOR SECTION A. General The axial-flow compressor section consists of the compressor rotor and the enclosing casing. Within the compressor casing are the inlet guide vanes, 17 stages of rotor and stator blading, and the exit guide vanes. In the compressor, air is confined to the space between the rotor and stator blading where it is compressed in stages by a series of alternate rotating (rotor) and stationary (stator) airfoil-shaped blades. The rotor blades supply the force needed to compress the air in each stage and the stator blades guide the air so that it enters the following rotor stage at the proper angle. The compressed air exits through the compressor discharge casing to the combustion chambers. Air is extracted from the compressor for bearing sealing and pulsation control. B. Rotor The compressor rotor is an assembly of 15 individual wheels, two stubshafts (each with an integral wheel) a speed ring, tie bolts, and the compressor rotor blades (see Figure 4). Each wheel and the wheel portion of each stubshaft has slots machined around its circumference. The rotor blades and spacers are inserted into these slots and are held in axial position by staking at each end of the slot. The wheels and stubshafts are assembled to each other with mating rabbets for concentricity control and are held together with tie bolts. Selective positioning of the wheels is made during assembly to reduce balance correction. After assembly, the rotor is dynamically balanced to a fine limit. The forward stubshaft is machined to provide the forward and aft thrust faces and the journal for the No. 1 bearing, as well as the sealing surfaces for the No. 1 bearing oil seals and the compressor low-pressure air seals. C. Stator 1. General The stator (casing) area of the compressor section is composed of four major sections (Figure 5). These are the: • Inlet casing • Forward compressor casing • Aft compressor casing • Compressor discharge casing These sections, in conjunction with the turbine shell, form the primary structure of the gas turbine. They support the rotor at the bearing points and constitute the outer wall of the gas path annulus. The casing bore is maintained to close tolerances with respect to the rotor blade tips for maximum efficiency.
6
Gas Turbine Functional Description
GFD91ES
Inlet Casing Forward Compressor Casing
Compressor Discharge Casing Assembly Aft Compressor Casing
Figure 4. Compressor Stator-Cutaway View 2. Inlet Casing The inlet casing (see Figure 5) is located at the forward end of the gas turbine. Its prime function is to uniformly direct air into the compressor. The inlet casing also supports the No. l bearing housing, a separate casting that contains the No. 1 bearing. The No. 1 bearing housing is supported in the inlet casing on machined surfaces on either side of the inner bellmouth of the lower half casing. To maintain axial and radial alignment with the compressor rotor shaft, the bearing housing is shimmed, doweled and bolted in place at assembly. The inner bellmouth is positioned to the outer bellmouth by eight airfoil-shaped radial struts that provide structural integrity for the inlet casing. The struts are cast into the bellmouth walls. Variable inlet guide vanes are located at the aft end of the inlet casing as shown on Figure 5. The position of these vanes affects the quantity of compressor air flow. Movement of these guide vanes is accomplished by the inlet guide vane control ring that turns individual pinion gears attached to
Inlet Casing Lower Half
Variable Inlet Guide Vanes Number One Bearing Inlet Guide Vane Control Ring
Figure 5. Air Inlet Casing With Variable Inlet Guide Vanes
7
GFD91ES
Gas Turbine Functional Description the end of each vane. The control ring is positioned by a hydraulic actuator and linkage arm assembly. The pinion gears and control ring arrangement is shown in Figure 6. 3. Forward Casing The forward compressor casing contains the first four compressor stator stages. It also transfers the structural loads from the adjoining casing to the forward support which is bolted and doweled to this compressor casing’s forward flange. The forward compressor casing is equipped with two large integrally cast trunnions which are used to lift the gas turbine when it is separated from its base. 4. Aft Casing The aft compressor casing contains the 5th through 10th compressor stages. Extraction ports in the casing permit removal of 5th and 11th-stage compressor air. This air is used for cooling and sealing functions and is also used for starting and shutdown pulsation control. 5. Discharge Casing The compressor discharge casing is the final portion of the compressor section. It is the longest single casting. It is situated at the midpoint — between the forward and aft supports and is, in effect, the keystone of the gas turbine structure. The functions of the compressor discharge casings are to contain the final seven compressor stages, to form both the inner and outer walls of the compressor diffuser, and to join the compressor and turbine stators. They also provide support for the No. 2 bearing, the forward end of the combustion wrapper, and the inner support of the first-stage turbine nozzle. The compressor discharge casing (Figure 7) consists of two cylinders, one being a continuation of the compressor casings and the other an inner cylinder that surrounds the compressor rotor. The two cylinders are concentrically positioned by twelve radial struts. These struts flair out to meet the larger diameter of the turbine shell, and are the primary load bearing members in this portion of the gas turbine stator. The supporting structure for the No. 2 bearing is contained within the inner cylinder. A diffuser is formed by the tapered annulus between the outer cylinder and inner cylinder of the discharge casing. The diffuser converts some of the compressor exit velocity into added pressure. 6. Blading The compressor rotor and stator blades are airfoil shaped and designed to compress air efficiently at high blade tip velocities. The blades are attached to their wheels by dovetail arrangements. The dovetail is very precise in size and position to maintain each blade in the desired position and location on the wheel. The compressor stator blades are airfoil shaped and are mounted by similar dovetails into ring segments. The ring segments are inserted into circumferential grooves in the casing and are held in place with locking keys. The stator blades of the last nine stages and two exit guide vanes have a square base dovetail that are inserted directly into circumferential grooves in the casing. Locking keys also hold them in place.
8
Gas Turbine Functional Description
GFD91ES
Ring Gear
Control Ring
Pinion Gears
Gear Ring Cover
Figure 6. Inlet Guide Vane Control Ring and Pinion Gears
9
GFD91ES
Gas Turbine Functional Description
Compressor Discharte Case-Upper Half Number Two Bearing Housing
Compressor Discharge Case-Lower Half
Inner Compressor Discharge Case
Figure 7. Compressor Discharge Casing Assembly
10
Gas Turbine Functional Description
GFD91ES
IV. COMBUSTION SYSTEM A. General The combustion system is a reverse-flow type with 14 combustion chambers arranged around the periphery of the compressor discharge casing (Figure 8). This system also includes fuel nozzles, spark plug ignition system, flame detectors, and crossfire tubes. Hot gases, generated from burning fuel in the combustion chambers, are used to drive the turbine. High-pressure air from the compressor discharge is directed around the transition pieces and into the combustion chamber liners. This air enters the combustion zone through both metering holes (for proper fuel combustion) and through slots (to cool the combustion liner). Fuel is supplied to each combustion chamber through a nozzle designed to disperse and mix the fuel with the proper amount of combustion air. Orientation of the combustion chambers around the periphery of the compressor is shown on Figure 9. Combustion chambers are numbered counterclockwise when viewed looking downstream and starting from the top of the machine. Spark plugs and flame detector locations are also shown. B. Combustion Wrapper The combustion wrapper is a fabricated casing that encloses the combustion area. It provides a supporting surface for the combustion chamber assemblies. A plenum is formed by the combustion wrapper in which the compressor discharge air flow is directed to the combustion chambers. The forward face of the combustion wrapper is slanted at a 13° angle from the vertical and contains the machined openings for mounting the 14 covers of the combustion chamber assemblies (see Figure 9 and 10). Support plates for mounting the spark plugs and flame detectors are recessed in wells in the outer wall of the wrapper. The wrapper is supported by the compressor discharge casing and the turbine shell. C. Combustion Chambers Discharge air from the axial-flow compressor flows into each combustion flow sleeve from the combustion wrapper (Figure 10). The air flows upstream along the outside of the combustion liner toward the liner cap. This air enters the combustion chamber reaction zone through the fuel nozzle swirl tip, the metering holes in both the cap and liner and combustion holes in the forward half of the liner. The hot combustion gases from the reaction zone pass through a thermal soaking zone and then into a dilution zone where additional air is mixed with the combustion gases. Metering holes in the dilution zone allow the correct amount of air to enter and cool the gases to the desired temperature. Along the length of the combustion liner and in the liner cap are openings whose function is to provide a film of air for cooling the walls of the liner and cap as shown in Figure 11. Transition pieces direct the hot gases from the liners to the turbine nozzles. All combustion liners, flow sleeves and transition pieces are identical. D. Spark Plugs Combustion is initiated by means of the discharge from two high-voltage retractable-electrode spark plugs installed in adjacent combustion chambers. These spring-injected, pressure-retracted plugs receive their energy from ignition transformers. At firing, a spark at one or both of these plugs ignites the gases in a chamber; the remaining chambers are ignited by crossfire through the tubes that interconnect
11
GFD91ES
Gas Turbine Functional Description
Spark Plug Combustion Liner Fuel Nozzle Compressor Discharge Casing
Transition Piece
Combustion Cover Atomizing Air Manifold
Flame Detector
Fuel Oil Line
Combustion Wrapper
Figure 8. Combustion System Arrangement
12
Gas Turbine Functional Description
GFD91ES
Spark Plugs
Flame Detectors
Figure 9. Combustion Chamber Arrangement
13
14
Dual Fuel Nozzle
View A
Crossfire Tube
Combustion Cover
Flow Sleeve
Spark Plug
Combustion Wrapper
Compresspr Discharge Casing
C L Chamber Flow Sleeve
Combustion Air
Cooling Slots
Transition Piece
Slot Cooled Liner Combustion Wrapper
Turbine Shell
GFD91ES Gas Turbine Functional Description
Figure 10. Combustion Chamber Details and Flow Diagram
Gas Turbine Functional Description
Liner Stop
GFD91ES
Slot Cooling Holes
Crossfire Tube Collar
Spring Seal
Combustion Holes
Figure 11. Slot-Cooled Combustion Liner
the reaction zone of the remaining chambers. As rotor speed increases, chamber pressure causes the spark plugs to retract and the electrodes are removed from the combustion zone. E. Ultraviolet Flame Detectors During the starting sequence, it is essential that an indication of the presence or absence of flame be transmitted to the control system. For this reason, a flame monitoring system is used consisting of sensors which are installed on adjacent combustion chambers and an electronic amplifier mounted in the turbine control panel. The ultraviolet flame sensor contains a gas-filled detector. The gas within this detector is sensitive to the presence of ultraviolet radiation emitted by a hydrocarbon flame. A dc voltage, supplied by the amplifier, is impressed across the detector terminals. If flame is present, the ionization of the gas in the detector allows conduction in the circuit which gives an output defining “flame.” Conversely, the absence of flame will generate an opposite output defining “no flame.” After the establishment of flame, if voltage is reestablished to both sensors defining the loss (or lack) of flame, a signal is sent to a relay panel in the turbine control circuitry where auxiliary relays in the turbine firing trip circuit, starting means circuit, etc. shut down the turbine. “FAILURE TO FIRE” or “LOSS OF FLAME” is also indicated on the annunciator. If a loss of flame is sensed by only one flame detector sensor, the control circuitry will cause an annunciation of only this condition. F. Fuel Nozzles Each combustion chamber is equipped with a fuel nozzle that emits a metered amount of fuel into the combustion liner. Gaseous fuel is admitted directly into each chamber through metering holes located in the outer wall of the gas swirl tip. When liquid fuel is used, it is atomized in the nozzle swirl chamber by means of high pressure air. The atomized fuel/air mixture is then sprayed into the combustion zone. Action of the tip imparts a swirl to the combustion air with the result of more complete combustion and essentially smoke-free operation of the unit. See Figure 12 for fuel nozzle details.
15
GFD91ES
Gas Turbine Functional Description Gasket (3) Body Nozzle Body
Retainer (2) Pilot (1) Transition Piece Assembly (Includes 1, 2 & 3)
Fuel Oil Connection
Swirl Chamber
Inner Cap
Swirl Tip Assembly
Fuel Nozzle Ring Atomizing Air Connection
Gas Connection (If Used)
Figure 12. Fuel Nozzle Assembly (Typical Air Atomized, Dual Fuel)
Detailed inspection and maintenance information on the fuel nozzles and other combustion system components is included in the Maintenance section of this manual. G. Crossfire Tubes All fourteen combustion chambers are interconnected by means of crossfire tubes. These tubes allow flame from the fired chambers to propagate to the unfired chambers. V. TURBINE SECTION A. General The three-stage turbine section is the area where energy, in the form of high-temperature pressurized gas produced by the compressor and combustion sections, is converted to mechanical energy. MS9000 gas turbine hardware includes the turbine rotor, turbine casing exhaust frame, exhaust diffuser, nozzles and shrouds. B. Turbine Rotor 1. Structure The turbine rotor assembly (Figure 13) consists of two wheel shafts; the first, second, and third-stage turbine wheels with buckets; and two turbine spacers. Concentricity control is achieved with mating rabbets on the turbine wheels, wheel shafts, and spacers. The wheels are held together with through bolts. Selective positioning of rotor members is performed to minimize balance corrections.
16
Gas Turbine Functional Description
GFD91ES
2nd-Stage Turbine Wheel Assembly
17 Stage Compressor Wheel & Blade Assembly
3rd-Stage Turbine Wheel Assembly
1st-Stage Turbine Wheel Assembly Forward Turbine Wheel Shaft
Aft Turbine Wheel Shaft
Figure 13. Compressor and Turbine Rotor Assembly
17
GFD91ES
Gas Turbine Functional Description The forward wheel shaft extends from the first-stage turbine wheel to the aft flange of the compressor rotor assembly. The journal for the #2 bearing is a part of the wheel shaft. The aft wheel shaft connects the third-stage turbine wheel to the load coupling. It includes the #3 bearing journal. Spacers between the first and second, and between the second and third-stage turbine wheels determine the axial position of the individual wheels. These spacers carry the diaphragm sealing lands. The forward faces of the spacer include radial slots for cooling air passages. The first- and secondstage spacer also has radial slots for cooling air passages on the aft face. 2. Buckets The turbine buckets (Figure 14) increase in size from the first to the third-stage. Because of the pressure reduction resulting from energy conversion in each stage, an increased annulus area is required to accommodate the gas flow; thus necessitating increasing the size of the buckets. The first-stage buckets are the first rotating surfaces encountered by the extremely hot gases leaving the first-stage nozzle. Each first-stage bucket contains a series of longitudinal air passages for bucket cooling as shown in Figure 15. Air is introduced into each first-stage bucket through a plenum at the base of the bucket dovetail. It flows through cooling holes extending the length of the bucket and exits at the recessed bucket tip. The holes are spaced and sized to obtain optimum cooling of the airfoil with minimum compressor extraction air.
3rd-Stage Turbine Bucket
Integral Shroud
2nd-Stage Turbine Bucket 1st-Stage Turbine Bucket
Bucket Vane
Shank
Dovetail
Figure 14. First, Second and Third-Stage Turbine Buckets
18
Gas Turbine Functional Description
GFD91ES
Cross Section of a Cooling Hole in Bucket
Cooling Air Inlet Holes
Cooling Holes & Squealer Section Suction Side (Convex) Bucket Blade
Platform
Pressure Side (Concave)
Bucket Shank
Figure 15. First-Stage, Air-Cooled Bucket Details
19
GFD91ES
Gas Turbine Functional Description Like the first-stage buckets, the second-stage buckets are cooled by span-wise air passages running the length of the airfoil. Since the lower temperatures surrounding the bucket shanks do not require shank cooling, the second-stage cooling holes are fed by a plenum cast into the bucket shank. Spanwise holes provide cooling air to the airfoil at a higher pressure than shank holes. This increases the cooling effectiveness in the airfoil with minimum penalty to the thermodynamic cycle. The third-stage buckets are not internally air-cooled; the tips of these buckets, like the second-stage buckets, are enclosed by a shroud which is a part of the tip seal. These shrouds interlock from bucket to bucket to provide vibration damping. Turbine buckets for each stage are attached to their wheels by straight, axial-entry, multiple-tang dovetails that fit into matching cutouts in the turbine wheel rims. Bucket vanes are connected to their dovetails by means of shanks (Figure 14). These shanks locate the bucket-to-wheel attachment at a significant distance from the hot gases, reducing the temperature at the dovetail. The turbine rotor assembly is arranged so that the buckets can be replaced without unstacking the wheels, spacers, and wheel shaft assemblies. 3. Cooling The turbine rotor must be cooled to maintain reasonable operating temperatures and, therefore, assure a longer turbine service life. Cooling is accomplished by a positive flow of cool air radially outward through a space between the turbine wheel with buckets and the stator, into the main gas stream. This area is called the wheelspace. 4. First-Stage Wheelspaces The first-stage forward wheelspace is cooled by compressor discharge air. High-pressure packing is installed at the aft end of the compressor rotor between the rotor and the inner barrel of the compressor discharge casing. Part of the leakage through this labyrinth furnishes the air flow through the first-stage forward wheelspace. This cooling air flow discharges into the main gas stream aft of the first-stage nozzle. In addition, a small amount of air is supplied by a single hole at the forward end of the inner barrel. This air provides adequate cooling during all transient operation conditions. The first-stage aft wheelspace is cooled by compressor discharge air supplied through the secondstage nozzle. Some of this first-stage aft wheelspace cooling air flows through the second-stage inner seal while the remainder returns to the gas path forward of the second-stage nozzle. 5. Second-Stage Wheelspaces The second-stage forward wheelspace is cooled by leakage from the first-stage aft wheelspace through the interstage labyrinth. This air returns to the gas path at the entrance of the second-stage buckets. The second-stage aft wheelspace is cooled by air from the internal extraction system. This air enters the wheelspace through slots in the forward face of the spacer. Some of this second-stage aft cooling air flows through the third-stage inner seal while the remainder returns to the gas path at the thirdstage nozzle entrance.
20
Gas Turbine Functional Description
GFD91ES
6. Third-Stage Wheelspaces The third-stage forward wheelspace is cooled by leakage from the second-stage aft wheelspace through the interstage labyrinth. This air re-enters the gas path at the third-stage bucket entrance. The third-stage aft wheelspace obtains its cooling air from the exhaust frame cooling system. This air enters the wheelspace at the rear of the third-stage turbine wheel and then flows into the gas path at the entrance to the exhaust diffuser. C. Turbine Stator 1. Structure The turbine shell and the exhaust frame constitute the major portion of the MS9000 gas turbine stator structure. The turbine nozzles, shrouds, #3 bearing and turbine exhaust diffuser are internally supported from these components. 2. Turbine Casing (Shell) The turbine shell controls the axial and radial positions of the shrouds and nozzles. It determines turbine clearances and the relative positions of the nozzles to the turbine buckets. This positioning is critical to gas turbine performance. See Figure 16 for positions of these components. Hot gases contained by the turbine shell are a source of heat flow into the shell. To control the shell diameter, it is important that the shell design reduces the heat flow into the shell and limits its temperature. Heat flow limitations incorporate insulation, cooling, and multi-layered structures. The external surface of the shell incorporates cooling air passages. Flow through these passages is generated by an off-base cooling fan. Structurally, the shell forward flange is bolted to flanges at the aft end of the compressor discharge casing and combustion wrapper. The shell aft flange is bolted to the forward flange of the exhaust frame. Trunnions cast onto the sides of the shell are used with similar trunnions on the forward compressor casing to lift the gas turbine when it is separated from its base. 3. Nozzles In the turbine section, there are three stages of stationary nozzles (Figure 16) which direct the highvelocity flow of the expanded hot combustion gas against the turbine buckets causing the turbine rotor to rotate. Because of the high pressure drop across these nozzles, there are seals at both the inside and the outside diameters to prevent loss of system energy by leakage. Since these nozzles operate in the hot combustion gas flow, they are subjected to thermal stresses in addition to gas pressure loadings. 4. First-Stage Nozzles The first-stage nozzle (Figure 17) receives the hot combustion gases from the combustion system via the transition pieces (Figure 10). The transition pieces are sealed to both the outer and inner sidewalls on the entrance side of the nozzle. This minimizes leakage of compressor discharge air into the nozzles. The 18 cast nozzle segments, each with two partitions or airfoils, are contained by a horizontally-split retaining ring which is centerline supported to the turbine shell on lugs at the sides
21
GFD91ES
Gas Turbine Functional Description
First-Stage Shroud
Second-Stage Shroud Second-Stage Nozzle
Third-Stage Nozzle Third-Stage Shroud
First-Stage #2 Retaining Ring
First-Stage Nozzle Third-Stage Diaphragm
First-Stage Nozzle Support Ring
Second-Stage Diaphragm Segment Third-Stage Turbine Wheel First-Stage Turbine Wheel
Second-Stage Turbine Wheel
Figure 16. Turbine Section-Cutaway View
22
Gas Turbine Functional Description
GFD91ES
Outer Wall Cooling Holes Cooling Air Impingement Plate Partition Core Cooling Holes (Air Inlet)
Assembled View
Cooling Holes (Air Exit)
Suction End of Partition
Hollow Core of Partition
Trailing Edge Cooling Holes (Not Visible) Pressure Side Cooling Holes (Air Exit)
Partition
Partially Assembled View
Figure 17. First-Stage Turbine Nozzle Segment
23
GFD91ES
Gas Turbine Functional Description and guided by pins at the top and bottom vertical centerlines. This permits radial growth of the retaining ring, resulting from changes in temperature, while the ring remains centered in the shell. The aft outer diameter of the retaining ring is loaded against the forward face of the first-stage turbine shroud and acts as the air seal to prevent leakage of compressor discharge air between the nozzle and shell. On the inner sidewall, the nozzle is sealed by direct bearing of the nozzle inner load rail against the first-stage nozzle support ring bolted to the compressor discharge casing. The nozzle is prevented from moving forward by the lugs welded to the aft outside diameter of the retaining ring at 45° from vertical and horizontal centerlines. These lugs fit in a groove machined in the turbine shell just forward of the first-stage shroud T-hook. By moving the horizontal joint support block and the bottom centerline guide pin, the lower half of the nozzle can be rolled out with the turbine rotor in place. 5. Second-Stage Nozzle Combustion air exiting from the first-stage buckets is again expanded and redirected against the second-stage turbine buckets by the second-stage nozzle. This nozzle is made of 16 cast segments (Figure 19), each with three partitions or airfoils. The male hooks on the entrance and exit sides of the outer sidewall fit into female grooves on the aft side of the first-stage shrouds and on the forward side of the second-stage shroud to maintain the nozzle concentric with the turbine shell and rotor. This close tongue-and-groove fit between nozzle and shrouds acts as an outside diameter air seal. The nozzle segments are held in a circumferential position by radial pins from the shell into axial slots in the nozzle outer sidewall. The second-stage nozzle is cooled by compressor discharge air. 6. Third-Stage Nozzles The third-stage nozzle receives the hot gas as it leaves the second-stage buckets, increases its velocity by pressure drop, and directs this flow against the third-stage buckets. The nozzle consists of 16 cast segments, each with four partitions or airfoils (Figure 18). It is held at the outer sidewall forward and aft sides in grooves in the turbine shrouds in a manner identical to that used on the second-stage nozzle. The third-stage nozzle is circumferentially positioned by radial pins from the shell. 7. Diaphragms Attached to the inside diameters of both the second and third-stage nozzle segments are the nozzle diaphragms (Figure 18). These prevent air leakage past the inner sidewall of the nozzles and the turbine rotor. High/low labyrinth seal teeth are machined into the inside diameter of the diaphragm. They mate with opposing sealing lands on the turbine rotor. Minimal radial clearance between stationary parts (diaphragm and nozzles) and the moving rotor are essential for maintaining low interstage leakage. This results in higher turbine efficiency. 8. Shrouds Unlike the compressor blading, the turbine bucket tips do not run directly against an integral machined surface of the casing but against annular curved segments called turbine shrouds. The
24
Gas Turbine Functional Description
GFD91ES
Nozzle Partitions
Nozzle Segment
Cooling Air Exit Openings
Diaphragm Segment
Seal Teeth
Nozzle Segment
Nozzle Partition
Figure 18. Second- and Third-Stage Turbine Nozzle and Diaphragm Segments
25
GFD91ES
Gas Turbine Functional Description shrouds’ primary function is to provide a cylindrical surface for minimizing bucket tip clearance leakage. This bucket-to-shroud interface can be seen in Figure 19. The turbine shrouds’ secondary function is to provide a high thermal resistance between the hot gases and the comparatively cool shell. In doing this, shell cooling load is drastically reduced, the shell diameter is controlled, the shell roundness is maintained, and important turbine clearances are assured. The shroud segments are maintained in the circumferential position by radial pins from the shell. Joints between shroud segment are sealed by interconnecting tongues and grooves. 9. Exhaust Frame Assembly The exhaust frame assembly (Figure 20) consists of the exhaust frame and the exhaust diffuser. The exhaust frame is bolted to the aft flange of the turbine shell. Structurally, the frame consists of an outer cylinder and inner cylinder interconnected by ten radial struts. On the inner gas path surfaces of the two cylinders are attached the inner and outer diffusers. The #3 bearing is supported from the inner cylinder. The exhaust diffuser (Figure 21), located at the extreme aft end of the gas turbine, bolts to, and is supported by, the exhaust frame. The exhaust diffuser is a fabricated assembly consisting of an inner cylinder and an outer divergent cylinder that flairs at the exit end at a right angle to the turbine centerline. At the exit end of the diffuser, between the two cylinders, are five turning vanes mounted at the bend. Gases exhausted from the third turbine stage enter the diffuser where velocity is reduced by diffusion and pressure is recovered. At the exit of the diffuser, turning vanes direct the gases into the exhaust plenum. Exhaust frame radial struts cross the exhaust gas stream. These struts position the inner cylinder and #3 bearing in relation to the outer casing of the gas turbine. The struts must be maintained at a uniform temperature to control the center position of the rotor in relation to the stator. This temperature stabilization is accomplished by protecting the struts from exhaust gases with a metal fairing fabricated into the diffuser and then forcing cooling air into this space around the struts. Turbine shell cooling air enters the space between the exhaust frame and the diffuser and flows in two directions — into the turbine shell cooling annulus and also down through the space between the struts and the airfoil fairings surrounding the struts and, subsequently, into the load shaft tunnel and turbine third-stage aft wheelspace.
VI. BEARINGS A. General The MS9000 gas turbine unit contains three main journal bearings used to support the gas turbine rotor. The unit also includes thrust bearings to maintain the rotor-to-stator axial position and support the thrust loads developed on the rotor. These bearings and seals are incorporated in three housings: one at the inlet casing, one in the discharge casing, and one in the exhaust frame. These bearings are pressure-lubricated by oil supplied from the main lubricating oil system. The oil flows through branch lines to an inlet in each bearing housing.
26
Gas Turbine Functional Description
GFD91ES
Figure 19. Turbine Area-Top Half Removed Showing Turbine Nozzles and Wheel Assemblies
27
GFD91ES
Gas Turbine Functional Description
Exhaust Diffuser
Enlarged View Of Strut Cross Section
Assembled View Exhaust Frame
Inner Cylinder
Outer Cylinder Exhaust Frame Exhaust Frame Airfoil Strut Lower Half Assembly
Figure 20. Exhaust Frame Assembly
28
Gas Turbine Functional Description
GFD91ES
Insulation Pack
Inner Diffuser
Turning Vanes
Outer Difference
Figure 21. Exhaust Diffuser
29
GFD91ES
Gas Turbine Functional Description The bearings used in this gas turbine are classified as follows: No.
Class
Type
1
Loaded Unloaded
Tilting Pad–Thrust Equalizing Tilting Pad-Non-Thrust Equalizing
1 2 3
Journal Journal Journal
Elliptical Elliptical Tilting Pad
B. Elliptical Journal Bearings 1. General Elliptical bearings are the predominant type of journal bearings used in gas turbines. These are characterized by their non-cylindrical bores, and are designed to improve the stability of the shafts at high speeds. In the design of these bearings, convergent clearance regions exist even at a concentric shaft position. The convergence increases with an increase in shaft eccentricity. This convergency creates high-pressure regions which, in effect, puts an additional load on the bearing; a factor which tends to improve the shaft stability. The extra clearance space, as compared with a cylindrical bearing of a diameter equal to the inscribed circle in these bearings, increases the oil flow and also often reduces power losses resulting in lower temperature rises in the bearing. Figure 22 shows the elliptical journal bearing installed in a typical bearing assembly as used in General Electric gas turbine units. 2. Description The elliptical bearing is made up of two cylindrical halves brought together so that their centers are displaced several millimeters from the bearing center. It is manufactured by placing shims at the horizontal split and then machining a cylindrical bore. The shims are then removed and the two halves are brought together to form the elliptical bearing as shown in Figure 23. 3. Maintenance Refer to the Maintenance section of this Service Manual for information. C. Tilting Pad Journal Bearings 1. General In those gas turbine applications where a shaft may exhibit susceptibility to whirl or misalignment, tilting pad bearings are frequently employed. These bearings are distinguished by their movable segments or pads, which give them very stable dynamic properties. Tilting pad bearings operate in the hydrodynamic mode just like elliptical types which are more commonly employed in gas turbines. The pads are assembled creating converging passages between
30
Gas Turbine Functional Description
GFD91ES
1
2
3
1. Oil Baffle 2. Journal Bearing 3. Tilting-pad Thrust Bearing
4
5
6
4. Bearing Housing 5. Flatland Thrust Bearing 6. Oil Seal
Figure 22. Typical Bearing Assembly with Elliptical Journal (Bottom Lobe) and Thrust Bearings (Lower Half) Installed
RL is the radius of each lobe d RL
RL
d RC
RC is the radius of the inscribed circle. d is the distance at which the center of each lobe arc is displaced from the center of the inscribed circle.
Figure 23. Elliptical Journal Bearing Schematic Diagram
31
GFD91ES
Gas Turbine Functional Description each pad and the journal surface. These converging passages generate a high-pressure oil film beneath each pad which produces a symmetric loading or “clamping” effect on the journal. This is a stabilizing influence which is very effective in resisting shaft whirl particularly in bearings that are lightly loaded and operating at high speed. Because the pads are point pivoted, they are free to move in two dimensions which makes them capable of tolerating both offset and angular shaft misalignment. Another very desirable characteristic of this bearing is its ability to run cool when supporting heavy loads, due to the relatively short arc length of the individual pads. Figure 24 shows a typical tilting pad journal bearing employed in a General Electric gas turbine. This particular bearing has five pads which is a common design. 2. Description A tilting pad journal bearing is comprised of pads and a retainer ring. The pads are made from a cylindrical steel shell which is babbitted, cut into sectors, and then finish bored. In their final assembled configuration, the pads are displaced inward toward the bearing center to produce converging clearances when assembled around the bearing journal. The inscribed clearance circle formed by the pads is located high relative to the outside diameter of the retaining ring. This allows the rotor to run concentric with respect to the stator under full-speed operating conditions. Figure 25 describes the clearance geometry present in a tilting pad bearing. In most designs, the pad pivots are offset toward the trailing edges of the pads. This is done deliberately to improve the hydrodynamic operation of the bearing. The retainer ring serves to locate and support the pads. It is a horizontally-split member which contains the pad support pins, adjusting shims, oil feed orifices, and oil discharge seals. The outside diameter of the retainer ring is carefully machined to produce a good fit when inserted into the bearing housing. The oil discharge seals have babbitted surfaces and float on the shaft. The support pins and shims transmit the loads generated at the pad surfaces and are used to set the bearing clearance. An anti-rotation pin extends from one edge of the lower half of the retainer ring. This pin locates the bearing within its housing and prevents the bearing from rotating with the journal. The anti-rotation pin also provides the correct installation of the bearing liner in the bearing housing which is essential. The offset of individual pads on their supporting pins makes the bearing non-symmetrical with respect to shaft rotation. Some of the components of a tilting pad bearing are shown in Figures 24 and 27. Oil is fed from the lower half of the bearing housing into the annulus which surrounds the retainer ring. Orifice holes are drilled radially through the ring into the gaps that exist between the individual pads. These orifices serve to control the flow entering the bearing. The oil is then drawn by the shaft into the gap between shaft and pads. Floating ring seals with babbitted surfaces restrict the outgoing oil flow thereby maintaining an adequate oil supply within the pad region. Excess oil drains from the liner through slots in the bottom area of the lower half of the liner. 3. Maintenance A minimum of maintenance is required for tilting pad journal bearings. During the regularly scheduled complete unit disassembly, the bearings should be thoroughly cleaned and inspected. Special attention should be given to the pad support pins to be sure that they do not exhibit fretting or excessive wear. The pad must also be inspected for scratches, loose particles and any high or low spots which may exist. These must be removed or repaired in accordance with procedures used in the maintenance of babbitted surfaces. The bearing clearance must also be checked especially if the pad pins have shown any signs of wear. This can be done with either a three-point micrometer or a ma-
32
Gas Turbine Functional Description
GFD91ES
3 4
2 5
CL Pad CL Pivot Pin Offset Trailing Edge of Pad
Rotation RC d
RP
3 6 7
1
8
1. 2. 3. 4.
Antirotation Pin Pivit Pin Oil Feed Hole Pad Retaining Ring (Upper Half)
RP is the radius of each pad
5. Pad Retaining Ring (Lower Half) 6. Pad 7. Pad Holding Pin 8. Oil Seal Surfaces
RC is the radius of the inscribed clearance circle. d is the pad preload distance
Figure 24. Typical Tilting Pad Journal Bearing
Figure 25. Tilting Pad Journal Bearing Schematic Diagram
Upper Half Lower Half
Figure 26. Upper and Lower Halves of a Typical Tilting Pad Journal Bearing-Disassembled
33
GFD91ES
Gas Turbine Functional Description
1
2
7
1. 2. 3. 4.
3
6
Seal Ring Assembly Bearing Liner Pad Pivot Pin Bushing Headless Shoulder Pin
4
5
5. Pivot Pin 6. Shim 7. Tilting Pad Retainer
Figure 27. Tilting Pad Journal Bearing-Section Through Pad
34
Gas Turbine Functional Description
GFD91ES
chined mandrel. If the clearance is found to be outside of drawing tolerances, it must be reset by adjusting the shims. When cleaning the bearing, be sure that the bearing surfaces do not come in contact with hard objects which may scratch or dent them. The bearing should be cleaned by using kerosene and clean rags. Do no use cotton waste as it will leave lint on the bearing surfaces. After the bearing has been cleaned and inspected, the bearing parts should be coated with a good rust-inhibited turbine oil, to protect against corrosion, and wrapped to protect against mechanical damage. If it should be necessary to hold the bearing parts in storage, the parts should be coated with a good rust-inhibited grease and wrapped in a moisture and vapor-proof barrier such as vinylidene chloride-coated, paper-backed foil. D. Bearing Lubrication 1. General The three gas turbine bearing housings are pressure-lubricated with oil supplied from the lubricating oil reservoir and interconnected tanks and piping. Oil feed piping, where practical, is run within the lube oil reservoir drain line, or drain channels, as a protective measure. This construction is referred to as double piping. In the event of a supply line leak, oil will not be sprayed on nearby equipment, thus eliminating a potential safety hazard. When the oil enters the housing inlet, it flows into an annulus around the bearing. From the annulus, the oil flows through machined holes or slots to the bearing-rotor interface. 2. Lubricant Sealing Oil on the surface of the turbine shaft is prevented from being spun along the shaft by oil seals in each of the three bearing housings. These labyrinth seals are assembled at the extremities of the bearing assemblies where oil control is required. A smooth surface is machined on the shaft and the seals are assembled so that only a small clearance exists between the oil seal and the shaft. The oil seals are designed with tandem rows of teeth and an annular space between them. Pressurized sealing air is admitted into this space and prevents lubricating oil from spreading along the shaft. Some of this air returns with the oil to the main lubricating oil reservoir and is vented through a lube oil vent. The remainder of the air passes into adjoining turbine spaces or is vented into atmosphere. E. #1 Bearing The #1 bearing subassembly is located in the center of the inlet casing assembly (Figure 28) and contains three bearings: (1) active (loaded) thrust bearing, (2) inactive (unloaded) thrust bearing, and (3) journal bearing. Additionally, it contains a “running-type” ring seal, four labyrinth seals and a two-part housing in which the components are installed. The components are keyed to the housing to prevent rotation. The #1 bearing housing is supported from the inner cylinder of the compressor inlet casing. The top of the housing is removable, being flanged and bolted to the bottom half. The outer labyrinth seals at each end of the housing are pressurized with air extracted from the compressor fifth-stage. Inboard of the pressurized labyrinth seals, are two additional labyrinth back-up seals for positive sealing of the bearing oil cavity. The “running-type” ring seal at the forward end of the thrust bearing cavity contains the oil within the bearing and limit entrance of air into the cavity. The #1 journal
35
GFD91ES
Gas Turbine Functional Description No. 1 Bearing Liner Shim Unloaded Thrust Bearing Shaft Thrust Runner Loaded Thrust Bearing Inlet Casing
Figure 28. No. 1 Bearing In Inlet Casing bearing liner has an integral, non-contacting ring seal which contains the oil in a circumferential drain groove. The oil drains from this groove through a vertical slot into the bearing drain cavity. F. #2 Bearing The #2 bearing subassembly is located in the center of the inner cylinder of the compressor discharge casing. The casing support consists of ledges at the horizontal plane and an axial key at the bottom centerline. This arrangement permits relative growth resulting from temperature differences while the bearing remains centered in the discharge casing. The #2 bearing housing and its mounting arrangement in the compressor discharge casing is shown in Figure 7. The assembly includes a bearing liner, labyrinth seals and a bearing housing. This assembly is located in a pressurized space (the inner barrel) between the turbine and compressor. The seal system is shown in Figure 29 The #2 bearing liner is prevented from rotating with the shaft by an anti-rotation pin located in the lower bearing liner. G. #3 Bearing The #3 bearing subassembly is located at the aft end of the turbine shaft in the center of the exhaust frame assembly (Figure 20). It consists of a tilting pad bearing, three labyrinth seals, two floating ring seals and a bearing housing. The individual pads are designed and assembled so that a high pressure oil film is generated between each pad and the bearing surface. This produces a symmetrical loading or “clamping” effect on the bearing surface that helps maintain shaft stability. Because the pads are free to move in two dimensions, they are capable of tolerating a certain amount of shaft misalignment.
36
Gas Turbine Functional Description
GFD91ES Vented Cavity
Oil Deflector
Turbine End
Bearing Liner Bearing Cavity
Compressor End
Figure 29. #2 Bearing Assembly
H. Thrust Bearings –Tilting Pad Equalizing and Non-Equalizing Types 1. General A thrust bearing unit is made up of a shaft member called the “thrust runner” and a stationary member, called the “bearing.” Thrust bearings support the thrust loads developed on the rotor surfaces of a gas turbine unit. The thrust load imposed on such a bearing is the sum of the forces that act on the rotor assembly in a direction along the rotor axis. For example, the thrust forces of an axial-flow compressor, such as those used in General Electric gas turbines, are only partially compensated for by the anti-thrust forces of the turbine that drives it. The resultant thrust load will tend to move the rotor assembly in a direction opposite to that of the air flow through the compressor. During normal operation of a gas turbine unit, the thrust load of a rotor assembly is unidirectional; however, during startup and shutdown of the unit, the direction of the thrust load will generally reverse. Thus, two thrust bearings are provided on a rotor shaft assembly in order to support the thrust loads imposed in either direction. The bearing which takes the thrust load during normal operation is called the “active” or “loaded” thrust bearing. That which takes the thrust load during startup or shutdown of the unit is called the “inactive” or “unloaded” thrust bearing. Tilting pad, equalizing-type thrust bearings are commonly employed as “loaded” thrust bearings in General Electric gas turbines. This type of bearing will sustain high loads and is tolerant of shaft and housing misalignment. A typical tilting pad, equalizing-type thrust bearing is shown in Figure 30. A typical outline and section are shown in Figure 31. Tilting pad, non-equalizing type thrust bearings are used for the “inactive” or “unloaded” application. This type of bearing is capable of carrying high thrust loads but is less tolerant of misalignment than the tilting pad, equalizing-type. A cross section and outline diagram of a typical non-equalizing thrust bearing is shown in Figure 32. 2. Description The principal parts of the tilting pad equalizing thrust bearing include the stationary pivoted segments or “pads;” two rows of hardened steel equalizing levers called “leveling plates;” and the sup-
37
GFD91ES
Gas Turbine Functional Description
1 2
3 8 7 6
1. 2. 3. 4.
Pad Oil Control Plate Base Ring Upper Leveling Plate
4 5
5. 6. 7. 8.
Lower Leveling Plate Pad Support Upper Leveling Plate Screw Base Ring Key
Figure 30. Typical Tilting Pad Equalizing Thrust Bearing
38
Gas Turbine Functional Description
GFD91ES
7
6
1
1 5
2
4
3
1. 2. 3. 4. 5. 6. 7.
Thrust Pad Pad-Babbit Surface Pad Support Base Ring Upper Leveling Link Lower Leveling Link Anti-Rotation Dowel Pin
Figure 31. Outline of Typical Tilting-Pad Equalizing Thrust Bearing
39
GFD91ES
Gas Turbine Functional Description
1
6
4
5
2 4
3
1. Base Ring at Oil Control Plate 2. Base Ring at Thrust Pad 3. Pad Support 4. Thrust Pad 5. Pad-Babbit Surface 6. Oil Control Plate
Figure 32. Typical Tilting-Pad Non-Equalizing Thrust Bearing-Outline Diagram
40
Gas Turbine Functional Description
GFD91ES
porting member called the “base ring.” Typical pads, leveling plates, and the base ring are shown in Figures 33, 34, and 35. The tilting pad, non-equalizing types of thrust bearing is similar to the equalizing types, except for the “leveling plates” which are not a part of the design. The pads and the leveling plates are assembled in the base ring. The complete assembly is supported in a bearing housing which is secured to the main turbine structure. The thrust bearings are keyed in place to prevent rotation. The bearing pad is shaped like the sector of a ring. Its bearing surface is faced with babbitt and each pad has a hardened steel button, called a “pad support,” set into its back which allows the pad to tilt slightly in any direction on its leveling plate. The leveling plates are in effect short levers with center fulcrums. Their function is to align the bearing pads with the thrust runner and equalize the load among the pads despite possible slight misalignment of the shaft axis from the normal, a condition that might result from small deflections in the turbine structure during operation. The leveling plates are located in the base ring by dowels or screws such that the plates are free to tilt on their fulcrums. The arrangement of the leveling plates with respect to the pads and the base ring is shown in Figure 36. The load transmitted by the thrust runner to any one pad causes that pad to press against the upper leveling plate immediately behind it. Each leveling plate, in turn, is supported upon one edge of each of the two adjacent lower leveling plates, the other edges of which take part in supporting the next upper leveling plates on either side. As a result of this arrangement, any incipient excess of thrust on one pad is shared through the interaction of the leveling plates by the adjacent pads. This interaction and load sharing is distributed all around the circle so that all the pads receive equal loading. The tilting pad, non-equalizing-type thrust bearing does not contain leveling plates and, as a result, is thinner in the axial dimension. The base ring provides support for all the parts of the bearing assembly and keeps the parts in their proper location. In some bearing applications, the base ring is specially designed to contain the oil flow around the pads and thrust runner to prevent flooding of adjacent compartments. Such a base ring incorporates a tooth which surrounds the thrust runner on the shaft to contain the oil flow within the bearing. In other applications, a base ring such as the one shown in Figure 35 is used. A thrust bearing with this type of base ring would be installed in a bearing housing which would incorporate the necessary oil baffles or other devices to allow proper oil flow around the bearing and prevent excessive leakage along the shaft where such leakage would be objectionable. Oil control plates (Figure 30) are used on some tilting pad thrust bearings to direct the flow of lubricating oil to the pads and prevent excessive leakage of oil outward away from the pads. The oil control plates are bronze segments which are placed between the pads and attached at both ends to the base ring. The tilting pad thrust bearing is classified as a hydrodynamically lubricated bearing which means that the bearing surfaces are separated from the thrust runner by a thin film of lubricating oil which is formed and maintained by the relative motion of the bearing surfaces. This oil film supports the thrust load and prevents metal-to-metal contact of the bearing surfaces. In addition to acting as a
41
GFD91ES
Gas Turbine Functional Description
1
2
1. Babbitted Bearing Surface 2. Pad Support
Figure 33. Pads
1 2
1. Lower Leveling Plate Showing Dowel Hole 2. Upper Leveling Plate Showing Set-Screw Hole
Figure 34. Leveling Plates
42
Gas Turbine Functional Description
GFD91ES
4
1
1. 2. 3. 4. 5. 6.
2
3
5
6
Holes for Fastening Oil-Control Plates Bearing Pad Space Lube Oil Passages Upper Leveling-Plate Set-Screw Hole Base Ring Key Lower Leveling-Plate Dowel
Figure 35. Typical Base Ring
Collar
Leveling Plates
Pad
Base Ring
Figure 36. Schematic Diagram Showing Arrangement of Equalizing Means
43
GFD91ES
Gas Turbine Functional Description load-supporting medium, the oil also carries away the heat generated by the shearing action in the oil film. The pads of a tilting pad thrust bearing are free to assume the position which will provide for the optimum wedge-shaped oil film required by different combination of load, speed, oil viscosity and temperature to which the bearing is subjected. The tilting pad thrust bearing is lubricated by oil which is admitted under pressure through ports in the bearing housing to an annulus behind the base ring. The lube oil then flows through ports in the base ring to the thrust bearing cavity where it is picked up by the rotating thrust runner and carried around the entire bearing surface. Oil circulation through the tilting pad thrust bearing is assisted by the natural pumping action of the rotating thrust collar. Oil leaves the bearing at the outer periphery of the pads and thrust collar where it is gathered in a large annular cavity and drained. The drain annulus and exit ports are cast or machined into the bearing housing. 3. Maintenance Refer to the Maintenance Manual for information.
VII. COUPLINGS A. Accessory Gear Coupling –Oil Filled 1. Description The major components of the oil-filled accessory gear coupling consist of sleeves, hubs, and a floating shaft (Figure 37). The coupling sleeves include flanges which interface with the accessory gear box and the turbine rotor. Internal gear teeth machined within the coupling sleeve mesh with the external crowned teeth of the hubs. These hubs are splined onto the floating shaft, and the resultant pivoting action of the sleeves and the hubs compensate for a nominal misalignment of the accessory gear box and the turbine rotor. The sliding action between the hubs and the sleeves permits axial movement of the turbine relative to the accessory gear box. The O-ring seals, recessed in the face of the coupling flanges and located between the sleeves and hubs, are used to contain the lubricant within the coupling. 2. Operation Check During the startup and normal rotation of the gas turbine, a visual check of the accessory gear coupling should be made for possible misalignment or malfunction as evidenced by unusual motion or vibration. A check should also be made for lubricant leakage. After performing a running check,the turbine should be shut down and the general alignment and axial clearance, torque values of the coupling fasteners, and lube plugs should be rechecked for leakage.
44
Gas Turbine Functional Description
GFD91ES
3. Maintenance Periodic inspection and maintenance procedures, as described in the Maintenance section of the MS9000 Instruction Manual, provide suggested routine inspections and maintenance to be performed at recommended specified time intervals. The procedures also include inspections which are not specified for definite time intervals, but are based on operating experience, turbine conditions, and as-needed determinations. The actual time interval established for any particular gas turbine should be based on the user’s operating experience, and on ambient conditions such as temperature range, humidity, dust and corrosive atmosphere. 4. Lubrication The oil-filled couplings are to be cleaned and inspected every three years, and relubricated with the proper lubricant as specified in the Lubrication Guidance Chart contained in the Maintenance volume of this manual. The procedure outlined below should be strictly followed during the relubrication operation to prevent shaft misalignment and possible damage to the accessory gear box or to the coupling. a. Remove Accessory Coupling 1. Matchmark the accessory shaft to the rotor, and the accessory coupling to the accessory gear box shaft. See Figure 37 for matchmark location. 2. Support the coupling adequately and unbolt it from the accessory gear box and rotor. The coupling must be unbolted to completely drain the oil from each end of the coupling. b. Flush, Clean and Inspect 1. Flush and clean out all dirty oil with clean oil. 2. Caution should be exercised to remove all accumulation of sludge and foreign material from the gear teeth and spline areas. 3. Inspect the splines and gear teeth for cleanliness, damage, and wear. See Inspection paragraph below. 4. Inspect and replace the O-ring if necessary. c. Reassemble 1. Reassemble the coupling to the accessory gear box and the turbine rotor using the following torque values: 7/8–14 Bolts –275/285 ft–lb 1–8 Bolts –400/410 ft–lb 2. Extreme caution should be taken not to pinch the O-ring seals. d. Relubrication 1. Remove the lube plugs on each end of the coupling.
45
GFD91ES
Gas Turbine Functional Description
Mating Flange
Matchmark Both Ends of Coupling Assembly
O-Ring Sleeve O-Ring Hub Lube Plug
Floating Shaft
Figure 37. Oil-Filled Accessory Gear Coupling Assembly
46
Gas Turbine Functional Description
GFD91ES
2. Fill each end of the coupling with 335 cc (11.3 fluid ounces) of lubricant conforming to MIL–L–2105B, Grade 140 and replace the plugs. CAUTION Do not overfill the coupling with lubricant. Overfilling can result in damage to the accessory gear box bearing. 3. Record the lubrication date for future reference. 5. Inspection Inspect the gear teeth for abrasive wear indicated by scratch-like lines or marks on the tooth surfaces that are caused by dirt or foreign particles in the oil. Excessive gear tooth wear clearances and tooth failure can cause a large vibration response. Vibration levels should be plotted against time over the running history of the gas turbine so that trends, if any, can be used to detect coupling deterioration. A record should be maintained of the wearing surfaces so that wear progress can be determined with time. 6. Reassembly Check List The following list of items should be checked prior to startup: a. Check that matchmarked parts are correctly positioned. b. Check the axial movement of the hub. Adequate clearance should be provided between the end of the shaft assembly and the connected equipment to accommodate variations in shaft separation. For further information, refer to the Field Alignment Instructions. c. Check that radial movement between the hubs and the sleeves is held to an absolute minimum by the pilot fit of the gear. d. Confirm that the coupling has been properly lubricated and that the lube date is recorded. e. Check fasteners for correct bolt torque and lube plugs for tightness. f. Check that the general alignment is correct. g. Ascertain that connected equipment is properly secured and ready for operation. VIII. GEAR ASSEMBLIES A. General Gear assemblies are used to increase, or decrease, shaft rpm as required by driven equipment such as load and accessories.
47
GFD91ES
Gas Turbine Functional Description
B. Accessory Drive The accessory drive gear, located at the compressor end of the gas turbine, is a gearing assembly coupled directly through a flexible coupling to the turbine rotor. Its function is to drive each gas turbine accessory at its proper speed and to connect the turbine to its starting device. In addition, it contains the system main lube oil pump and the turbine overspeed bolt and trip mechanism. Contained within the gear casing, there are the gear trains which provide the proper gear reductions to drive the accessory devices at the required speed with the correct torque values. Accessories driven by the gear may include the main lube oil pump, the main hydraulic supply pump, the liquid fuel pump, the water pump, and the main atomizing air compressor. Lubrication of the gear is from the turbine’s pressurized bearing header supply. A high–pressure turbine overspeed trip, capable of mechanically dumping the oil in the trip circuits, is mounted on the exterior casing of the gear. This device can shut the turbine down when the speed exceeds the design speed. The overspeed bolt which actuates the trip upon overspeed is installed in the main shaft. 1. Description For ease of maintenance and inspection, the gear casing is split at the horizontal plane into an upper and lower section. Interconnected shafts are arranged in a parallel axis in the lower casing. Three of the shafts are located on the same horizontal plane as the casing joint. The gear consists of four parallel axis, interconnected shafts arranged in a casing which provides mounting pads for the various driven accessories. With the exception of the lube oil pump and hydraulic supply pump shaft, all the shaft centerlines are located on the horizontal joint of the accessory drive casing. Numbers are assigned to the various shafts and the rpm of each shaft and the load horsepower are shown in the design data which follows this text. The gear casing is made of cast iron and split at the horizontal joint to facilitate assembly. The lower– half casing has a closed bottom with openings for lube oil pump suction and discharge lines and casing drain line. All of the shafts are connected together by single helical gears which are shrunk to the shafts after the teeth are cut. It is possible, in some instances, to remove individual gears which may have been damaged in service, and to replace them with new gears. This operation, however, should be performed at the factory so that the required precision may be maintained. All of the shafts located on the horizontal joint are contained in babbitt–lined, steel–backed journal bearings with integral thrust faces which are split on the horizontal joint of the casing. The thrust faces of the bearings maintain the shafts in their proper axial location. The necessary thrust clearance is preset at the factory. The shafts which are not on the horizontal joint are contained in babbitt–lined, steel–backed, non–split bushings with integral thrust faces. Their thrust clearance is preset at the factory. The main lubricating oil pump is located on the inboard wall of the lower–half casing of the accessory drive gear and is described in the Lubrication System section.
48
Gas Turbine Functional Description
GFD91ES
2. Maintenance Very little routine inspection of the gear is required. However, should excessive temperatures, unusual noises, or oil leaks occur, their cause should be determined and corrected. Refer to the Manufacturer’s operating and maintenance instructions.
49
GFD91ES
Gas Turbine Functional Description
THIS PAGE INTENTIONALLY LEFT BLANK.
50
GE Power Systems
GAS TURBINE FUNDAMENTALS Model Series 9001E
Simple-Cycle, Single-Shaft Heavy-Duty Gas Turbine
id0002
Figure 1
The Diesel Cycle
GENERAL
The Diesel Cycle, Figure 3, is similar, except that combustion takes place at a constant pressure (2–3). This is accomplished by injecting fuel at a rate sufficient to compensate for the volume change. Expansion and exhaust then take place as it does in the Otto Cycle.
Figure 1 depicts a General Electric simple–cycle single–shaft, heavy–duty gas turbine. It is an internal combustion engine which produces energy through a cycle similar to the Otto or Diesel cycles in that the three cycles consist of the same four stages: compression, combustion, expansion, and exhaust. There are, however, differences in the details of the three cycles which are worth examining.
2
P = PRESSURE V = VOLUME
3
P
The Otto Cycle
4 1
In the Otto Cycle, Figure 2, the compression stroke (from 1 to 2) is followed by combustion of constant volume (2 to 3) resulting in increased pressure. The pressure causes expansion (3 to 4) with exhaust taking place between points 4 and 1.
V id0022
Figure 3 Diesel Cycle
The Brayton Cycle In both the Otto and Diesel cycles a loss occurs due to the pressure drop involved in the exhaust stroke. This loss is avoided by creating a cycle in which the exhaust stroke is longer than the compression stroke, thus allowing the working fluid to be expanded to atmospheric pressure. Such a cycle has been devised, and is called a Brayton Cycle (Figure 4). It is also called a Constant Pressure Cycle since combustion and exhaust both take place at constant
3 P = PRESSURE V = VOLUME
P
2
4 1 V id0021
Figure 2 Otto Cycle A00203
1
GAS TURBINE FUNDAMENTALS
GE Power Systems pressure. When the Brayton Cycle is worked out for a steady–flow process, we have the simple gas turbine cycle.
2
GENERAL DESCRIPTION The Model Series 9001E gas turbine is a 3000–rpm, single–shaft, simple–cycle power package that basically requires only fuel and fuel connections, generator breaker connections, and an AC–power source for turbine start–up. The MS9001E is also available in a combined–cycle configuration for applications utilizing a Heat Recovery Steam Generator or similar device.
3 P = PRESSURE V = VOLUME
P 4
GAS TURBINE UNIT
1 V
The gas turbine unit consists of a 17–stage axial– flow compressor and a 3–stage power turbine. Each section, compressor rotor and turbine rotor, is assembled separately and then joined together. Through–bolts connect the compressor rotor wheels to the forward and aft stubshafts. The turbine rotor also utilizes through–bolt construction with spacer wheels between the first– and second–stage and the second– and third–stage wheels.
id0010
Figure 4 Brayton Cycle
In the simple gas turbine cycle, combustion and exhaust occur at constant pressure and compression and expansion occur continuously, rather than intermittently as in the Otto or Diesel cycles. This means that gas turbine power is continuously available, whereas in a reciprocating engine power takeoff is available only on the expansion stroke. Figure 5 schematically represents the hardware necessary for the cycle. The points on Figures 4 and 5 are consistent. At point 1, air enters the compressor (c). The high pressure compressor discharge air at point 2 is mixed with fuel in the burner (b). The product of this continuous combustion at point 3 enters the turbine (t), and is expanded to atmospheric pressure (point 4). The turbine provides the horsepower to drive the compressor and load (in this case, a generator).
The assembled rotor is a three–bearing design utilizing pressure–feed elliptical and tilt–pad journal bearings. The three–bearing design assures that rotor–critical speeds are above the operating speed and allows for optimum turbine bucket/turbine shell clearances.
TURBINE COMPONENTS – OVERVIEW The major components of the gas turbine are the rotor components, primarily the axial flow compressor and the turbine wheels; the stationary components, primarily the compressor casings, turbine shell, and nozzles; and the combustion components.
FUEL 2
c
1 AIR
b
4
3
t
GEN
Casings
c = COMPRESSOR b = BURNERS t = TURBINE id0017
The casings make up the structural backbone of the gas turbine. This structure supports the rotating ele-
Figure 5 Fundamental Gas Turbine
GAS TURBINE FUNDAMENTALS
2
A00203
GE Power Systems Nozzles
ments through its bearing housings, functions as a pressure vessel to contain the turbine’s working fluids of compressed air and combustion gases, and provides a surface of revolution for the blading to operate while maintaining minimum radial and axial clearance and, therefore, optimum performance.
General Electric turbines are of the impulse or high– energy stage design (i.e., pressure and heat conversion in the nozzle). The high pressure drop across the nozzle imparts a high velocity (kinetic energy) to the combustion gases. This energy is directed to the buckets which use this energy to rotate the shaft, driving the axial compressor and load.
Compressor
Combustion System
The function of the axial flow compressor is to furnish high pressure air to the combustion chambers for the production of the hot gases necessary to operate the turbine. Since only a portion of its output is used for combustion the compressor also serves as a source of cooling air for the turbine nozzles, turbine wheels, transition pieces, and other portions of the hot–gas path.
The overall function of the combustion system is to supply the heat energy to the gas turbine cycle. This is accomplished by burning fuel mixed with compressor discharge air. The combustion gases are then diluted with excess air to achieve the desired gas temperature at the inlet of the first–stage turbine nozzle.
Air enters the inlet of the multistage compressor where it is compressed from atmospheric pressure to approximately 8.95 to 12.92 bar (130 to 185 psig), depending on frame size. This gives a Compressor Pressure Ratio of approximately 10:1 to 13.5:1, C.R. +
The combustion system consists of a number of similar combustion chambers. Compressor discharge air is distributed to these chambers where it is bled into a cylindrical combustion liner. Fuel is injected into the forward end of the liners where it mixes with the compressor discharge air and combustion takes place, thereby creating hot gases with temperatures in excess of 1650°C (3000°F) in the flame zone. As well as being used for combustion, the relatively cool compressor discharge air acts as a blanket to protect the liners from the heat of combustion. In addition to cooling the combustion liners, compressor discharge air mixes with the combustion gases downstream of the combustion reaction zone, cooling and diluting the gases which now pass through transition pieces to the turbine first–stage nozzle. The amount of air necessary to cool the liner wall and dilute the hot gas to the temperature desired at the first–stage nozzle is about four times that required for complete combustion; this “excess air” in the turbine exhaust makes it possible to install auxiliary burners in a Heat Recovery Steam Generator if so desired.
Atmos Press ) Compressor Disch Pressure (Atmospheric Pressure)
again dependent on frame size. The air which continuously discharges from the compressor will occupy a smaller volume at the compressor discharge than at the inlet and, due to heating during compression, will have a temperature of 315°C to 360°C (600°F to 680°F).
Turbine
The turbine wheels are an area of primary importance because they are the point at which the kinetic energy of the hot gases is converted into useful rotational, mechanical energy by the turbine buckets. This produces the power necessary to meet the load requirements and drive the axial–flow compressor. A00203
The schematic operation of the single–shaft simple– cycle gas turbine may be seen in Figure 6. 3
GAS TURBINE FUNDAMENTALS
GE Power Systems
ATMOSPHERIC AIR
IGNITION (FOR STARTUP)
COMPRESSED AIR
EXHAUST
COMBUSTION CHAMBER
HOT GASES
FUEL TORQUE OUTPUT TO DRIVEN ACCESSORIES
COMPRESSOR
TORQUE INPUT FROM STARTING DEVICE
TURBINE
TORQUE OUTPUT TO DRIVEN LOAD
ROTOR id0020
Figure 6 Simple–Cycle Gas Turbine Operation
GE Power Systems Training GAS TURBINE FUNDAMENTALS
4
A00203
DT-1C
E
G
l
ci a
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al
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RADIAL LOCKING PIN
BUCKET
AXIAL LOCKING PIN
SECTION VIEW LOCKING BUCKET DOVETAIL LOCKING PIN ASSEMBLY
”D” KEY RADIAL LOCKING PIN MS7001EA 1st STAGE BUCKET (Example)
BUCKET SEALS REFER TO VIEW A BKTASM1A
BUCKET ASSEMBLED IN DOVETAIL ”D” KEY PLACED IN TURBINE WHEEL SLOT AND PUSHED INTO BUCKET POCKET LOCKING THE BUCKET TO THE TURBINE WHEEL
LOCKING BUCKET DOVETAIL
AXIAL LOCKING PIN
ENLARGED VIEW C BUCKET & ”D” KEY ASSEMBLY BKTASM1C 10/94
”D” KEY ASSEMBLY
BUCKET ”D” KEY POCKET
TWISTLOCKS
MS7001EA 2nd STAGE BUCKET (Example)
TWISTLOCK ROTATED TO SECURE BUCKET TWISTLOCK STAKING GROOVE
HEAD STAKED INTO GROOVE TO PREVENT FURTHER ROTATION
DETAIL VIEW BUCKET & TWISTLOCK ASSEMBLY
TWISTLOCK ASSEMBLY BKTASM1B 10/94
SIZE
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F
TBFT-TMP-FR-GTE-0060- Rev : 001
ISO PROJECTION
REV
EACH SECTION SHALL BE REVISED IN ITS ENTIRETY. ALL SHEETS OF EACH SECTION ARE THE SAME REVISION LEVEL AS INDICATED IN THE REVISION BLOCK
SECTION
REV F F F
A
First issue
B
IM-2006002198
C
IM-2006002376
D
IM-2006006416 (DCI 06018692)
E
IM-2007001938
F
IM-2007003054
REVISIONS NAMES
T. Fischer D. Pâques JM. Jost T. Fischer D. Pâques JM. Jost T. Fischer D. Pâques JM. Jost JM. Jost D. Pâques V. Sicard D. Pâques JM. Jost V. Sicard D. Pâques JM. Jost V. Sicard
DATE
SIGNATURES
20/03/2006
21/03/2006
28/03/2006
19/09/2006
07/03/2007
10/04/2007
DIMENSIONS ARE IN MM [INCHES] TOLERANCES ON: 1 [2] PL DECIMALS + 2 [3] PL DECIMALS +
NAMES
G
UNLESS OTHERWISE SPECIFIED
E
This document, exclusive property of GE Energy Products France SNC is strictly confidential. It must not be communicated, copied or reproduced without our prior written consent.
O
Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel. Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
ffi
ci al
INDEX 01E 01F
NO. OF SHEETS 1 1 1
DESCRIPTION
DATE
DRAWN
20/03/06
CHECKED
20/03/06
APPROVED
20/03/06
T. Fischer D. Pâques JM. Jost
ITEM : 0414
First made for : 9171E
NOMENCLATURE DES APPAREILS DE CONTROLE
ANGLES +
DIAGRAM. SCHEMA. P.P. – DEVICE SUMMARY
FRACTIONS +
WEIGHT : 0000 kg
SIZE
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CAGE CODE
SCALE
DWG NO
137A3171 SHEET
DT-1C
INDEX
1/1 Doc. Source : TBFT-ISP-FR-GTE-0020
SIZE
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SH
REV
1
F
TBFT-TMP-FR-GTE-0060 Rev : 001
REVISIONS Rev A B
C
D E F
Description First issue - Modified wiring diagram for 95BT-1, 2 & 3 : ENCL-T instead of ENCL-?? - Added water injection enclosure (PID 0436) : 20JS-30, 33JS-1 & 2, 63JS-30, 88JS-1 & 2, AT-WI-1 - Modified level of voltage : replaced 230 VAC by 240 VAC and 115 VAC by 120 VAC - Added devices 20BA-31, 63BA-31, 95BA-4, 5 & 6 - Suppressed devices 63FL-2, 71QL-1 & 71QH-1 - Added devices 23QV-2 / 88QV-2 / 96QL-1 / 96QV-1 / 96FL-2A & 2B / 96FP-1 & 2 / FF2-2 / FF11-2 - Modified PID for MLI 0425 : 206D7308 instead of 209D7177 - Modified setting for 63PL-21 Add PF1-90 Add 88QAOB and 88QEOB
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Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
SH
REV
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F
TBFT-TMP-FR-GTE-0060 Rev : 001
PRESSURE : All pressures are gauge pressure, abs means absolute pressure.
Abbreviations AA ACF AD AE AMF DEC. DPDT DPG FC FO GF GFV GPL INC. LVDT MLI NC NO Normal OD OD OD OH OHT OL OLV OR PC Slope SPDT SPST WD WF WR
Descriptions Atomizing Air Control Filter Downstream Pressure Compressor Discharge Air Extraction Air Lube Oil Filter Downstream Pressure Decreasing Double pole, double throw Differential Pressure Gauge Fail safe to close Fail open Gas Fuel Gas Fuel Vent Gas Valve Stem Packaging Leakoff Increasing Linear variable differential transformer Model List Item : four digit code used by General Electric to identify components, assembly, drawings or specifications, example : MLI 0414 for Device Summary Normally closed Normally open Means absolute zero energy level, such as no power, no oil, no speed, no temperature Oil Drain Oil drain above oil tank level Oil drain below oil tank level Control Oil High Pressure Trip Oil High Pressure Lube Oil Lube Oil Event Regulated Lube Oil Piping connecting point The arrow direction indicates the liquid gravitational drainage due to the slope Single pole, double throw Single pole, single throw Water Drain Water Feed Water Return
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Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
SH
REV
3
F
Wiring diagram ACCY AIR
TBFT-TMP-FR-GTE-0060 Rev : 001
Description The device is in the accessories wiring diagram (MLI 401A) The device is in the cooling fan module wiring diagram (MLI A132)
ENCL-G
The device is in the gas enclosure interface drawing (MLI 1658)
ENCL-LF
The device is in the liquid fuel / atomizing air / water injection module enclosure interface drawing (MLI 1650)
ENCL-LO
The device is in the lube oil / fuel gas module enclosure interface drawing (MLI 1634)
ENCL-T
The device is in the turbine enclosure interface drawing (MLI 1605)
ENCL-WI
The device is in the water injection enclosure interface drawing (MLI 1659)
FILT
The device is in the air filter wiring diagram (MLI A040)
GAS
The device is in the gas module wiring diagram (MLI 0991 or 401G)
GENE IBH LF AA WI
The device is in the generator wiring diagram The device is in the bleed heating wiring diagram (MLI A037) The device is in the liquid fuel / atomizing air / water injection module wiring diagram (MLI A162)
LF-SR
The device is in the liquid fuel recirculation skid wiring diagram (MLI 969C)
LO FG
The device is in the lube oil / fuel gas module wiring diagram (MLI A160)
LOAD
The device is in the load gear wiring diagram (MLI A012)
MIST
The device is in the mist eliminator outline drawing (MLI A098)
OIL
The device is in the lube oil wiring diagram (MLI 0991 or 401H)
STEAM
The device is in the steam injection module wiring diagram (MLI A135)
TURB
The device is in the gas turbine wiring diagram (MLI 401T)
VAN
The device is in the additive injection vanadium module wiring diagram (MLI E021)
WI
The device is in the water injection module wiring diagram (MLI A035)
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Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
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4
F
TBFT-TMP-FR-GTE-0060 Rev : 001
System Name
Items
System
Reference
Control Devices Turbine System
0415
CD
214D1164
Lube Oil System
0416
LO
206D6970
Cooling and Sealing Air System
0417
CSA
206D6971
Trip Oil System
0418
TO
N/A
Instrument Air System
0419
APU
N/A
Cooling Water System
0420
CW
206D6786
Starting Means System
0421
SM
205D4866
Gas Fuel System
0422
GF
206D6972
Liquid Fuel System
0424
LF
206D6600
Atomizing Air System
0425
AA
206D7308
Fire Protection System
0426
FP
206D6966
PP Station Air System
0428
AE
N/A
Steam Injection System
0431
SI
N/A
Inlet Air heating System
0432
IAR
N/A
Hydraulic Supply System
0434
HS
209D7043
Heating and Ventilation System
0436
HV
206D6596
Turbine and Compressor Cleaning System
0441
TCC
N/A
Turbine and Compressor Washing System
0442
TCW
205D4265
Water Injection System
0462
WI
206D6293
Compressor Inlet Guide Vanes System
0469
IGV
206D6828
Flow Inlet and Exhaust System
0471
IE
206D6968
Gas Detection System
0474
GD
206D6595
Fuel Purge System
0477
FPU
209D7645
Nitrogen Injection System
0491
NI
N/A
Performance Monitor System
0492
PM
214D1258
Additive Injection Skid System
0494
LFAD
206D6208
Load Gear System
0495
LG
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Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
5
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0425
20AA-1
0983
TURB
Solenoid valve for VA18-1 control Characteristics : Normal : 1 to 3 open ; 2 closed | 0.035 kW | 125 VDC
0425
20AB-1
0922
ACCY
Solenoid valve for VA22-1 control Characteristics : Normal : 1 to 3 open ; 2 closed | 0.035 kW | 125 VDC
0436
20BA-30
1605
ENCL-T
Electromagnet, air inlet filtring system by pass door, auxiliaries compartment Characteristics : 24 VDC
0436
20BA-31
1605
ENCL-T
Electromagnet, air inlet filtring system by pass door auxiliaries compartment Characteristics : 24 VDC
0436
20BT-30
1605
ENCL-T
Electromagnet, air inlet filtring system by pass door, GT compartment Characteristics : 24 VDC
0436
20BT-40
1605
ENCL-T
Electromagnet, air inlet filtring system by pass door Characteristics : 24 VDC
0417
20CB-1
1071
TURB
Compressor bleed solenoid valve Characteristics : Normal : B to C Open, A closed | 0.04 kW | 125 VDC
0424
20CF-1
0601
ACCY
Fuel pump clutch solenoid Characteristics : Normal : NO | 0.16 kW (max) | 125 VDC
0422
20FGC-1
0509
GAS
Trip solenoid valve for gas control valve (VGC-1) Characteristics : Normal : NO | 0.0156 kW | 125 VDC
0422
20FGS-1
0507
GAS
Fuel gas stop valve solenoid valve Characteristics : Normal : NO | 0.0156 kW | 125 VDC
0424
20FL-1
1019
ACCY
Liquid fuel stop valve solenoid Characteristics : Normal : NO | 0.02 kW | 125 VDC
0494
20IA-11
E021
VAN
Solenoïd valve Characteristics : Normal : NC | 12 W | 125 VDC
0436
20JS-30
1659
ENCL-WI
0424
20PF-100
0961
TURB
Electromagnet, air inlet filtring system by pass door, water injection compartment Characteristics : 24 VDC Purge fuel liquid solenoid valve Characteristics : Normal : A to P open. B closed | 40 W | 125 VDC
0477
20PG-1
0991
GAS
Solenoid valve for VA13-1 control Characteristics : Normal : 1 to 3 open ; 2 closed | 0.035 kW | 125 VDC Settings : A needle-valve is installed upstream of 20PG-1 in order to adjust VA13-1 time opening at 30 seconds
0477
20PG-2
0991
GAS
Solenoid valve for VA13-2 control Characteristics : Normal : 1 to 3 open ; 2 closed | 0.035 kW | 125 VDC Settings : A needle-valve is installed upstream of 20PG-1 in order to adjust VA13-1 time opening at 30 seconds
0477
20PL-1
918T
TURB
Solenoid valve for VA19-1 control Characteristics : Normal : 1 to 3 open ; 2 closed | 0.035 kW | 125 VDC
0421
20TU-1
0605
ACCY
Torque converter fill / drain solenoid valve Characteristics : Normal : NC
0469
20TV-1
1019
ACCY
Solenoid valve for compressor IGV trip system Characteristics : Normal : NO | 0.1 kW | 125 VDC
0442
20TW-1.
0953
TURB
Motor valve off-line compressor water wash Characteristics : Normal : FC | 0.092 kW | 50 Hz | 115 VAC
0442
20TW-3.
0953
TURB
Motor valve on-line compressor water wash Characteristics : Normal : FC | 0.092 kW | 50 Hz | 115 VAC
0422
20VG-1
0991
GAS
Fuel gas vent solenoid valve Characteristics : Normal : NO | 0.009 kW | 125 VDC
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Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
6
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation Vent solenoid valve of inter-valve cavity VA13-1 and VA13-2 Characteristics : Normal : NO | 0.125 kW | 125 VDC
0477
20VG-2
0991
GAS
0436
20VG--30
1605
ENCL-T
Electromagnet, load compartment air inlet filtering system by pass door Characteristics : 24 VDC
0436
20VL-30
1658
ENCL-T
Electromagnet, gas compartment air inlet filtering system by pass door Characteristics : 24 VDC
0462
20WN-1
A035
WI
Water injection stop valve solenoid valve Characteristics : Normal : NO | 125 VDC
0462
20WN-2
A035
WI
Water injection stop valve solenoid valve (part of VS2-2) Characteristics : Normal : NO | 125 VDC
0425
23AB-1
1047
ACCY
Anti-condensation heater for motor 88AB-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0436
23BA-1
1605
ENCL-T
Anti-condensation heater for motor 88BA-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0436
23BA-2
1605
ENCL-T
Anti-condensation heater for motor 88BA-2 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0436
23BT-1
1605
ENCL-T
Anti-condensation heater for motor 88BT-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0436
23BT-2
1605
ENCL-T
Anti-condensation heater for motor 88BT-2 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0421
23CR-1
0603
ACCY
Anti-condensation heater for motor 88CR-1 Characteristics : 50 Hz | 0.18 kW | 240 VAC
0421
23CR-2
0603
ACCY
Anti-condensation heater for motor 88CR-1 Characteristics : 50 Hz | 0.18 kW | 240 VAC
0421
23CR-3
0603
ACCY
Anti-condensation heater for motor 88CR-1 Characteristics : 50 Hz | 0.18 kW | 240 VAC
0436
23HA-1
1113
ENCL-T
Auxiliaries compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
0436
23HA-11
1195
ENCL-G
Gas compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
0436
23HA-12
1195
ENCL-G
Gas compartment air inlet heater Characteristics : 50 Hz | 15 kW | 415 VAC
0436
23HA-2
1113
ENCL-T
Auxiliaries compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
0436
23HA-3
1113
ENCL-T
Auxiliaries compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
0436
23HA-4
1113
ENCL-T
Auxiliaries compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
0434
23HQ-1
0628
ACCY
Anti-condensation heater for motor 88HQ-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0436
23HT-1
1113
ENCL-T
Turbine compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
0436
23HT-2
1113
ENCL-T
Turbine compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
0436
23HT-3
1113
ENCL-T
Turbine compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
0436
23HT-4
1113
ENCL-T
Turbine compartment heater Characteristics : 50 Hz | 3.9 kW | 415 VAC
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
6/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
7
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0416
23QA-1
1006
ACCY
Anti-condensation heater for motor 88QA-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0416
23QT-1
0938
ACCY
Immersion heater lube oil tank Characteristics : 50 Hz | 10.2 kW | 415 VAC
0416
23QV-1
A098
MIST
Anti-condensation heater for motor 88QV-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0416
23QV-2
A098
MIST
Anti-condensation heater for motor 88QV-2 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0421
23TG-1
0603
ACCY
Anti-condensation heater for motor 88TG-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0417
23TK-1
1233
ACCY
Anti-condensation heater for motor 88TK-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0417
23TK-2
1233
ACCY
Anti-condensation heater for motor 88TK-2 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0436
23VG-1
1605
ENCL-T
Anti-condensation heater for motor 88VG-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0436
23VG-2
1605
ENCL-T
Anti-condensation heater for motor 88VG-2 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0462
23WN-1
A035
WI
Anti-condensation heater for motor 88WN-1 Characteristics : 50 Hz | 0.05 kW | 240 VAC
0471
27TF-1
A040
FILT
GT air filter general alarm dispatching
0415
28FD-10
1121
TURB
Flame detector combustion chamber n°10
0415
28FD-11
1121
TURB
Flame detector combustion chamber n°11
0415
28FD-4
1121
TURB
Flame detector combustion chamber n°4
0415
28FD-5
1121
TURB
Flame detector combustion chamber n°5
0415
30SG-1
1213
TURB
Alarm relay Characteristics : Normal : NO
0436
33BA-1
1605
ENCL-T
Auxiliaries compartment ventilation damper limit switch Characteristics : Normal : NO
0436
33BA-2
1605
ENCL-T
Auxiliaries compartment ventilation damper limit switch Characteristics : Normal : NO
0436
33BT-1
1605
ENCL-T
GT compartment ventilation damper limit switch Characteristics : Normal : NO Settings : Flap closed : limit switch activated, contact closed
0436
33BT-2
1605
ENCL-T
GT compartment ventilation damper limit switch Characteristics : Normal : NO Settings : Flap closed : limit switch activated, contact closed
0417
33CB-1
1022
TURB
11 stage compressor bleed valve limit switch Characteristics : Normal : NO Settings : Valve opened : limit switch activated, contact closed
0417
33CB-2
1022
TURB
11 stage compressor bleed valve limit switch Characteristics : Normal : NO Settings : Valve opened : limit switch activated, contact closed
0417
33CB-3
1022
TURB
11 stage compressor bleed valve limit switch Characteristics : Normal : NO Settings : Valve opened : limit switch activated, contact closed
0417
33CB-4
1022
TURB
11 stage compressor bleed valve limit switch Characteristics : Normal : NO Settings : Valve opened : limit switch activated, contact closed
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
7/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
8
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0436
33DT-1
1605
ENCL-T
Auxiliaries compartment door limit switch Characteristics : Normal : NO Settings : Door closed : limit switch activated, contact closed
0436
33DT-11
1658
ENCL-T
Gas compartment door limit switch Characteristics : Normal : NO Settings : Door closed : limit switch activated, contact closed
0436
33DT-12
1658
ENCL-G
Gas compartment door limit switch Characteristics : Normal : NO Settings : Door closed : limit switch activated, contact closed
0436
33DT-13
1658
ENCL-G
Gas compartment door limit switch Characteristics : Normal : NO Settings : Door closed : limit switch activated, contact closed
0436
33DT-14
1658
ENCL-G
Gas compartment door limit switch Characteristics : Normal : NO Settings : Door closed : limit switch activated, contact closed
0436
33DT-2
1605
ENCL-T
Auxiliaries compartment door limit switch Characteristics : Normal : NO Settings : Door closed : limit switch activated, contact closed
0436
33DT-3
1605
ENCL-T
GT compartment door limit switch Characteristics : Normal : NO Settings : Door closed : limit switch activated, contact closed
0436
33DT-4
1605
ENCL-T
GT compartment door limit switch Characteristics : Normal : NO Settings : Door closed : limit switch activated, contact closed
0424
33FL-1
0511
ACCY
Liquid fuel stop valve limit switch Characteristics : Normal : NO Settings : Valve closed : limit switch activated, contact closed
0436
33JS-1
1659
ENCL-WI
Water injection skid enclosure : ventilation damper limit switch Characteristics : Normal : NO Settings : Flap closed : limit switch activated, contact closed
0436
33JS-2
1659
ENCL-WI
Water injection skid enclosure : ventilation damper limit switch Characteristics : Normal : NO Settings : Flap closed : limit switch activated, contact closed
0424
33PF-1
0961
TURB
Purge fuel liquid valve limit switch VP-1 Characteristics : Normal : NO Settings : Valve closed : limit switch activated, contact closed
0424
33PF-2
0961
TURB
Purge fuel liquid valve limit switch VP-2 Characteristics : Normal : NO Settings : Valve closed : limit switch activated, contact closed
0477
33PG-1
0991
GAS
VA13-1 close position limit switch Characteristics : Normal : NO Settings : Valve closed : limit switch activated, contact closed
0477
33PG-2
0991
GAS
VA13-1 open position limit switch Characteristics : Normal : NO Settings : Valve opened : limit switch activated, contact closed
0477
33PG-3
0991
GAS
VA13-2 close position limit switch Characteristics : Normal : NO Settings : Valve closed : limit switch activated, contact closed
0477
33PG-4
0991
GAS
VA13-2 open position limit switch Characteristics : Normal : NO Settings : Valve opened : limit switch activated, contact closed
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
8/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
9
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0421
33TC-1
0605
ACCY
Torque converter solenoid valve limit switch Characteristics : Normal : NO Settings : 20TU-1 de-energized : switch activated, contact closed
0421
33TM-5
0605
ACCY
Torque converter low torque limit switch Characteristics : Normal : NO, switch closed for IGV closed or max torque Settings : Setup at 2 round (range 0-31 rack bar revolution)
0421
33TM-6
0605
ACCY
Torque converter high torque limit switch Characteristics : Normal : NO, switch closed for IGV closed or max torque Settings : Setup at 28 round (range 0-31 rack bar revolution)
0436
33VG-1
1605
ENCL-T
0422
33VG-11
0991
GAS
0436
33VG-2
1605
ENCL-T
Load compartment ventilation damper limit switch Characteristics : Normal : NO Settings : Flap closed : limit switch activated, contact closed
0436
33VL-1
1658
ENCL-G
Gas compartment ventilation damper limit switch Characteristics : Normal : NO Settings : Flap closed : limit switch activated, contact closed
0436
33VL-2
1658
ENCL-G
Gas compartment ventilation damper limit switch Characteristics : Normal : NO Settings : Flap closed : limit switch activated, contact closed
0462
33WN-1
A035
WI
Water injection control valve limit switch (part of VC4-1) Characteristics : Normal : NO Settings : Valve full opened : limit switch activated, contact closed
0462
33WN-2
A035
WI
Water injection control valve limit switch (part of VC4-1) Characteristics : Normal : NO Settings : Valve full closed : limit switch activated, contact closed
0462
33WN-3
A035
WI
Water injection stop valve limit switch (part of VS2-2) Characteristics : Normal : NO Settings : Valve full opened : limit switch activated, contact closed
0462
33WN-4
A035
WI
Water injection stop valve limit switch (part of VS2-2) Characteristics : Normal : NO Settings : Valve full closed : limit switch activated, contact closed
0415
39V-1A
1218
TURB
Vibration sensor Characteristics : For 25.4 mm/s (1 in/s), 150 ± 4.5 mV peak
0415
39V-1B
1218
TURB
Vibration sensor Characteristics : For 25.4 mm/s (1 in/s), 150 ± 4.5 mV peak
0415
39V-2A
1218
TURB
Vibration sensor Characteristics : For 25.4 mm/s (1 in/s), 150 ± 4.5 mV peak
0415
39V-3A
1218
TURB
Vibration sensor Characteristics : For 25.4 mm/s (1 in/s), 150 ± 4.5 mV peak
0415
39V-3B
1218
TURB
Vibration sensor Characteristics : For 25.4 mm/s (1 in/s), 150 ± 4.5 mV peak
0415
39VS-11
235A
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0415
39VS-12
235A
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
Load compartment ventilation damper limit switch Characteristics : Normal : NO Settings : Flap closed : limit switch activated, contact closed Solenoid valve 20VG-1 limit switch Characteristics : Normal : NC Settings : Valve opened : limit switch activated, contact closed
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
9/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
10
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0415
39VS-21
235B
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0415
39VS-22
235B
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0415
39VS-23
235B
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0415
39VS-24
235B
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0415
39VS-31
235C
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0415
39VS-32
235C
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0426
43CP-1
1113
ENCL-T
Break glass unit auxiliaries compartment access door Characteristics : Normal : NO
0426
43CP-2
1113
ENCL-T
Break glass unit GT compartment access door Characteristics : Normal : NO
0426
43CP-3
1113
ENCL-T
Break glass unit auxiliaries compartment access door Characteristics : Normal : NO
0426
43CP-4
1113
ENCL-T
Break glass unit GT compartment access door Characteristics : Normal : NO
0426
43CP-5
1113
ENCL-T
Break glass unit load compartment access door Characteristics : Normal : NO
0426
43CP-6
1195
ENCL-G
Break glass unit gas compartment access door Characteristics : Normal : NO
0426
43CP-7
1195
ENCL-G
Break glass unit gas compartment access door Characteristics : Normal : NO
0442
43TW-1/PB
1105
TURB
0426
45FA-10A
1113
ENCL-T
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-10B
1113
ENCL-T
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-11A
1113
ENCL-T
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-11B
1113
ENCL-T
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-12A
1113
ENCL-T
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-12B
1113
ENCL-T
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
Off-line water wash push button Characteristics : Normal : NO
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
10/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
11
F
TBFT-TMP-FR-GTE-0060 Rev : 001
MLI
Wiring Diagram
Designation
0426
45FA-13A
1113
ENCL-T
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-13B
1113
ENCL-T
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-1A
1104
ACCY
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-1B
1104
ACCY
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-2A
1104
ACCY
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-2B
1104
ACCY
Thermostatic fire detector auxiliaries compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-6A
A116
GAS
Thermostatic fire detector gas compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-6B
1195
GAS
Thermostatic fire detector gas compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-7A
A116
GAS
Thermostatic fire detector gas compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FA-7B
A116
GAS
Thermostatic fire detector gas compartment Characteristics : Normal : NO Settings : Closed : 163 ± 14°C (325 ± 25°F)
0426
45FT-1A
1103
TURB
Thermostatic fire detector GT compartment Characteristics : Normal : NO Settings : Closed : 316 ± 14°C (600 ± 25°F)
0426
45FT-1B
1103
TURB
Thermostatic fire detector GT compartment Characteristics : Normal : NO Settings : Closed : 316 ± 14°C (600 ± 25°F)
0426
45FT-2A
1154
TURB
Thermostatic fire detector GT compartment Characteristics : Normal : NO Settings : Closed : 316 ± 14°C (600 ± 25°F)
0426
45FT-2B
1154
TURB
Thermostatic fire detector GT compartment Characteristics : Normal : NO Settings : Closed : 316 ± 14°C (600 ± 25°F)
0426
45FT-3A
1154
TURB
Thermostatic fire detector GT compartment Characteristics : Normal : NO Settings : Closed : 316 ± 14°C (600 ± 25°F)
0426
45FT-3B
1154
TURB
Thermostatic fire detector GT compartment Characteristics : Normal : NO Settings : Closed : 316 ± 14°C (600 ± 25°F)
0426
45FT-8A
1160
TURB
Thermostatic fire detector load compartment Characteristics : Normal : NO Settings : Closed : 385 ± 14°C (725 ± 25°F)
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
11/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Devices
SH
REV
12
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0426
45FT-8B
1160
TURB
Thermostatic fire detector load compartment Characteristics : Normal : NO Settings : Closed : 385 ± 14°C (725 ± 25°F)
0426
45FT-9A
1160
TURB
Thermostatic fire detector load compartment Characteristics : Normal : NO Settings : Closed : 316 ± 14°C (600 ± 25°F)
0426
45FT-9B
1160
TURB
Thermostatic fire detector load compartment Characteristics : Normal : NO Settings : Closed : 316 ± 14°C (600 ± 25°F)
0474
45HA-1
1153
ACCY
Gas detector auxiliary compartment Characteristics : Range : 0 - 20% LEL
0474
45HA-10
1113
ENCL-T
Gas detector Characteristics : Range : 0 - 20% LEL
0474
45HA-11
1113
ENCL-T
Gas detector Characteristics : Range : 0 - 20% LEL
0474
45HA-12
1113
ENCL-T
Gas detector Characteristics : Range : 0 - 20% LEL
0474
45HA-2
1153
ACCY
Gas detector auxiliary compartment Characteristics : Range : 0 - 20% LEL
0474
45HA-3
1153
ACCY
Gas detector auxiliary compartment Characteristics : Range : 0 - 20% LEL
0474
45HA-4
1195
ENCL-G
Gas detector gas module compartment ventilation duct Characteristics : Range : 0 - 20% LEL
0474
45HA-5
1195
ENCL-G
Gas detector gas module compartment ventilation duct Characteristics : Range : 0 - 20% LEL
0474
45HA-6
1195
ENCL-G
Gas detector gas module compartment ventilation duct Characteristics : Range : 0 - 20% LEL
0474
45HT-1
1154
TURB
Gas detector turbine compartment Characteristics : Range : 0 - 20% LEL
0474
45HT-2
1154
TURB
Gas detector turbine compartment Characteristics : Range : 0 - 20% LEL
0474
45HT-3
1154
TURB
Gas detector turbine compartment Characteristics : Range : 0 - 20% LEL
0474
45HT-4
1113
ENCL-T
Gas detector turbine compartment ventilation duct Characteristics : Range : 0 - 20% LEL
0474
45HT-5
1113
ENCL-T
Gas detector turbine compartment ventilation duct Characteristics : Range : 0 - 20% LEL
0474
45HT-6
1113
ENCL-T
Gas detector turbine compartment ventilation duct Characteristics : Range : 0 - 20% LEL
0436
49HA-12
1658
ENCL-G
Security thermostat gas compartment heater Characteristics : Normal : NO | Closed at 100°C (212°F)
0426
5E-1
1104
ACCY
Emergency stop button auxiliaries compartment Characteristics : Normal : NC
0426
5E-2
1104
ACCY
Emergency stop button auxiliaries compartment Characteristics : Normal : NC
VAN
Pressure switch Characteristics : Normal : NC Settings : Increase open at 3 ± 0.25 bar (43.5 ± 4 psi)
0494
63AF-11
E021
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
12/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
13
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0436
63BA-30
1605
ENCL-T
Differential pressure switch , air inlet auxiliaries compartment Settings : Closed at 1 ± 0.1 mbar (0.015 ± 0.001 psi)
0436
63BA-31
1605
ENCL-T
Differential pressure switch air inlet auxiliaries compartment Settings : Closed at 1 ± 0.1 mbar (0.015 ± 0.001 psi)
0436
63BT-30
1605
ENCL-T
Differential pressure switch air inlet Settings : Closed at 1 ± 0.1 mbar (0.015 ± 0.001 psi)
0436
63BT-40
1605
ENCL-T
Differential pressure switch air inlet Settings : Closed at 1 ± 0.1 mbar (0.015 ± 0.001 psi)
0471
0471
0471
0422
0422
0434
63CA-1
63CS-2A
63CS-2B
63FG-1
63FG-2
63HF-1
A040
A040
A040
0991
0991
0926
FILT
GT compressed air inlet filter low pressure switch Characteristics : Normal : NC Settings : Decrease open at : 5.5 ± 0.5 bar (79.77 ± 7.25 psi) | Not adjustable : increase close at : 6 ± 0.5 bar (87 ± 7.25 psi)
FILT
GT inlet air system differential pressure switch Characteristics : Normal : NC Settings : Increase open at : 23 ± 0.5 mbar (0.33 ± 0.007 psi)
FILT
GT inlet air system differential pressure switch Characteristics : Normal : NC Settings : Increase open at : 23 ± 0.5 mbar (0.33 ± 0.007 psi)
GAS
Gas fuel pressure switch Characteristics : Normal : NC Settings : Not adjustable : increase open at : 2.41 ± 0.05 bar (35.0 ± 0.75 psi) | Decrease close at : 1.03 ± 0.05 bar (15.0 ± 0.75 psi)
GAS
Gas fuel pressure switch Characteristics : Normal : NC Settings : Not adjustable : increase open at : 2.41 ± 0.05 bar (35.0 ± 0.75 psi) | Decrease close at : 1.03 ± 0.05 bar (15.0 ± 0.75 psi)
ACCY
Hydraulic filter differential pressure alarm Characteristics : Normal : NC Settings : Increase open at : 4.13 ± 0.2 bar (60 ± 3 psi) | Not adjustable : decrease close at : 2.75 ± 1.03 bar (40 ± 15 psi) Low hydraulic supply pressure auxiliary hydraulic pump start Characteristics : Normal : NO Settings : Decrease open at : 93 ± 1.7 bar (1350 ± 25 psi) | Not adjustable : increase close at : 100 ± 3.1 bar (1450 ± 45 psi)
0434
63HQ-1
0926
ACCY
0436
63JS-30
1659
ENCL-WI
0424
63LF-3
0992
ACCY
Differential pressure switch air inlet water injection compartment Settings : Closed at 1 ± 0.1 mbar (0.015 ± 0.001 psi) Fuel filter differential pressure alarm Characteristics : Normal : NC Settings : Increase open at : 1.3 ± 0.07 bar (19 ± 1 psi)
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
13/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
0477
0477
0416
DWG NO
137A3171
Devices
63PG-1
63PL-21
63QA-2
MLI
0991
918T
0926
SH
REV
14
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Wiring Diagram
Designation
GAS
Pressure switch on VA13-1 & VA13-2 intervalves space Characteristics : Normal : NC Settings : Increase open at : 3.45 ± 0.14 bar (50 ± 2 psi) | Not adjustable : decrease close at : 3.17 ± 0.21 bar (46 ± 3 psi)
TURB
Pressure switch on liquid fuel purge air Characteristics : Normal : NO Settings : Not adjustable : decrease open at : 4.6 ± 0.3 bar (67 ± 4 psi) | Increase close at : 6 ± 0.3 bar (87 ± 4 psi)
ACCY
Low lube oil pressure alarm Characteristics : Normal : NO Settings : Decrease open at : 2.8 ± 0.07 bar (40.6 ± 1 psi) | Not adjustable : increase close at : 3.1 ± 0.14 bar (45 ± 2 psi)
0416
63QQ-1
0926
ACCY
Differential pressure switch main lube oil filter Characteristics : Normal : NC Settings : Increase open at : 1.03 ± 0.068 bar (15 ± 1 psi) | Not adjustable : decrease close at : 0.9 ± 0.2 bar (13 ± 3 psi)
0416
63QQ-10
A098
MIST
Oil mist eliminator filter high pressure drop alarm Characteristics : Normal : NC Settings : Increase open at : 80 ± 3 mbar (1.16 ± 0.044 psi)
0416
63QQ-8
0916
ACCY
Torque converter filter differential pressure Characteristics : Normal : NC Settings : Increase open at : 1.5 ± 0.2 bar (21.75 ± 3 psi)
0416
63QT-2A
ALT.
GENE
Generator bearing low lube oil pressure Characteristics : Normal : NO Settings : Decrease open at : 0.55 ± 0.021 bar (8 ± 0.3 psi) | Not adjustable : increase close at : 0.62 ± 0.035 bar (9 ± 0.5 psi)
0417
63TK-1
A053
ACCY
Turbine exhaust frame cooling pressure switch Characteristics : Normal : NO Settings : Closed above 381 ± 19 mm H2O (15 ± 0.75 in H2O) Turbine exhaust frame cooling pressure switch Characteristics : Normal : NO Settings : Closed above 381 ± 19 mm H2O (15 ± 0.75 in H2O)
0417
63TK-2
A053
ACCY
0436
63VG-30
1605
ENCL-T
Differential pressure switch, air inlet load compartment Settings : Closed at 1 ± 0.1 mbar (0.015 ± 0.001 psi)
0436
63VL-30
1658
ENCL-T
Differential pressure switch, air inlet gas compartment Settings : Closed at 1 ± 0.1 mbar (0.015 ± 0.001 psi)
0462
63WN-1
A035
WI
Water injection differential pressure switch Characteristics : Normal : NC Settings : Open on decreasing pressure / atm : -0.270 ± 0.01 bar (-3.9 ± 0.14 psi)
0462
63WN-2
A035
WI
Water injection pressure switch Characteristics : Normal : NO Settings : Open on decreasing pressure : 25 bar (363 psi)
0462
63WN-3
A035
WI
Water injection differential pressure switch Characteristics : Normal : NC Settings : Open on increasing differential pressure : 1.03 bar ± 0.1 bar (15 ± 1 psi)
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
14/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Devices
SH
REV
15
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0424
65FP
0533
ACCY
Liquid fuel pump (by pass valve) servo valve
0422
65GC-1
0509
GAS
Gas control valve servo valve (VGC-1)
0494
71FA-11
E021
VAN
Level switch Characteristics : Normal : NO Settings : Opening on low level
0494
71FA-12
E021
VAN
Level switch Characteristics : Normal : NO Settings : Opening on low level
0442
71FF-4
969L
TURB
Level sensor Characteristics : Normal : NC Settings : Opening on high level
0442
71FF-5
969L
TURB
Level sensor Characteristics : Normal : NC Settings : Opening on high-high level
0442
71FF-6
969L
TURB
Level sensor Characteristics : Normal : NC Settings : Opening on high-high level
0424
77FD-1
0910
ACCY
Flow divider magnetic pickup-speed Settings : Gap : 0.23 ± 0.025 mm (0.009 ± 0.001 in)
0424
77FD-2
0910
ACCY
Flow divider magnetic pickup-speed Settings : Gap : 0.23 ± 0.025 mm (0.009 ± 0.001 in)
0424
77FD-3
0910
ACCY
Flow divider magnetic pickup-speed Settings : Gap : 0.23 ± 0.025 mm (0.009 ± 0.001 in)
0415
77HT-1
0546
TURB
Speed sensor Settings : Gap : 1.27 ± 0.127 mm (0.05 ± 0.005 in)
0415
77HT-2
0546
TURB
Speed sensor Settings : Gap : 1.27 ± 0.127 mm (0.05 ± 0.005 in)
0415
77HT-3
0546
TURB
Speed sensor Settings : Gap : 1.27 ± 0.127 mm (0.05 ± 0.005 in)
0415
77NH-1
0546
TURB
Speed sensor Settings : Gap : 1.27 ± 0.127 mm (0.05 ± 0.005 in)
0415
77NH-2
0546
TURB
Speed sensor Settings : Gap : 1.27 ± 0.127 mm (0.05 ± 0.005 in)
0415
77NH-3
0546
TURB
Speed sensor Settings : Gap : 1.27 ± 0.127 mm (0.05 ± 0.005 in)
0415
77RP-11
235A
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0425
88AB-1
1047
ACCY
Atomizing air booster motor Characteristics : 15 kW | 2925 rpm | 415 VAC | 50 Hz
0436
88BA-1
1605
ENCL-T
Cooling air fan motor - acoustic enclosure GT compartment Characteristics : 15 kW | - rpm | 415 VAC | 50 Hz
0436
88BA-2
1605
ENCL-T
Cooling air fan motor - acoustic enclosure GT compartment Characteristics : 15 kW | - rpm | 415 VAC | 50 Hz
0436
88BT-1
1605
ENCL-T
Cooling air fan motor - acoustic enclosure GT compartment Characteristics : 37 kW | - rpm | 415 VAC | 50 Hz
0436
88BT-2
1605
ENCL-T
Cooling air fan motor - acoustic enclosure GT compartment Characteristics : 37 kW | - rpm | 415 VAC | 50 Hz
0421
88CR-1
0603
ACCY
Electrical cranking motor Characteristics : 1000 kW | 2975 rpm | 6.6 kV | 50 Hz
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
15/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
16
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0494
88FA-10
E021
VAN
Electrical motor Characteristics : 0.46 kW | 1500 rpm | 240 VAC | 50 Hz
0494
88FA-11
E021
VAN
Electrical motor Characteristics : 0.37 kW | 1500 rpm | 415 VAC | 50 Hz
0494
88FA-12
E021
VAN
Electrical motor Characteristics : 0.37 kW | 1500 rpm | 415 VAC | 50 Hz
0424
88FM
0613
ACCY
Flow divider starting motor Characteristics : 0.37 kW | 1400 rpm | 415 VAC | 50 Hz
0434
88HQ-1
0628
ACCY
Auxiliary hydraulic supply pump motor Characteristics : 15 kW | 1450 rpm | 415 VAC | 50 Hz
0436
88JS-1
1659
ENCL-WI
Cooling air fan motor water injection skid enclosure Characteristics : 0.37 kW | - rpm | 415 VAC | 50 Hz
0436
88JS-2
1659
ENCL-WI
Cooling air fan motor water injection skid enclosure Characteristics : 0.37 kW | - rpm | 415 VAC | 50 Hz
0416
88QA-1
1006
ACCY
0424
88QAOB
0611
OTHER
0416
88QE-1
1007
ACCY
0424
88QEOB
0611
OTHER
0416
88QV-1
A098
MIST
Lube oil mist eliminator motor Characteristics : 18.5 kW | 3000 rpm | 415 VAC | 50 Hz
0416
88QV-2
A098
MIST
Lube oil mist eliminator motor Characteristics : 18.5 kW | 3000 rpm | 415 VAC | 50 Hz
0421
88TG-1
0538
ACCY
Turning gear electrical motor Characteristics : 30 kW | 725 rpm | 415 VAC | 50 Hz
0417
88TK-1
1233
ACCY
Turbine exhaust frame cooling blower & motor Characteristics : 45 kW | 2900 rpm | 415 VAC | 50 Hz
0417
88TK-2
1233
ACCY
Turbine exhaust frame cooling blower & motor Characteristics : 45 kW | 2900 rpm | 415 VAC | 50 Hz
0421
88TM-1
0605
ACCY
Torque adjuster drive motor Characteristics : 1.5 kW | 3000 rpm | 415 VAC | 50 Hz
0436
88VG-1
1605
ENCL-T
Cooling air fan motor acoustic enclosure load compartment Characteristics : 11 kW | - rpm | 415 VAC | 50 Hz
0436
88VG-2
1605
ENCL-T
Cooling air fan motor acoustic enclosure load compartment Characteristics : 11 kW | - rpm | 415 VAC | 50 Hz
0436
88VL-1
1658
ENCL-G
Cooling air fan motor gas module acoustic enclosure Characteristics : 4 kW | - rpm | 415 VAC | 50 Hz
0436
88VL-2
1658
ENCL-G
Cooling air fan motor gas module acoustic enclosure Characteristics : 4 kW | - rpm | 415 VAC | 50 Hz
0462
88WN-1
A035
WI
Water injection pump motor Characteristics : 55 kW | 3000 rpm | 415 VAC | 50 Hz
0422
90SR-1
0507
GAS
0469
90TV-1
0548
TURB
Auxiliary lube oil pump motor Characteristics : 90 kW | 3000 rpm | 415 VAC | 50 Hz Liquid fuel Warren pump normal lubrication pump motor Characteristics : 0.75 kW | 415 VAC Emergency lube oil pump motor Characteristics : 7.5 kW | 1750 rpm | 125 VDC Liquid fuel Warren pump emergency lubrication pump motor Characteristics : 0.75 kW | 125 VDC
Speed ratio/stop valve servovalve Servovalve, compressor IGV actuator
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
16/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
MLI
SH
REV
17
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Wiring Diagram
Designation Electro-pneumatic converter Settings : 04 ± 0.20 mA for 0 ± 0.01 bar (0 ± 0.14 psi) 20 ± 0.20 mA for 3.1 ± 0.1 bar (45 ± 1.4 psi)
0462
90WN-1
A035
WI
0436
95BA-1
1605
ENCL-T
Air flow control (anemometer) for ventilation Settings : 16 ± 1 mA when the fan is running
ENCL-T
Air flow control (anemometer) for ventilation Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for ventilation Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for ventilation Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for ventilation Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for ventilation Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for turbine enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for turbine enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for turbine enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for turbine enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-T
Air flow control (anemometer) for turbine enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
0436
0436
0436
0436
0436
0436
0436
0436
0436
0436
95BA-2
95BA-3
95BA-4
95BA-5
95BA-6
95BT-1
95BT-2
95BT-3
95BT-4
95BT-5
1605
1605
1605
1605
1605
1605
1605
1605
1605
1605
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
17/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
MLI
SH
REV
18
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Wiring Diagram
Designation Air flow control (anemometer) for turbine enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
0436
95BT-6
1605
ENCL-T
0415
95SG-13
1213
TURB
Ignition transformer for 95SP-13 Characteristics : 0.15 kVA | 115 VAC (230 VAC) | 15 kV | 50 Hz
0415
95SG-14
1213
TURB
Ignition transformer for 95SP-14 Characteristics : 0.15 kVA | 115 VAC (230 VAC) | 15 kV | 50 Hz
0415
95SP-13
1214
TURB
Spark plug for combustion chamber n°13
0415
95SP-14
1214
TURB
Spark plug for combustion chamber n°14
0436
0436
95VL-1
95VL-2
1658
1658
ENCL-G
Air flow control (anemometer) for gas skid enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
ENCL-G
Air flow control (anemometer) for gas skid enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA } Air flow control (anemometer) for gas skid enclosure Characteristics : 4 - 20 mA for 0.5 - 30 m/s Settings : fan not running, 0% air flow : 4 -0/+1 mA fan running and doors closed : adjust the speedtronic constant software at a value equivalent to { [60% * (x1 - 4) ] + 4 mA }
0436
95VL-3
1658
ENCL-T
0425
96AD-1
0926
ACCY
Atomizing air main compressor differential pressure transmitter Settings : 4 ± 0.02 mA for 0 bar (0 psi) 20 ± 0.1 mA for 6 bar (87 psi)
0492
96AP-1A
0559
ACCY
Pressure transmitter Settings : 04 ± 0.02 mA for 0.745 bar abs (22 in of Hg) 20 ± 0.10 mA for 1.250 bar abs (36.9 in of Hg)
0492
96AP-1B
0559
ACCY
Pressure transmitter Settings : 04 ± 0.02 mA for 0.745 bar abs (22 in of Hg) 20 ± 0.10 mA for 1.250 bar abs (36.9 in of Hg)
ACCY
Pressure transmitter Settings : 04 ± 0.02 mA for 0.745 bar abs (22 in of Hg) 20 ± 0.10 mA for 1.250 bar abs (36.9 in of Hg)
ACCY
Pressure transmitter Settings : 04 ± 0.02 mA for 0.000 bar (0.000 in of H2O) 20 ± 0.10 mA for 0.345 bar (138.5 in of H2O)
0492
0492
96AP-1C
96BD-1
0559
0559
0417
96CD-1A
0557
ACCY
Compressor discharge pressure transmitter Settings : 04 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.05 mA for 21 bar (304.5 psi)
0417
96CD-1B
0557
ACCY
Compressor discharge pressure transmitter Settings : 04 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.05 mA for 21 bar (304.5 psi)
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
18/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
MLI
SH
REV
19
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Wiring Diagram
Designation
0417
96CD-1C
0557
ACCY
Compressor discharge pressure transmitter Settings : 04 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.05 mA for 21 bar (304.5 psi)
0492
96CS-1
0559
ACCY
Pressure transmitter Settings : 04 ± 0.02 mA for 0 mbar 20 ± 0.10 mA for 27.4 mbar (11 in of H2O)
0471
96CS-3
A040
FILT
GT air inlet system differential pressure transmitter Settings : 04 ± 0.05 mA for 0 mbar (0 psi) 20 ± 0.05 mA for 63 mbar (0.91 psi)
0422
96FG-1
0991
GAS
Inlet gas fuel module pressure transmitter Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 34.5 bar (500 psi)
GAS
Fuel gas inter-valve pressure transmitter Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 34.5 bar (500 psi)
GAS
Fuel gas inter-valve pressure transmitter Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 34.5 bar (500 psi)
0422
0422
96FG-2A
96FG-2B
0991
0991
0422
96FG-2C
0991
GAS
Fuel gas inter-valve pressure transmitter Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 34.5 bar (500 psi)
0424
96FL-2A
0992
ACCY
Liquid fuel module pressure transmitter inlet Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 10 bar (145 psi)
0424
96FL-2B
0992
ACCY
Liquid fuel module pressure transmitter inlet Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 10 bar (145 psi)
0424
96FP-1
0992
ACCY
Liquid fuel control valve (VC3) LVDT Settings : 0.7 ± 0.01 VAC for 0 mm 3.5 ± 0.01 VAC for 20.5 mm (0.81 in)
0424
96FP-2
0992
ACCY
Liquid fuel control valve (VC3) LVDT Settings : 0.7 ± 0.01 VAC for 0 mm 3.5 ± 0.01 VAC for 20.5 mm (0.81 in)
0422
96GC-1,2
0509
GAS
Gas control valve (VGC-1) LVDT Settings : 0.7 ± 0.01 VAC for 0 mm
0416
96QA-2
0926
ACCY
Lube oil system VPR-2 inlet pressure transmitter Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 7 bar (101.5 psi)
ACCY
Lube oil tank level transmitter Settings : 4 ± 0.05 mA for 456 mm (17.95 in) 20 ± 0.1 mA for 246 mm (9.68 in)
0416
96QL-1
1038
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
19/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
MLI
SH
REV
20
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Wiring Diagram
Designation
0416
96QT-2B
ALT.
GENE
Low lube oil pressure transmitter generator Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 1.72 bar (25 psi)
0416
96QV-1
A098
MIST
Tank's air vacuum differential pressure transmitter Settings : 4 ± 0.05 mA for 0 bar (0 psi) 20 ± 0.1 mA for 0.025 bar (0.36 psi)
0471
96RH
A040
FILT
Dew point and temperature transmitter Settings : Outlet 1 : 04 ± 0.05 mA for -50°C (-58 °F) 20 ± 0.05 mA for +50°C (122 °F) Outlet 2 : 04 ± 0.05 mA for 0% RH 20 ± 0.05 mA for 100 % RH
0422
96SR-1,2
0507
GAS
Stop ratio fuel gas (VSR-1) LVDT Settings : 0.7 ± 0.01 VAC for 0 mm
0471
96TF-1
A040
FILT
Differential pressure transmitter of total filtration stages Settings : 4 ± 0.05 mA for 0 mbar (0 psi) 20 ± 0.1 mA for 25 mbar (0.36 psi)
0421
96TM-1
0605
ACCY
Torque converter IGV position transmitter Settings : 04 ± 0.05 mA for 0 rack bar revolution (range 0-31 rack bar revolution ) 20 ± 0.05 mA for 31 rack bar revolution (range 0-31 rack bar revolution )
0469
96TV-1
0548
TURB
LVDT (Linear variable displacement transmitter), compressor IGV actuator Settings : 0.7 ± 0.01 VAC for 34° IGV angle
0469
96TV-2
0548
TURB
LVDT (Linear variable displacement transmitter), compressor IGV actuator Settings : 0.7 ± 0.01 VAC for 34° IGV angle
0415
96VC-11
235A
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0415
96VC-12
235A
TURB
Vibration sensor Characteristics : Output proximitor : 7.87 V/mm (0.2 V/mil) Settings : Gap : 1.4 ± 0.05 mm (0.055 ± 0.002 in)
0422
96VM-1
0639
GAS
Mass flow transmitter Settings : Factory Calibrated : 4 ± 0.05 mA for 0 kg/s (0 lbm/s) 20 ± 0.1 mA for 10 kg/s (22 lbm/s)
0462
96WF-1
A035
WI
Flow transmitter Settings : 04 ± 0.2 mA for 0 m3/h (0 gpm) 20 ± 0.2 mA for 30 ± 0.1 m3/h (132 ± 0.44 gpm)
0462
96WF-2
A035
WI
Flow transmitter Settings : 04 ± 0.2 mA for 0 m3/h (0 gpm) 20 ± 0.2 mA for 30 ± 0.1 m3/h (132 ± 0.44 gpm)
0462
96WF-3
A035
WI
Flow transmitter Settings : 04 ± 0.2 mA for 0 m3/h (0 gpm) 20 ± 0.2 mA for 30 ± 0.1 m3/h (132 ± 0.44 gpm)
0425
AAT-1A
637T
TURB
Atomizing air precooler air discharge thermocouple Characteristics : Type K
SIZE
CAGE CODE
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137A3171 SECTION 01E
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20/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
21
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation Atomizing air precooler air discharge thermocouple Characteristics : Type K
0425
AAT-2A
637T
TURB
0434
AH1-1
0908
N/A
Control oil hydraulic accumulator Characteristics : 17.8 l (4.7 gal) | Nitrogen Settings : 51.7 ± 1 bar (750 ± 15 psi)
0422
AH1-3
0991
N/A
Control oil hydraulic accumulator Characteristics : 17.8 l (4.70 gal) Settings : 51.7 ± 1 bar (750 ± 15 psi)
0471
AR-20
A040
FILT
Air filter electrical control box
0436
AT-AC-1
1113
ENCL-T
Thermocouple accessory compartment Characteristics : Type K
0436
AT-AC-11
1113
ENCL-T
Thermocouple gas compartment Characteristics : Type K
0436
AT-LC-1
637T
TURB
Air temperature load compartment Characteristics : Platinum PT100 | 100 Ohm at 0°C (32°F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0436
AT-TC-1
637T
TURB
Air temperature turbine compartment Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0436
AT-TC-2
1113
ENCL-T
Thermocouple : turbine compartment enclosure Characteristics : Type K
0436
AT-TC-3
1113
ENCL-T
Thermocouple : turbine compartment enclosure Characteristics : Type K
0436
AT-WI-1
1659
ENCL-WI
Water injection compartment temperature water injection compartment Characteristics : Type K
0415
BT-J1-1A,1B
235A
TURB
Dual thermocouple temperature journal bearing n°1 Characteristics : Type K
0415
BT-J1-2A,2B
235A
TURB
Dual thermocouple temperature journal bearing n°1 Characteristics : Type K
0415
BT-J2-1A,1B
235B
TURB
Dual thermocouple temperature journal bearing n°2 Characteristics : Type K
0415
BT-J2-2A,2B
235B
TURB
Dual thermocouple temperature journal bearing n°2 Characteristics : Type K
0415
BT-J3-1A,1B
235C
TURB
Dual thermocouple temperature journal bearing n°3 Characteristics : Type K
0415
BT-J3-2A,2B
235C
TURB
Dual thermocouple temperature journal bearing n°3 Characteristics : Type K
0415
BT-TA1-2A,2B
235A
TURB
Dual thermocouple temperature pad n°2 of thrust bearing n°1 Characteristics : Type K
0415
BT-TA1-5A,5B
235A
TURB
Dual thermocouple temperature pad n°5 of thrust bearing n°1 Characteristics : Type K
0415
BT-TA1-8A,8B
235A
TURB
Dual thermocouple temperature pad n°8 of thrust bearing n°1 Characteristics : Type K
0415
BT-TI1-2A,2B
235A
TURB
Dual thermocouple temperature pad n°2 of counter thrust bearing n°1 Characteristics : Type K
0415
BT-TI1-5A,5B
235A
TURB
Dual thermocouple temperature pad n°5 of counter thrust bearing n°1 Characteristics : Type K
0415
BT-TI1-9A,9B
235A
TURB
Dual thermocouple temperature pad n°9 of counter thrust bearing n°1 Characteristics : Type K
SIZE
CAGE CODE
A4
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137A3171 SECTION 01E
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SHEET
21/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Devices
SH
REV
22
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0425
CA1
0607
N/A
Main atomizing air compressor Characteristics : Centrifugal | 2.7 kg/s | 6600 rpm
0425
CA2
1047
N/A
Booster atomizing air compressor Characteristics : Volumetric | 510 m3/h (2245.46 gal/min) | 6200 rpm
0415
CT-DA-1
637T
TURB
Thermocouple temperature compressor air outlet Characteristics : Type K
0415
CT-DA-2
637T
TURB
Thermocouple temperature compressor air outlet Characteristics : Type K
0415
CT-IF-1
637T
TURB
Thermocouple temperature compressor air inlet Characteristics : Type K
0415
CT-IF-2
637T
TURB
Thermocouple temperature compressor air inlet Characteristics : Type K
0492
CT-IF-3/R
637T
TURB
Resistance temperature detector Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0421
ET-CRS-11/R
0603
ACCY
Cranking motor stator Ph1 temperature sensor 1 Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0421
ET-CRS-12/R
0603
ACCY
Cranking motor stator Ph1temperature sensor 2 Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0421
ET-CRS-21/R
0603
ACCY
Cranking motor stator Ph2 temperature sensor 1 Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0421
ET-CRS-22/R
0603
ACCY
Cranking motor stator Ph2 temperature sensor 2 Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0421
ET-CRS-31/R
0603
ACCY
Cranking motor stator Ph3 temperature sensor 1 Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0421
ET-CRS-32/R
0603
ACCY
Cranking motor stator Ph3 temperature sensor 2 Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0477
FA3-1
918T
N/A
Liquid fuel purge air filter Characteristics : 5 µm
0425
FA4-1
0983
N/A
Filter on actuation air of atomizing air and purge systems Characteristics : 5 µm
0462
FA8-2
A035
N/A
Water injection air filter Characteristics : 5 µm
0424
FD1-1
0613
N/A
Flow divider Characteristics : type lineare 7 elements with double pumps ; 14 elements 60 tooth wheel | 1650 Hz | 883 l/min (233 gpm) at 1650 rpm
0494
FF11-1
E021
N/A
Filter Characteristics : 910 µm
0494
FF11-2
E021
N/A
Filter Characteristics : 910 µm
0424
FF2-1
1014
N/A
HP fuel filter Characteristics : Beta 40 = 75
0424
FF2-2
1014
N/A
HP fuel filter Characteristics : Beta 40=75
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
22/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Devices
SH
REV
23
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0434
FH2-1
1051
N/A
Hydraulic oil supply filter Characteristics : Beta 3 > 200
0434
FH2-2
1051
N/A
Hydraulic oil supply filter Characteristics : Beta 3 > 200
0424
FH3
0992
N/A
Hydraulic filter liquid fuel servo valve (control) Characteristics : 40 µm
0469
FH6-1
0548
N/A
Filter, hydraulic oil supply , IGV controller assembly Characteristics : Beta 15 = 75
0422
FH7-1
0507
N/A
Servo hydraulic supply filter of stop ratio valve (VSR) Characteristics : 15 µ abs
0422
FH8-1
0509
N/A
Gas fuel control valve (VGC) servo hydraulic oil supply filter Characteristics : 15 µ abs
0462
FM1-1
A035
WI
0462
FW1-1
A035
N/A
High pressure filter Characteristics : Beta 13 = 75
0462
FW1-2
A035
N/A
Water injection upstream pump unit conical filter Characteristics : Filtering media 800µm
0462
FW1-3
A035
N/A
Conical filter downstream flowmeter Characteristics : Filtering media 150µm
0421
HM-1
0605
N/A
Torque converter and reversing gear
0469
HM3-1
0548
N/A
Actuator assembly, inlet guide valve system Characteristics : Actuator operation limits : 32° to 86°
0425
HX1-1
1003
N/A
Atomizing air precooler
0416
LT-B1D-1
637T
TURB
Lube oil thermocouple #1 bearing drain Characteristics : Type K
0416
LT-B2D-1
637T
TURB
Lube oil thermocouple #2 bearing drain Characteristics : Type K
0416
LT-B3D-1
637T
TURB
Lube oil thermocouple #3 bearing drain Characteristics : Type K
0416
LT-BT1D-1
637T
TURB
Lube oil thermocouple #1 bearing thrusts drain Characteristics : Type K
0416
LT-G1D-1
ALT.
GENE
Lube oil thermocouple generator and load gear #1 bearing drain Characteristics : Type K
0416
LT-G2D-1
ALT.
GENE
Lube oil thermocouple generator and load gear #2 bearing drain Characteristics : Type K
0416
LT-OT-1A
637A
ACCY
Resistance temperature detector Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0416
LT-OT-2A
637A
ACCY
Resistance temperature detector Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0416
LT-TH-1A,1B
637A
ACCY
Lube oil temperature turbine header thermocouple Characteristics : Type K
0416
LT-TH-2A,2B
637A
ACCY
Lube oil temperature turbine header thermocouple Characteristics : Type K
0416
LT-TH-3A,3B
637A
ACCY
Lube oil temperature turbine header thermocouple Characteristics : Type K
Water injection flowmeter Characteristics : 3.6 m3/h (16 gpm) | 29.5 m3/h (130 gpm) | Nominal K factor : 158.5 pulse / l (600 pulse/US gallon)
SIZE
CAGE CODE
A4
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137A3171 SECTION 01E
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Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Devices
SH
REV
24
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0422
MG1
0512
N/A
Gas fuel nozzle
0424
PF1
0611
ACCY
Main fuel Pump Characteristics : Positive displacements screw up | 870.5 l/min (230 gpm) | 68.9 bar (1000 psi) | 1500 rpm
0424
PF1-90
0611
N/A
Lubricator pump Characteristics : Refer to P&ID LMA-37361
0494
PFA-10
E021
N/A
Unloading pump Characteristics : Volumetric pump | 25 l/min (6.60 gpm)
0494
PFA-11
E021
N/A
Dosing pump Characteristics : Volumetric pump | 4 l/h (0.88 Gal/h) | 10 bar (145 psi) | 1500 rpm
0494
PFA-12
E021
N/A
Dosing pump Characteristics : Volumetric pump | 4 l/h (0.88 Gal/h) | 10 bar (145 psi) | 1500 rpm
0434
PH1
0627
ACCY
Main hydraulic supply pump Characteristics : Volumetric pump | 65 l/min (17.1 gpm) | 105 bar (1500 psi) | 1422 rpm
0434
PH2
0628
ACCY
Auxiliary hydraulic supply pump Characteristics : Volumetric pump | 45.4 l/min (12 gpm) | 105 bar (1500 psi) | 1450 rpm
0494
PSV-11
E021
N/A
Breather valve of 501BA tank Characteristics : Normal : NC Settings : Overpressure : 0.15 bar (2.17 psi); Vaccum : 0.01 bar (0.15 psi)
0462
PW1-1
A035
N/A
Water injection pump unit
0426
SLI-1
1104
ACCY
Light warning auxiliaries compartment Characteristics : 240 UPS | 50 Hz
0426
SLI-1A
1113
ENCL-T
Fire alarm auxiliaries compartment Characteristics : 24 VDC
0426
SLI-1B
1113
ENCL-T
Fire alarm GT compartment Characteristics : 24 VDC
0426
SLI-1C
1113
ENCL-T
Fire alarm GT compartment Characteristics : 24 VDC
0426
SLI-1D
1195
ENCL-G
Fire alarm gas compartment Characteristics : Visual alarm | 24 VDC
0426
SLI-1E
1195
ENCL-G
Fire alarm gas compartment Characteristics : 24 VDC
0426
SLI-2
1104
ACCY
0426
SLI-2B
1113
ENCL-T
Fire alarm GT compartment Characteristics : 24 VDC
0426
SLI-2C
1113
ENCL-T
Fire alarm GT compartment Characteristics : 24 VDC
0426
SLI-2E
1195
ENCL-G
Fire alarm gas compartment Characteristics : 24 VDC
0426
SLI-3C
1113
ENCL-T
Fire alarm load compartment Characteristics : 24 VDC
0415
TT-IB-1
637T
TURB
Thermocouple temperature exhaust tunnel Characteristics : Type K
0415
TT-WS1AO-1
637T
TURB
Thermocouple temperature outer position after first wheel space Characteristics : Type K
0415
TT-WS1AO-2
637T
TURB
Thermocouple temperature outer position after first wheel space Characteristics : Type K
Light warning auxiliaries compartment Characteristics : 240 UPS | 50 Hz
SIZE
CAGE CODE
A4
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137A3171 SECTION 01E
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24/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
25
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0415
TT-WS1FI-1
637T
TURB
Thermocouple temperature inner position forward first wheel space Characteristics : Type K
0415
TT-WS1FI-2
637T
TURB
Thermocouple temperature inner position forward first wheel space Characteristics : Type K
0415
TT-WS2AO-1
637T
TURB
Thermocouple temperature outer position after second wheel space Characteristics : Type K
0415
TT-WS2AO-2
637T
TURB
Thermocouple temperature outer position after second wheel space Characteristics : Type K
0415
TT-WS2FO-1
637T
TURB
Thermocouple temperature outer position forward second wheel space Characteristics : Type K
0415
TT-WS2FO-2
637T
TURB
Thermocouple temperature outer position forward second wheel space Characteristics : Type K
0415
TT-WS3AO-1
637T
TURB
Thermocouple temperature outer position after third wheel space Characteristics : Type K
0415
TT-WS3AO-2
637T
TURB
Thermocouple temperature outer position after third wheel space Characteristics : Type K
0415
TT-WS3FO-1
637T
TURB
Thermocouple temperature outer position forward third wheel space Characteristics : Type K
0415
TT-WS3FO-2
637T
TURB
Thermocouple temperature outer position forward third wheel space Characteristics : Type K
0415
TT-XD-1
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-10
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-11
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-12
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-13
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-14
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-15
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-16
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-17
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-18
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-19
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-2
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-20
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-21
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
25/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
26
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0415
TT-XD-22
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-23
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-24
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-3
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-4
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-5
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-6
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-7
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-8
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0415
TT-XD-9
0623
TURB
Thermocouple temperature exhaust gas diffuser Characteristics : Type K
0477
VA13-1
918T
N/A
Fuel gas circuit purge air valve Characteristics : Normal : NC Settings : Opening time shall be 35 ± 5 seconds. Closing time shall be 10 seconds at maximum.
0477
VA13-2
918T
N/A
Fuel gas circuit purge air valve Characteristics : Normal : NC Settings : Opening time shall be 35 ± 5 seconds. Closing time shall be 10 seconds at maximum.
0442
VA17-1
1026
N/A
False start drain valve-combustion wrapper Characteristics : Normal : NO
0442
VA17-2
1026
N/A
False start drain valve-exhaust frame Characteristics : Normal : NO
0442
VA17-5
1026
N/A
False start drain valve-exhaust plenum Characteristics : Normal : NO
0425
VA18-1
1070
N/A
Atomizing air compressor pressure adjustment valve Characteristics : Normal : NC
0477
VA19-1
918T
N/A
Liquid fuel purge air valve Characteristics : Normal : C to L opened ; U closed
0417
VA2-1
1022
N/A
Compressor bleed valve 11th stage Characteristics : Normal : NO
0417
VA2-2
1022
N/A
Compressor bleed valve 11th stage Characteristics : Normal : NO
0425
VA22-1
0922
N/A
CA2 booster atomizing air compressor inlet air isolation butterfly valve Characteristics : Normal : NO
0417
VA2-3
1022
N/A
Compressor bleed valve 11th stage Characteristics : Normal : NO
0417
VA2-4
1022
N/A
Compressor bleed valve 11th stage Characteristics : Normal : NO
SIZE
CAGE CODE
A4
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137A3171 SECTION 01E
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SHEET
26/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Devices
MLI
SH
REV
27
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Wiring Diagram
Designation
0477
VA36-1
918T
N/A
Quick exhaust pneumatic valve Characteristics : under pressure: 1 to 2 open and vent 3 closed out of pressure: 2 open to vent 3
0477
VA36-2
918T
N/A
Quick exhaust pneumatic valve Characteristics : under pressure: 1 to 2 open and vent 3 closed out of pressure: 2 open to vent 3
0494
VA99-11
E021
N/A
Pneumatic valve Characteristics : Normal : NO
0494
VA99-12
E021
N/A
Pneumatic valve Characteristics : Normal : NC
0494
VA99-13
E021
N/A
Pneumatic valve Characteristics : Normal : NO
0434
VAB1
0947
N/A
Hydraulic system air bleed valve (main)
0434
VAB2
0947
N/A
Hydraulic system air bleed valve (auxiliary)
0424
VC3
0516
N/A
By pass control valve Characteristics : Normal : NO | Stroke = 28.57 mm (1.125 in)
0462
VC4-1
A035
N/A
Water injection flow control valve Characteristics : Normal : NC
0462
VCK100
A035
N/A
Check valve
0462
VCK110
A035
N/A
Check valve
0462
VCK111
A035
N/A
Check valve
0424
VCK1-1T14
0961
N/A
Liquid fuel nozzle check valve Characteristics : Normal : NC Settings : Cracking pressure : 8.27 ± 0.34 bar (120 ± 5 psi)
0477
VCK2-1T14
918T
N/A
Liquid fuel primary nozzle purge air check valve Characteristics : Normal : NC Settings : Cracking pressure : Minimum 0.07 bar (1 psi)
0434
VCK3-1
0947
N/A
Hydraulic pump check valve for main pump Characteristics : Normal : NC Settings : Treshold = 1.5 bar (21.75 psi)
0434
VCK3-2
0947
N/A
Hydraulic pump check valve for auxiliary pump Characteristics : Normal : NC Settings : Treshold = 1.5 bar (21.75 psi)
0417
VCK7-1
1233
N/A
Turbine exhaust frame cooling check valve Characteristics : Normal : NC Settings : opening pressure : 7 mbar (0.1 psi)
0417
VCK7-2
1233
N/A
Turbine exhaust frame cooling check valve Characteristics : Normal : NC Settings : opening pressure : 7 mbar (0.1 psi)
0422
VGC-1
0509
GAS
Gas control valve primary Characteristics : Normal : NC | Stroke maxi = 38.1 mm (1.5 in)
0469
VH3-1A
0548
N/A
Trip relay, hydraulic IGV
0469
VH3-1B
0548
N/A
Trip relay, hydraulic IGV
0422
VH5-1
0507
GAS
Gas fuel dump valve (VSR-1) - Stop/speed ratio valve Characteristics : Normal : NC
0422
VH5-2
0509
GAS
Gas fuel dump valve (VGC-1) - Gas control valve Characteristics : Normal : NC
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
27/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Devices
SH
REV
28
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0422
VM-1
0639
N/A
Coriolis mass flow meter
0434
VM4
1052
N/A
Hydraulic filter transfer valve
0424
VP-1
0961
N/A
Fuel liquid purge multiport valve Characteristics : Normal : NC
0424
VP-2
0961
N/A
Fuel liquid purge multiport valve Characteristics : Normal : NC
0416
VPR2-1
1023
N/A
Bearing header pressure regulator valve Characteristics : Normal : NC Settings : Set point : 1.72 +0.13/-0 bar (25 +2/-0 psi)
0494
VPR30-11
E021
N/A
Filter regulator Characteristics : Normal : NO Settings : 4 ± 0.35 bar (58 ± 5 psi)
0434
VPR3-1
0627
N/A
Hydraulic supply pump (PH1) compensator Settings : 103.4 ± 1.37 bar (1500 ± 20 psi)
0477
VPR44-1
918T
N/A
Filter pressure regulator on actuation air of gas fuel purge air valve Settings : 2.3 +0/-0.2 bar (33 +0/-3 psi)
0477
VPR44-2
918T
N/A
Filter pressure regulator on actuation air of gas fuel purge air valve Settings : 2.3 +0/-0.2 bar (33 +0/-3 psi)
0477
VPR54-1
918T
N/A
Filter pressure regulator on actuation air of liquid fuel purge air valve Settings : 3.27 +1.7/-0 bar (47.5 +2.7/-0 psi)
0462
VPR62-1
A035
N/A
Water injection control valve pressure regulation (part of VC4-1) Settings : 3.1 ± 0.1 bar (45 ± 1.5 psi)
0462
VPR62-13
A035
N/A
Water Injection control valve pressure regulation (part of VS2-2) Settings : 3.1 ± 0.1 bar (45 ± 1.5 psi)
0425
VPR68-1
0922
N/A
Pressure regulator valve booster AA isolation valve Settings : 3.79 ± 0.13 bar (55 ± 2 psi)
0416
VR1
1016
N/A
Main lube oil pump pressure relief valve Characteristics : Normal : NC Settings : Opening at 6.89 + 0.13/-0 bar (100 + 2/-0 psi)
0434
VR21
0947
N/A
Main hydraulic supply pump pressure relief valve Characteristics : Normal : NC Settings : 113.7 ± 1.37 bar (1650 ± 20 psi)
0434
VR22
0947
N/A
Auxiliary hydraulic supply pump pressure relief valve Characteristics : Normal : NC Settings : 113.7 ± 1.37 bar (1650 ± 20 psi)
0424
VR27
0992
N/A
Fuel oil supply pressure relief valve Characteristics : Normal : NC Settings : 6.2 ± 0.2 bar (87 ± 2.9 psi)
0424
VR4
0992
N/A
Main fuel pump pressure relief valve Characteristics : Normal : NC Settings : 82.7 ± 1.72 bar (1200 ± 25 psi)
0494
VR60-11
E021
N/A
Pump relief pressure valve Characteristics : Normal : NC Settings : Opening at 12 ± 1 bar (174 ± 14.5 psi)
0494
VR60-12
E021
N/A
PFA-12 pump relief pressure valve Characteristics : Normal : NC Settings : Opening at 12 ± 1 bar (174 ± 14,5 psi)
0424
VS1
0511
N/A
Fuel oil stop valve Characteristics : Normal : NC
0462
VS2-2
A035
N/A
Water injection stop valve Characteristics : Normal : NC
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
28/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Devices
SH
REV
29
MLI
Wiring Diagram
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Designation
0422
VSR-1
0507
GAS
Fuel gas stop/speed ratio valve Characteristics : Normal : NC | Stroke maxi = 88.9 ± 0.127 mm (3.5 ± 0.05 in)
0420
VTR1-1
1035
N/A
Thermostatic valve regulating lube oil temperature Characteristics : Normal : E to B open, C closed Settings : Starts to open at Oil T° = 54 ± 2°C (130 ± 3.6 °F)
0420
VTR2-1
1027
N/A
Thermostatic valve regulating atomizing air temperature Characteristics : Normal : B to E open, C closed Settings : T° air = 107 ± 2 °C (225 ± 3.6 °F)
0420
WT-TL-1
637T
TURB
Resistance thermometer detector support legs water temperature Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
0420
WT-TL-2
637T
TURB
Resistance thermometer detector support legs water temperature Characteristics : Platinum PT100 | 100 Ohm at 0°C (32 °F) | 0.385 Ohm/°C (0.214 Ohm/°F) | -50 to 260 °C (-58 to 500 °F)
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01E
SCALE
SHEET
29/ 29
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
SH
REV
1
F
TBFT-TMP-FR-GTE-0060 Rev : 001
REVISIONS Rev A B C
D E F
Description Première édition - Modifié schéma de cablâge pour 95BT-1, 2 & 3 : ENCL-T au lieu de ENCL-?? - Ajout du package module injection d'eau (PID 0436) : 20JS-30, 33JS-1 & 2, 63JS-30, 88JS-1 & 2, AT-WI-1 - Modifié niveau de tension : remplacé 230 VAC par 240 VAC et 115 VAC par 120 VAC - Ajout appareils 20BA-31, 63BA-31, 95BA-4, 5 & 6 - Suppression des appareils 63FL-2, 71QL-1 & 71QH-1 - Ajout appareils 23QV-2 / 88QV-2 / 96QL-1 / 96QV-1 / 96FL-2A & 2B / 96FP-1 & 2 / FF2-2 / FF11-2 - Modifié PID pour MLI 0425 : 206D7308 au lieu de 209D7177 - Modifié réglage pour 63PL-21 Ajout PF1-90 Ajout de 88QAOB et 88QEOB
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
1/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
SH
REV
2
F
TBFT-TMP-FR-GTE-0060 Rev : 001
PRESSION : Toutes les pressions sont relatives, abs indique pression absolue.
Abréviations
Désignations
AA ACF AD AE AMF DEC. DPDT DPG FC FO GF GFV GPL INC. LVDT
Air d’atomisation Pression aval filtre huile contrôle Air sortie compresseur Air d’extraction Pression aval filtre principal huile Décroissant Double contact, double pôle Manomètre – Pression différentielle Fermeture par sécurité Ouverture par sécurité Combustible gazeux Event de gaz Fuite aux garnitures vanne combinée gaz Croissant Transmetteur de position linéaire différentiel Model List Item : Code composé de 4 caractères utilisé par General Electric pour identifier les composants, assemblages, plans ou spécifications, exemple : MLI 0414 pour la nomenclature des appareils de contrôle Normalement fermé Normalement ouvert Niveau d'énergie zéro absolu, aucune puissance, pas d'huile, aucune vitesse, aucune température Retour d’huile
MLI NC NO Normal OD OD OD OH OHT OL OLV OR PC Pente SPDT SPST WD WF WR
Retour d’huile au-dessus du niveau cuve à huile Retour d’huile au-dessous du niveau cuve à huile Huile de régulation HP Huile de sécurité HP Huile de graissage Event d’huile de graissage Huile de graissage modulée Point de connexion Le sens de la flèche indique l'écoulement gravitationnel du liquide dû à la pente
Simple contact, double pôle Simple contact, simple pôle Egouttures d’eau Alimentation d’eau Retour d’eau
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
2/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
SH
137A3171
REV
3
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Nom du Système
Items
Système
Référence
Système Instrumentation Turbine
0415
CD
214D1164
Système Huile de Lubrification
0416
LO
206D6970
Système Air Refroidissement et Etanchéité
0417
CSA
206D6971
Système Huile de Déclenchement
0418
TO
N/A
Système Air Instrument
0419
APU
N/A
Système Eau de Refroidissement
0420
CW
206D6786
Système de Lancement
0421
SM
205D4866
Système Combustible Gaz
0422
GF
206D6972
Système Combustible Liquide
0424
LF
206D6600
Système Air Atomisation
0425
AA
206D7308
Système Protection Incendie
0426
FP
206D6966
Système Tuyauterie Poste Air
0428
AE
N/A
Système Injection Vapeur
0431
SI
N/A
Système Réchauffage Air Aspiration
0432
IAR
N/A
Système Alimentation Huile HP
0434
HS
209D7043
Système Chauffage et Ventilation
0436
HV
206D6596
Système Nettoyage Compresseur et Turbine
0441
TCC
N/A
Système Lavage Compresseur et Turbine
0442
TCW
205D4265
Système Injection d'Eau
0462
WI
206D6293
Système Commande Aubes Variables Compresseur
0469
IGV
206D6828
Système Débit Aspiration et Echappement
0471
IE
206D6968
Système Détection Gaz
0474
GD
206D6595
Système Balayage Combustible
0477
FPU
209D7645
Système d'Injection N2
0491
NI
N/A
Système Moniteur de Performances
0492
PM
214D1258
Système Module d'Injection Additif
0494
LFAD
206D6208
Système Réducteur de Puissance
0495
LG
SIZE
CAGE CODE
A4
DWG NO
N/A
137A3171 SECTION 01F
SCALE
SHEET
3/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
SH
REV
4
F
Schéma de câblage ACCY AIR
TBFT-TMP-FR-GTE-0060 Rev : 001
Description L'appareil est dans le schéma de câblage auxiliaires (MLI 401A) L'appareil est dans le schéma de câblage du module de ventilation & refroidissement (MLI A132)
ENCL-G
L'appareil est dans le plan d'interface du package module gaz (MLI 1658)
ENCL-LF
L'appareil est dans le plan d'interface du package module fioul / air atomisation / injection d'eau (MLI 1650)
ENCL-LO
L'appareil est dans le plan d'interface du package module huile / gaz (MLI 1634)
ENCL-T
L'appareil est dans le plan d'interface du package turbine (MLI 1605)
ENCL-WI
L'appareil est dans le plan d'interface du package module d'injection d'eau (MLI 1659)
FILT
L'appareil est dans le schéma de câblage du filtre à air (MLI A040)
GAS
L'appareil est dans le schéma de câblage module gaz (MLI 0991 ou 401G)
GENE IBH
L'appareil est dans le schéma de câblage de l'alternateur L'appareil est dans le schéma de câblage réchauffage entrée d'air (MLI A037)
LF AA WI
L'appareil est dans le schéma de câblage module fioul / air atomisation / injection d'eau (MLI A162)
LF-SR
L'appareil est dans le schéma de câblage du module de recirculation fioul (MLI 969C)
LO FG
L'appareil est dans le schéma de câblage module huile / gaz (MLI A160)
LOAD
L'appareil est dans le schéma de câblage du réducteur de puissance (MLI A012)
MIST
L'appareil est dans le plan d'arrangement du déshuileur (MLI A098)
OIL
L'appareil est dans le schéma de câblage module huile (MLI 0991 ou 401H)
STEAM
L'appareil est dans le schéma de câblage module d'injection vapeur (MLI A135)
TURB
L'appareil est dans le schéma de câblage turbine (MLI 401T)
VAN
L'appareil est dans le schéma de câblage module d'injection additive de vanadium (MLI E021)
WI
L'appareil est dans le schéma de câblage module d'injection d'eau (MLI A035) SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
4/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
SH
REV
5
F
TBFT-TMP-FR-GTE-0060 Rev : 001
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
5/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
6
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0425
20AA-1
0983
TURB
Electrovanne air atomisation pour la commande de VA18-1 Caractéristiques : Normal : 1 vers 3 ouvert ; 2 fermé | 0,035 kW | 125 VDC
0425
20AB-1
0922
ACCY
Electrovanne air atomisation suppresseur de démarrage Caractéristiques : Normal : 1 vers 3 ouvert ; 2 fermé | 0,035 kW | 125 VDC
0436
20BA-30
1605
ENCL-T
Electroaimant clapet de filtration entrée d'air compartiment auxiliaires Caractéristiques : 24 VDC
0436
20BA-31
1605
ENCL-T
Electroaimant clapet de filtration entrée d'air compartiment auxilaire Caractéristiques : 24 VDC
0436
20BT-30
1605
ENCL-T
Electroaimant clapet de filtration entrée d'air compartiment turbine Caractéristiques : 24 VDC
0436
20BT-40
1605
ENCL-T
Electroaimant clapet de filtration entrée d'air Caractéristiques : 24 VDC
0417
20CB-1
1071
TURB
Electrovanne commande vanne anti-pompage compresseur Caractéristiques : Normal : B vers C ouvert, A fermé | 0,04 kW | 125 VDC
0424
20CF-1
0601
ACCY
Embrayage électromagnetique pompe à fuel Caractéristiques : Normal : NO | 0,16 kW (max) | 125 VDC
0422
20FGC-1
0509
GAS
Electrovanne de déclenchement vanne de controle gaz (VGC-1) Caractéristiques : Normal : NO | 0,0156 kW | 125 VDC
0422
20FGS-1
0507
GAS
Electrovanne arrêt combustible gaz Caractéristiques : Normal : NO | 0,0156 kW | 125 VDC
0424
20FL-1
1019
ACCY
Electrovanne arrêt combustible liquide Caractéristiques : Normal : NO | 0,02 kW | 125 VDC
0494
20IA-11
E021
VAN
Electrovanne Caractéristiques : Normal : NC | 12 W | 125 VDC
0436
20JS-30
1659
ENCL-WI
0424
20PF-100
0961
TURB
0477
20PG-1
0991
Electroaimant clapet de filtration entrée d'air compartiment injection d'eau Caractéristiques : 24 VDC Electrovanne commande vanne multiport purge fuel liquide VP-1 et VP-2 Caractéristiques : Normal : A vers P ouvert. B fermé | 40 W | 125 VDC
GAS
Electrovanne de commande de la VA13-1 Caractéristiques : Normal : 1 vers 3 ouvert ; 2 fermé | 0,035 kW | 125 VDC Réglages : Installation d'un robinet-pointeau en amont de 20PG-1 pour régler le temps d'ouverture de VA13-1 à 30 secondes Electrovanne de commande de la VA13-2 Caractéristiques : Normal : 1 vers 3 ouvert ; 2 fermé | 0,035 kW | 125 VDC Réglages : Installation d'un robinet-pointeau en amont de 20PG-1 pour régler le temps d'ouverture de VA13-1 à 30 secondes
0477
20PG-2
0991
GAS
0477
20PL-1
918T
TURB
Electrovanne de commande de la VA19-1 Caractéristiques : Normal : 1 vers 3 ouvert ; 2 fermé | 0,035 kW | 125 VDC
0421
20TU-1
0605
ACCY
Electrovanne d'appoint / décharge du convertisseur de couple Caractéristiques : Normal : NC
0469
20TV-1
1019
ACCY
Electrovanne système déclenchement des aubes variables entrée compresseur (IGV) Caractéristiques : Normal : NO | 0,1 kW | 125 VDC
0442
20TW-1.
0953
TURB
Vanne motorisée lavage compresseur off-Line Caractéristiques : Normal : FC | 0,092 kW | 50 Hz | 115 VAC
0442
20TW-3.
0953
TURB
Vanne motorisée lavage compresseur on-Line Caractéristiques : Normal : FC | 0,092 kW | 50 Hz | 115 VAC
0422
20VG-1
0991
GAS
Electrovanne évent combustible gaz Caractéristiques : Normal : NO | 0,009 kW | 125 VDC
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
6/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
7
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation Electrovanne de mise à l'évent de l'espace inter-vannes VA13-1 et VA13-2 Caractéristiques : Normal : NO | 0,125 kW | 125 VDC
0477
20VG-2
0991
GAS
0436
20VG--30
1605
ENCL-T
Electro-aimant clapet de filtration entrée d'air compartiment puissance Caractéristiques : 24 VDC
0436
20VL-30
1658
ENCL-T
Electroaimant clapet de filtration entrée d'air compartiment gaz Caractéristiques : 24 VDC
0462
20WN-1
A035
WI
Electrovanne arrêt injection d'eau Caractéristiques : Normal : NO | 125 VDC
0462
20WN-2
A035
WI
Electrovanne d'arrêt injection d'eau (partie de VS2-2) Caractéristiques : Normal : NO | 125 VDC
0425
23AB-1
1047
ACCY
Résistance anti-condensation du moteur 88AB-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0436
23BA-1
1605
ENCL-T
Résistance anti-condensation du moteur 88BA-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0436
23BA-2
1605
ENCL-T
Résistance anti-condensation du moteur 88BA-2 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0436
23BT-1
1605
ENCL-T
Résistance anti-condensation du moteur 88BT-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0436
23BT-2
1605
ENCL-T
Résistance anti-condensation du moteur 88BT-2 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0421
23CR-1
0603
ACCY
Résistance anti-condensation du moteur 88CR-1 Caractéristiques : 50 Hz | 0,18 kW | 240 VAC
0421
23CR-2
0603
ACCY
Résistance anti-condensation du moteur 88CR-1 Caractéristiques : 50 Hz | 0,18 kW | 240 VAC
0421
23CR-3
0603
ACCY
Résistance anti-condensation du moteur 88CR-1 Caractéristiques : 50 Hz | 0,18 kW | 240 VAC
0436
23HA-1
1113
ENCL-T
Chauffage compartiment auxiliaires Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
0436
23HA-11
1195
ENCL-G
Chauffage compartiment gaz Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
0436
23HA-12
1195
ENCL-G
Chauffage entrée d'air du compartiment gaz Caractéristiques : 50 Hz | 15 kW | 415 VAC
0436
23HA-2
1113
ENCL-T
Chauffage compartiment auxiliaires Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
0436
23HA-3
1113
ENCL-T
Chauffage compartiment auxiliaires Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
0436
23HA-4
1113
ENCL-T
Chauffage compartiment auxiliaires Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
0434
23HQ-1
0628
ACCY
0436
23HT-1
1113
ENCL-T
Chauffage compartiment turbine Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
0436
23HT-2
1113
ENCL-T
Chauffage compartiment turbine Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
0436
23HT-3
1113
ENCL-T
Chauffage compartiment turbine Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
0436
23HT-4
1113
ENCL-T
Chauffage compartiment turbine Caractéristiques : 50 Hz | 3,9 kW | 415 VAC
Résistance anti-condensation du moteur 88HQ-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
7/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
8
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0416
23QA-1
1006
ACCY
Résistance anti-condensation du moteur 88QA-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0416
23QT-1
0938
ACCY
Thermoplongeur réservoir d'huile Caractéristiques : 50 Hz | 10,2 kW | 415 VAC
0416
23QV-1
A098
MIST
Résistance anti-condensation du moteur 88QV-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0416
23QV-2
A098
MIST
Résistance anti-condensation du moteur 88QV-2 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0421
23TG-1
0603
ACCY
Résistance anti-condensation du moteur 88TG-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0417
23TK-1
1233
ACCY
Résistance anti-condensation du moteur 88TK-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0417
23TK-2
1233
ACCY
Résistance anti-condensation du moteur 88TK-2 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0436
23VG-1
1605
ENCL-T
Résistance anti-condensation du moteur 88VG-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0436
23VG-2
1605
ENCL-T
Résistance anti-condensation du moteur 88VG-2 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
0462
23WN-1
A035
WI
0471
27TF-1
A040
FILT
Report d'alarme général filtre à air
0415
28FD-10
1121
TURB
Détecteur de flamme chambre de combustion n°10
0415
28FD-11
1121
TURB
Détecteur de flamme chambre de combustion n°11
0415
28FD-4
1121
TURB
Détecteur de flamme chambre de combustion n°4
0415
28FD-5
1121
TURB
Détecteur de flamme chambre de combustion n°5
0415
30SG-1
1213
TURB
Relais alarme Caractéristiques : Normal : NO
0436
33BA-1
1605
ENCL-T
Fin de course clapet anti-retour de la ventilation du compartiment auxilaire Caractéristiques : Normal : NO
0436
33BA-2
1605
ENCL-T
Fin de course clapet anti-retour de la ventilation du compartiment auxiliaire Caractéristiques : Normal : NO
0436
33BT-1
1605
ENCL-T
Fin de course clapet anti-retour de la ventilation du compartiment TG Caractéristiques : Normal : NO Réglages : Volet fermé : fin de course actionné, contact fermé
0436
33BT-2
1605
ENCL-T
Fin de course clapet anti-retour de la ventilation du compartiment TG Caractéristiques : Normal : NO Réglages : Volet fermé : fin de course actionné, contact fermé
0417
33CB-1
1022
TURB
Fin de course vanne anti-pompage (11 ème étage) Caractéristiques : Normal : NO Réglages : Vanne ouverte : fin de course actionné, contact fermé
0417
33CB-2
1022
TURB
Fin de course vanne anti-pompage (11 ème étage) Caractéristiques : Normal : NO Réglages : Vanne ouverte : fin de course actionné, contact fermé
0417
33CB-3
1022
TURB
Fin de course vanne anti-pompage (11 ème étage) Caractéristiques : Normal : NO Réglages : Vanne ouverte : fin de course actionné, contact fermé
0417
33CB-4
1022
TURB
Fin de course vanne anti-pompage (11 ème étage) Caractéristiques : Normal : NO Réglages : Vanne ouverte : fin de course actionné, contact fermé
Résistance anti-condensation moteur 88WN-1 Caractéristiques : 50 Hz | 0,05 kW | 240 VAC
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
8/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
9
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0436
33DT-1
1605
ENCL-T
Fin de course porte du compartiment auxiliaire Caractéristiques : Normal : NO Réglages : Porte fermée : fin de course actionné, contact fermé
0436
33DT-11
1658
ENCL-T
Fin de course porte du compartiment gaz Caractéristiques : Normal : NO Réglages : Porte fermée : fin de course actionné, contact fermé
0436
33DT-12
1658
ENCL-G
Fin de course porte du compartiment gaz Caractéristiques : Normal : NO Réglages : Porte fermée : fin de course actionné, contact fermé
0436
33DT-13
1658
ENCL-G
Fin de course porte du compartiment gaz Caractéristiques : Normal : NO Réglages : Porte fermée : fin de course actionné, contact fermé
0436
33DT-14
1658
ENCL-G
Fin de course porte du compartiment gaz Caractéristiques : Normal : NO Réglages : Porte fermée : fin de course actionné, contact fermé
0436
33DT-2
1605
ENCL-T
Fin de course porte du compartiment auxiliaire Caractéristiques : Normal : NO Réglages : Porte fermée : fin de course actionné, contact fermé
0436
33DT-3
1605
ENCL-T
Fin de course porte de l'enceinte TG Caractéristiques : Normal : NO Réglages : Porte fermée : fin de course actionné, contact fermé
0436
33DT-4
1605
ENCL-T
Fin de course porte de l'enceinte TG Caractéristiques : Normal : NO Réglages : Porte fermée : fin de course actionné, contact fermé
0424
33FL-1
0511
ACCY
Fin de course vanne arrêt combustible liquide Caractéristiques : Normal : NO Réglages : Vanne fermée : fin de course actionné, contact fermé
0436
33JS-1
1659
ENCL-WI
Fin de course clapet anti-retour de la ventilation de l'enceinte du skid injection d'eau Caractéristiques : Normal : NO Réglages : Volet fermé : fin de course actionné, contact fermé
0436
33JS-2
1659
ENCL-WI
Fin de course clapet anti-retour de la ventilation de l'enceinte du skid injection d'eau Caractéristiques : Normal : NO Réglages : Volet fermé : fin de course actionné, contact fermé
0424
33PF-1
0961
TURB
Fin de course sur vanne multiport VP-1 Caractéristiques : Normal : NO Réglages : Vanne fermée : fin de course actionné, contact fermé
0424
33PF-2
0961
TURB
Fin de course sur vanne multiport VP-2 Caractéristiques : Normal : NO Réglages : Vanne fermée : fin de course actionné, contact fermé
0477
33PG-1
0991
GAS
Fin de course position fermeture de VA13-1 Caractéristiques : Normal : NO Réglages : Vanne fermée : fin de course actionné, contact fermé
0477
33PG-2
0991
GAS
Fin de course position ouverture de VA13-1 Caractéristiques : Normal : NO Réglages : Vanne ouverte : fin de course actionné, contact fermé
0477
33PG-3
0991
GAS
Fin de course position fermeture de VA13-2 Caractéristiques : Normal : NO Réglages : Vanne fermée : fin de course actionné, contact fermé
0477
33PG-4
0991
GAS
Fin de course position ouverture de VA13-2 Caractéristiques : Normal : NO Réglages : Vanne ouverte : fin de course actionné, contact fermé
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
9/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
10
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0421
33TC-1
0605
ACCY
Fin de course position électrovanne convertisseur de couple Caractéristiques : Normal : NO Réglages : 20TU-1 au repos : fin de course actionné, contact fermé
0421
33TM-5
0605
ACCY
Fin de course couple bas convertisseur de couple Caractéristiques : Normal : NO, vanne fermée pour IGV fermé ou couple max Réglages : Réglé à 2 tr de crémaillère (échelle 0-31 tr de crémaillère)
0421
33TM-6
0605
ACCY
Fin de course couple haut convertisseur de couple Caractéristiques : Normal : NO, vanne fermée pour IGV fermé ou couple max Réglages : Réglé à 28 tr de crémaillère (échelle 0-31 tr de crémaillère)
0436
33VG-1
1605
ENCL-T
Fin de course clapet anti-retour de la ventilation du compartiment puissance Caractéristiques : Normal : NO Réglages : Volet fermé : fin de course actionné, contact fermé
0422
33VG-11
0991
GAS
0436
33VG-2
1605
ENCL-T
Fin de course clapet anti-retour de la ventilation du compartiment puissance Caractéristiques : Normal : NO Réglages : Volet fermé : fin de course actionné, contact fermé
0436
33VL-1
1658
ENCL-G
Fin de course clapet anti-retour de la ventilation du compartiment gaz Caractéristiques : Normal : NO Réglages : Volet fermé : fin de course actionné, contact fermé
0436
33VL-2
1658
ENCL-G
Fin de course clapet anti-retour de la ventilation du compartiment gaz Caractéristiques : Normal : NO Réglages : Volet fermé : fin de course actionné, contact fermé
0462
33WN-1
A035
WI
Fin de course vanne de contrôle (partie de VC4-1) Caractéristiques : Normal : NO Réglages : Vanne complètement ouverte : fin de course activé, contact fermé
0462
33WN-2
A035
WI
Fin de course vanne de contrôle (partie de VC4-1) Caractéristiques : Normal : NO Réglages : Vanne complètement fermée : fin de course actionné, contact fermé
0462
33WN-3
A035
WI
Fin de course vanne stop (partie de VS2-2) Caractéristiques : Normal : NO Réglages : Vanne complètement ouverte : fin de course activé, contact fermé
0462
33WN-4
A035
WI
Fin de course vanne stop (partie de VS2-2) Caractéristiques : Normal : NO Réglages : Vanne complètement fermée : fin de course activé, contact fermé
0415
39V-1A
1218
TURB
Capteur de vibration Caractéristiques : Pour 25,4 mm/s, 150 ± 4,5 mV crête
0415
39V-1B
1218
TURB
Capteur de vibration Caractéristiques : Pour 25,4 mm/s, 150 ± 4,5 mV crête
0415
39V-2A
1218
TURB
Capteur de vibration Caractéristiques : Pour 25,4 mm/s, 150 ± 4,5 mV crête
0415
39V-3A
1218
TURB
Capteur de vibration Caractéristiques : Pour 25,4 mm/s, 150 ± 4,5 mV crête
0415
39V-3B
1218
TURB
Capteur de vibration Caractéristiques : Pour 25,4 mm/s, 150 ± 4,5 mV crête
0415
39VS-11
235A
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0415
39VS-12
235A
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
Fin de course électrovanne 20VG-1 Caractéristiques : Normal : NC Réglages : Vanne ouverte : fin de course actionné, contact fermé
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
10/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
11
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0415
39VS-21
235B
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0415
39VS-22
235B
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0415
39VS-23
235B
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0415
39VS-24
235B
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0415
39VS-31
235C
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0415
39VS-32
235C
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0426
43CP-1
1113
ENCL-T
Bris de glace porte d'accès compartiment auxiliaire Caractéristiques : Normal : NO
0426
43CP-2
1113
ENCL-T
Bris de glace porte d'accès compartiment TG Caractéristiques : Normal : NO
0426
43CP-3
1113
ENCL-T
Bris de glace porte d'accès compartiment auxiliaire Caractéristiques : Normal : NO
0426
43CP-4
1113
ENCL-T
Bris de glace porte d'accès compartiment TG Caractéristiques : Normal : NO
0426
43CP-5
1113
ENCL-T
Bris de glace porte d'accès compartiment puissance Caractéristiques : Normal : NO
0426
43CP-6
1195
ENCL-G
Bris de glace porte d'accès compartiment gaz Caractéristiques : Normal : NO
0426
43CP-7
1195
ENCL-G
Bris de glace porte d'accès compartiment gaz Caractéristiques : Normal : NO
0442
43TW-1/PB
1105
TURB
0426
45FA-10A
1113
ENCL-T
Détecteur thermostatique incendie compartiment auxiliaires Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-10B
1113
ENCL-T
Détecteur thermostatique incendie compartiment auxiliaires Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-11A
1113
ENCL-T
Détecteur thermostatique incendie compartiment auxiliaires Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-11B
1113
ENCL-T
Détecteur thermostatique incendie compartiment auxiliaires Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-12A
1113
ENCL-T
Détecteur thermostatique incendie compartiment auxiliaires Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-12B
1113
ENCL-T
Détecteur thermostatique incendie compartiment auxiliaires Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
Bouton-poussoir lavage off-Line Caractéristiques : Normal : NO
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
11/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
12
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0426
45FA-13A
1113
ENCL-T
Détecteur thermostatique incendie compartiment auxiliaires Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-13B
1113
ENCL-T
Détecteur thermostatique incendie compartiment auxiliaires Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-1A
1104
ACCY
Détecteur thermostatique incendie compartiment auxiliaire Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-1B
1104
ACCY
Détecteur thermostatique incendie compartiment auxiliaire Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-2A
1104
ACCY
Détecteur thermostatique incendie compartiment auxiliaire Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-2B
1104
ACCY
Détecteur thermostatique incendie compartiment auxiliaire Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-6A
A116
GAS
Détecteur thermostatique incendie compartiment gaz Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-6B
1195
GAS
Détecteur thermostatique incendie compartiment gaz Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-7A
A116
GAS
Détecteur thermostatique incendie compartiment gaz Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FA-7B
A116
GAS
Détecteur thermostatique incendie compartiment gaz Caractéristiques : Normal : NO Réglages : Fermé : 163 ± 14°C
0426
45FT-1A
1103
TURB
Détecteur thermostatique incendie compartiment TG Caractéristiques : Normal : NO Réglages : Fermé : 316 ± 14°C
0426
45FT-1B
1103
TURB
Détecteur thermostatique incendie compartiment TG Caractéristiques : Normal : NO Réglages : Fermé : 316 ± 14°C
0426
45FT-2A
1154
TURB
Détecteur thermostatique incendie compartiment TG Caractéristiques : Normal : NO Réglages : Fermé : 316 ± 14°C
0426
45FT-2B
1154
TURB
Détecteur thermostatique incendie compartiment TG Caractéristiques : Normal : NO Réglages : Fermé : 316 ± 14°C
0426
45FT-3A
1154
TURB
Détecteur thermostatique incendie compartiment TG Caractéristiques : Normal : NO Réglages : Fermé : 316 ± 14°C
0426
45FT-3B
1154
TURB
Détecteur thermostatique incendie compartiment TG Caractéristiques : Normal : NO Réglages : Fermé : 316 ± 14°C
0426
45FT-8A
1160
TURB
Détecteur thermostatique incendie compartiment puissance Caractéristiques : Normal : NO Réglages : Fermé : 385 ± 14°C
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
12/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
13
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0426
45FT-8B
1160
TURB
Détecteur thermostatique incendie compartiment puissance Caractéristiques : Normal : NO Réglages : Fermé : 385 ± 14°C
0426
45FT-9A
1160
TURB
Détecteur thermostatique incendie compartiment puissance Caractéristiques : Normal : NO Réglages : Fermé : 316 ± 14°C
0426
45FT-9B
1160
TURB
Détecteur thermostatique incendie compartiment puissance Caractéristiques : Normal : NO Réglages : Fermé : 316 ± 14°C
0474
45HA-1
1153
ACCY
Détecteur gaz compartment auxiliaire Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HA-10
1113
ENCL-T
Détecteur gaz Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HA-11
1113
ENCL-T
Détecteur gaz Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HA-12
1113
ENCL-T
Détecteur gaz Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HA-2
1153
ACCY
Détecteur gaz compartiment auxiliaire Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HA-3
1153
ACCY
Détecteur gaz compartiment auxiliaire Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HA-4
1195
ENCL-G
Détecteur gaz dans gaine de ventilation compartiment gaz Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HA-5
1195
ENCL-G
Détecteur gaz dans gaine de ventilation compartiment gaz Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HA-6
1195
ENCL-G
Détecteur gaz dans gaine de ventilation compartiment gaz Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HT-1
1154
TURB
Détecteur gaz compartiment turbine Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HT-2
1154
TURB
Détecteur gaz compartiment turbine Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HT-3
1154
TURB
Détecteur gaz compartiment turbine Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HT-4
1113
ENCL-T
Détecteur gaz dans gaine de ventilation compartiment turbine Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HT-5
1113
ENCL-T
Détecteur gaz dans gaine de ventilation compartiment turbine Caractéristiques : Gamme de mesure : 0 à 20% LIE
0474
45HT-6
1113
ENCL-T
Détecteur gaz dans gaine de ventilation compartiment turbine Caractéristiques : Gamme de mesure : 0 à 20% LIE
0436
49HA-12
1658
ENCL-G
Thermostat de sécurité chauffage compartiment gaz Caractéristiques : Normal : NO | Fermé à 100°C
0426
5E-1
1104
ACCY
Bouton d'arrêt d'urgence compartiment auxiliaire Caractéristiques : Normal : NC
0426
5E-2
1104
ACCY
Bouton d'arrêt d'urgence compartiment auxiliaire Caractéristiques : Normal : NC
VAN
Pressostat Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 3 ± 0,25 bar
0494
63AF-11
E021
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
13/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
14
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0436
63BA-30
1605
ENCL-T
Pressostat différentiel entrée d'air compartiment auxiliaire Réglages : Fermé à 1 ± 0,1 mbar
0436
63BA-31
1605
ENCL-T
Pressostat différentiel entrée d'air compartiment auxiliaire Réglages : Fermé à 1 ± 0,1 mbar
0436
63BT-30
1605
ENCL-T
Pressostat différentiel entrée d'air Réglages : Fermé à 1 ± 0,1 mbar
0436
63BT-40
1605
ENCL-T
Pressostat différentiel entrée d'air Réglages : Fermé à 1 ± 0,1 mbar
0471
63CA-1
A040
FILT
Pressostat pression basse entrée air comprimé filtre à air TG Caractéristiques : Normal : NC Réglages : Ouvert à la descente à : 5,5 ± 0,5 bar | Non réglable : fermé à la montée à : 6 ± 0,5 bar
0471
63CS-2A
A040
FILT
Pressostat différentiel admission d'air TG Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 23 ± 0,5 mbar
FILT
Pressostat différentiel admission d'air TG Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 23 ± 0,5 mbar
GAS
Manostat Caractéristiques : Normal : NC Réglages : Non réglable : ouvert à la montée à : 2,41 ± 0,05 bar | Fermé à la descente à : 1,03 ± 0,05 bar
GAS
Manostat Caractéristiques : Normal : NC Réglages : Non réglable : ouvert à la montée à : 2,41 ± 0,05 bar | Fermé à la descente à : 1,03 ± 0,05 bar
ACCY
Manostat différentiel filtre alimentation hydraulique Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 4,13 ± 0,2 bar | Non réglable : fermé à la descente à : 2,75 ± 1,03 bar Manostat de pression basse alimentation huile HP Caractéristiques : Normal : NO Réglages : Ouvert à la descente à : 93 ± 1,7 bar | Non réglable : fermé à la montée à : 100 ± 3,1 bar
0471
0422
0422
0434
63CS-2B
63FG-1
63FG-2
63HF-1
A040
0991
0991
0926
0434
63HQ-1
0926
ACCY
0436
63JS-30
1659
ENCL-WI
0424
63LF-3
0992
ACCY
Pressostat différentiel entrée d'air compartiment injection d'eau Réglages : Fermé à 1 ± 0,1 mbar Manostat de pression différentielle filtre fuel principal Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 1,3 ± 0,07 bar
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
14/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
0477
0477
0416
DWG NO
137A3171
Appareils
63PG-1
63PL-21
63QA-2
MLI
0991
918T
0926
SH
REV
15
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Schéma câblage
Désignation
GAS
Manostat sur pression dans l'espace inter vannes VA13-1 et VA13-2 Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 3,45 ± 0,14 bar | Non réglable : fermé à la descente à : 3,17 ± 0,21 bar
TURB
Manostat sur air de balayage des injecteurs de combustible liquide Caractéristiques : Normal : NO Réglages : Non réglable : ouvert à la descente à : 4,6 ± 0,3 bar | Fermé à la montée à : 6 ± 0,3 bar
ACCY
Manostat pression huile de lubrification Caractéristiques : Normal : NO Réglages : Ouvert à la descente à : 2,8 ± 0,07 bar | Non réglable : fermé à la montée à : 3,1 ± 0,14 bar
0416
63QQ-1
0926
ACCY
Manostat pression différentielle filtre huile principal Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 1,03 ± 0,068 bar | Non réglable : fermé à la descente à : 0,9 ± 0,2 bar
0416
63QQ-10
A098
MIST
Alarme haute pression différentielle filtre de l'éliminateur de brouillard d'huile Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 80 ± 3 mbar
0416
63QQ-8
0916
ACCY
Manostat pression différentielle filtre convertisseur de couple Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 1,5 ± 0,2 bar
0416
63QT-2A
ALT.
GENE
Manostat pression huile de lubrification palier #2 alternateur Caractéristiques : Normal : NO Réglages : Ouvert à la descente à : 0,55 ± 0,021 bar | Non réglable : fermé à la montée à : 0,62 ± 0,035 bar
0417
63TK-1
A053
ACCY
Manostat de contrôle de ventilation du corps turbine Caractéristiques : Normal : NO Réglages : Fermé au dessus de 381 ± 19 mm H2O
0417
63TK-2
A053
ACCY
Manostat de contrôle de ventilation du corps turbine Caractéristiques : Normal : NO Réglages : Fermé au dessus de 381 ± 19 mm H2O
0436
63VG-30
1605
ENCL-T
Pressostat différentiel, entrée d'air compartiment puissance Réglages : Fermé à 1 ± 0,1 mbar
0436
63VL-30
1658
ENCL-T
Pressostat différentiel entrée d'air compartiment gaz Réglages : Fermé à 1 ± 0,1 mbar
0462
63WN-1
A035
WI
Pressostat différentiel entrée pompe injection d'eau Caractéristiques : Normal : NC Réglages : Ouvert à la descente à : -0,270 ± 0,01 bar
0462
63WN-2
A035
WI
Pressostat sortie pompe injection d'eau Caractéristiques : Normal : NO Réglages : Ouvert à la descente à : 25 bar
0462
63WN-3
A035
WI
Pressostat sortie pompe injection d'eau Caractéristiques : Normal : NC Réglages : Ouvert à la montée à : 1,03 ± 0,1 bar
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
15/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
16
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0424
65FP
0533
ACCY
Servovalve (bypass) pompe à fuel
0422
65GC-1
0509
GAS
Servovalve contrôle gaz (VGC-1)
0494
71FA-11
E021
VAN
Controleur de niveau Caractéristiques : Normal : NO Réglages : Ouvert à niveau bas
0494
71FA-12
E021
VAN
Contrôleur de niveau Caractéristiques : Normal : NO Réglages : Ouvert à niveau bas
0442
71FF-4
969L
TURB
Détecteur de niveau Caractéristiques : Normal : NC Réglages : Ouverture au niveau haut
0442
71FF-5
969L
TURB
Détecteur de niveau Caractéristiques : Normal : NC Réglages : Ouverture au niveau très haut
0442
71FF-6
969L
TURB
Détecteur de niveau Caractéristiques : Normal : NC Réglages : Ouverture au niveau très haut
0424
77FD-1
0910
ACCY
Capteur de vitesse magnétique diviseur de débit Réglages : Entrefer : 0,23 ± 0,025 mm
0424
77FD-2
0910
ACCY
Capteur de vitesse magnétique diviseur de débit Réglages : Entrefer : 0,23 ± 0,025 mm
0424
77FD-3
0910
ACCY
Capteur de vitesse magnétique diviseur de débit Réglages : Entrefer : 0,23 ± 0,025 mm
0415
77HT-1
0546
TURB
Capteur de vitesse Réglages : Entrefer : 1,27 ± 0,127 mm
0415
77HT-2
0546
TURB
Capteur de vitesse Réglages : Entrefer : 1,27 ± 0,127 mm
0415
77HT-3
0546
TURB
Capteur de vitesse Réglages : Entrefer : 1,27 ± 0,127 mm
0415
77NH-1
0546
TURB
Capteur de vitesse Réglages : Entrefer : 1,27 ± 0,127 mm
0415
77NH-2
0546
TURB
Capteur de vitesse Réglages : Entrefer : 1,27 ± 0,127 mm
0415
77NH-3
0546
TURB
Capteur de vitesse Réglages : Entrefer : 1,27 ± 0,127 mm
0415
77RP-11
235A
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0425
88AB-1
1047
ACCY
Moteur compresseur de démarrage air atomisation Caractéristiques : 15 kW | 2925 tr/min | 415 VAC | 50 Hz
0436
88BA-1
1605
ENCL-T
Moteur électrique ventilateur refroidissement compartiment TG Caractéristiques : 15 kW | - tr/min | 415 VAC | 50 Hz
0436
88BA-2
1605
ENCL-T
Moteur électrique ventilateur refroidissement compartiment TG Caractéristiques : 15 kW | - tr/min | 415 VAC | 50 Hz
0436
88BT-1
1605
ENCL-T
Moteur électrique ventilateur refroidissement compartiment TG Caractéristiques : 37 kW | - tr/min | 415 VAC | 50 Hz
0436
88BT-2
1605
ENCL-T
Moteur électrique ventilateur refroidissement compartiment TG Caractéristiques : 37 kW | - tr/min | 415 VAC | 50 Hz
0421
88CR-1
0603
ACCY
Moteur électrique de lancement Caractéristiques : 1000 kW | 2975 tr/min | 6,6 kV | 50 Hz
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
16/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
17
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0494
88FA-10
E021
VAN
Moteur électrique Caractéristiques : 0,46 kW | 1500 tr/min | 240 VAC | 50 Hz
0494
88FA-11
E021
VAN
Moteur électrique Caractéristiques : 0,37 kW | 1500 tr/min | 415 VAC | 50 Hz
0494
88FA-12
E021
VAN
Moteur électrique Caractéristiques : 0,37 kW | 1500 tr/min | 415 VAC | 50 Hz
0424
88FM
0613
ACCY
Moteur électrique démarrage répartiteur de débit combustible liquide Caractéristiques : 0,37 kW | 1400 tr/min | 415 VAC | 50 Hz
0434
88HQ-1
0628
ACCY
Moto-pompe auxiliaire huile HP Caractéristiques : 15 kW | 1450 tr/min | 415 VAC | 50 Hz
0436
88JS-1
1659
ENCL-WI
Moteur électrique ventilation enceinte acoustique skid injection d'eau Caractéristiques : 0,37 kW | - tr/min | 415 VAC | 50 Hz
0436
88JS-2
1659
ENCL-WI
Moteur électrique ventilation enceinte acoustique skid injection d'eau Caractéristiques : 0,37 kW | - tr/min | 415 VAC | 50 Hz
0416
88QA-1
1006
ACCY
0424
88QAOB
0611
OTHER
0416
88QE-1
1007
ACCY
0424
88QEOB
0611
OTHER
0416
88QV-1
A098
MIST
Moteur électrique de l'éliminateur de brouillard Caractéristiques : 18,5 kW | 3000 tr/min | 415 VAC | 50 Hz
0416
88QV-2
A098
MIST
Moteur électrique de l'éliminateur de brouillard Caractéristiques : 18,5 kW | 3000 tr/min | 415 VAC | 50 Hz
0421
88TG-1
0538
ACCY
Moteur électrique de virage Caractéristiques : 30 kW | 725 tr/min | 415 VAC | 50 Hz
0417
88TK-1
1233
ACCY
Ventilateur centrifuge + moteur électrique groupe moto ventilateur refroidissement corps TG Caractéristiques : 45 kW | 2900 tr/min | 415 VAC | 50 Hz
0417
88TK-2
1233
ACCY
Ventilateur centrifuge + moteur électrique groupe moto ventilateur refroidissement corps TG Caractéristiques : 45 kW | 2900 tr/min | 415 VAC | 50 Hz
0421
88TM-1
0605
ACCY
Moteur convertisseur de couple Caractéristiques : 1,5 kW | 3000 tr/min | 415 VAC | 50 Hz
0436
88VG-1
1605
ENCL-T
Moteur électrique ventilateur refroidissement compartiment puissance Caractéristiques : 11 kW | - tr/min | 415 VAC | 50 Hz
0436
88VG-2
1605
ENCL-T
Moteur électrique ventilateur refroidissement compartiment puissance Caractéristiques : 11 kW | - tr/min | 415 VAC | 50 Hz
0436
88VL-1
1658
ENCL-G
Moteur électrique ventilateur compartiment gaz Caractéristiques : 4 kW | - tr/min | 415 VAC | 50 Hz
0436
88VL-2
1658
ENCL-G
Moteur électrique ventilateur compartiment gaz Caractéristiques : 4 kW | - tr/min | 415 VAC | 50 Hz
0462
88WN-1
A035
WI
0422
90SR-1
0507
GAS
0469
90TV-1
0548
TURB
Moteur électrique de la pompe à huile auxiliaire Caractéristiques : 90 kW | 3000 tr/min | 415 VAC | 50 Hz Moteur pompe de lubrification principale de la pompe Warren fuel liquide Caractéristiques : 0,75 kW | 415 VAC Moteur électrique de la pompe à huile de secours Caractéristiques : 7,5 kW | 1750 tr/min | 125 VDC Moteur pompe de lubrification d'urgence de la pompe Warren fuel liquide Caractéristiques : 0,75 kW | 125 VDC
Moteur de la pompe à injection d'eau Caractéristiques : 55 kW | 3000 tr/min | 415 VAC | 50 Hz Servovalve arrêt et régulation gaz Servovalve actionneur IGV compresseur
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
17/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
MLI
SH
REV
18
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Schéma câblage
Désignation Régulateur électro-pneumatique Réglages : 04 ± 0,20 mA pour 0 ± 0,01 bar 20 ± 0,20 mA pour 3,1 ± 0,1 bar
0462
90WN-1
A035
WI
0436
95BA-1
1605
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation Réglages : 16 ± 1 mA lorsque le ventilateur fonctionne
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation compartiment turbine Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation compartiment turbine Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation compartiment turbine Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation compartiment turbine Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation compartiment turbine Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
0436
0436
0436
0436
0436
0436
0436
0436
0436
0436
95BA-2
95BA-3
95BA-4
95BA-5
95BA-6
95BT-1
95BT-2
95BT-3
95BT-4
95BT-5
1605
1605
1605
1605
1605
1605
1605
1605
1605
1605
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
18/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
MLI
SH
REV
19
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Schéma câblage
Désignation Contrôleur de débit d'air (anémomètre) de ventilation compartiment turbine Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
0436
95BT-6
1605
ENCL-T
0415
95SG-13
1213
TURB
Transformateur pour bougie d'allumage 95SP-13 Caractéristiques : 0,15 kVA | 115 VAC (230 VAC) | 15 kV | 50 Hz
0415
95SG-14
1213
TURB
Transformateur pour bougie d'allumage 95SP-14 Caractéristiques : 0,15 kVA | 115 VAC (230 VAC) | 15 kV | 50 Hz
0415
95SP-13
1214
TURB
Bougie d'allumage chambre de combustion n°13
0415
95SP-14
1214
TURB
Bougie d'allumage chambre de combustion n°14
0436
0436
0436
0425
0492
95VL-1
95VL-2
95VL-3
96AD-1
96AP-1A
1658
1658
1658
0926
0559
ENCL-G
Contrôleur de débit d'air (anémomètre) de ventilation compartiment gaz Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-G
Contrôleur de débit d'air (anémomètre) de ventilation compartiment gaz Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ENCL-T
Contrôleur de débit d'air (anémomètre) de ventilation compartiment gaz Caractéristiques : 4 - 20 mA pour 0,5 - 30 m/s Réglages : ventilateur à l'arrêt sans débit d'air : 4 -0/+1 mA ventilateur en service et portes fermées : x1 mA, régler la constante du speedtronic à une valeur équivalente à { [60% x (x1 - 4) ] + 4 mA }
ACCY
Transmetteur de la pression différentielle du compresseur principal d'air d'atomisation Réglages : 4 ± 0,02 mA pour 0 bar 20 ± 0,1 mA pour 6 bar
ACCY
Transmetteur de pression Réglages : 04 ± 0,02 mA pour 0,745 bar abs 20 ± 0,10 mA pour 1,250 bar abs
0492
96AP-1B
0559
ACCY
Transmetteur de pression Réglages : 04 ± 0,02 mA pour 0,745 bar abs 20 ± 0,10 mA pour 1,250 bar abs
0492
96AP-1C
0559
ACCY
Transmetteur de pression Réglages : 04 ± 0,02 mA pour 0,745 bar abs 20 ± 0,10 mA pour 1,250 bar abs
0492
96BD-1
0559
ACCY
Transmetteur de pression Réglages : 04 ± 0,02 mA pour 0,000 bar 20 ± 0,10 mA pour 0,345 bar
0417
96CD-1A
0557
ACCY
Transmetteur de pression sortie compresseur Réglages : 04 ± 0,05 mA pour 0 bar 20 ± 0,05 mA pour 21 bar
ACCY
Transmetteur de pression sortie compresseur Réglages : 04 ± 0,05 mA pour 0 bar 20 ± 0,05 mA pour 21 bar
0417
96CD-1B
0557
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
19/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
0417
DWG NO
137A3171
Appareils
96CD-1C
MLI
0557
SH
REV
20
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Schéma câblage
Désignation
ACCY
Transmetteur de pression sortie compresseur Réglages : 04 ± 0,05 mA pour 0 bar 20 ± 0,05 mA pour 21 bar
0492
96CS-1
0559
ACCY
Transmetteur de pression Réglages : 04 ± 0,02 mA pour 0 mbar 20 ± 0,10 mA pour 27,4 mbar
0471
96CS-3
A040
FILT
Transmetteur de pression différentielle admission d'air TG Réglages : 04 ± 0,05 mA pour 0 mbar 20 ± 0,05 mA pour 63 mbar
0422
96FG-1
0991
GAS
Transmetteur de pression entrée module gaz Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 34,5 bar
0422
96FG-2A
0991
GAS
Transmetteur de pression gaz inter-vanne Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 34,5 bar
0422
96FG-2B
0991
GAS
Transmetteur de pression gaz inter-vanne Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 34,5 bar
GAS
Transmetteur de pression gaz inter-vanne Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 34,5 bar
ACCY
Transmetteur de pression entrée module fuel Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 10 bar
0422
0424
96FG-2C
96FL-2A
0991
0992
0424
96FL-2B
0992
ACCY
Transmetteur de pression entrée module fuel Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 10 bar
0424
96FP-1
0992
ACCY
Transmetteur de position linéaire différentiel (LVDT) vanne contrôle liquid fuel (VC3) Réglages : 0,7 ± 0.01 VAC for 0 mm 3,5 ± 0.01 VAC for 20,5 mm
0424
96FP-2
0992
ACCY
Transmetteur de position linéaire différentiel (LVDT) vanne contrôle fuel (VC3) Réglages : 0,7 ± 0.01 VAC for 0 mm 3,5 ± 0.01 VAC for 20,5 mm
0422
96GC-1,2
0509
GAS
Transmetteur de position linéaire différentiel (LVDT) vanne contrôle gaz (VGC-1) Réglages : 0,7 ± 0,01 VAC pour 0 mm
0416
96QA-2
0926
ACCY
Transmetteur de pression huile de lubrification avant VPR-2 Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 7 bar
0416
96QL-1
1038
ACCY
Transmetteur de niveau de la cuve à huile Réglages : 4 ± 0,05 mA pour 456 mm 20 ± 0,1 mA pour 246 mm
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
20/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
0416
0416
DWG NO
137A3171
Appareils
96QT-2B
96QV-1
MLI
ALT.
A098
SH
REV
21
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Schéma câblage
Désignation
GENE
Transmetteur pression huile de graissage palier #2 alternateur Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 1,72 bar
MIST
Transmetteur pression d'air dans la cuve Réglages : 4 ± 0,05 mA pour 0 bar 20 ± 0,1 mA pour 0,025 bar
0471
96RH
A040
FILT
Transmetteur de point de rosée et de température Réglages : Sortie 1 : 04 ± 0,05 mA pour -50°C 20 ± 0,05 mA pour +50°C Sortie 2 : 04 ± 0,05 mA pour 0% HR 20 ± 0,05 mA pour 100 % HR
0422
96SR-1,2
0507
GAS
Transmetteur de position linéaire différentiel (LVDT) vanne stop ratio gaz (VSR-1) Réglages : 0,7 ± 0,01 VAC pour 0 mm
FILT
Transmetteur de pression différentielle de l'étage de filtration Réglages : 4 ± 0,05 mA pour 0 mbar 20 ± 0,1 mA pour 25 mbar
0471
96TF-1
A040
0421
96TM-1
0605
ACCY
Transmetteur de position aubes variables convertisseur de couple Réglages : 04 ± 0,05 mA pour 0 tr de crémaillère (échelle 0-31 tr de crémaillère) 20 ± 0,05 mA pour 31 tr de crémaillère (échelle 0-31 tr de crémaillère)
0469
96TV-1
0548
TURB
Transmetteur de position linéaire différentiel (LVDT), actionneur aubes variables entrée compresseur Réglages : 0,7 ± 0,01 VAC pour 34° angle IGV
0469
96TV-2
0548
TURB
Transmetteur de position linéaire différentiel (LVDT), actionneur aubes variables entrée compresseur Réglages : 0,7 ± 0,01 VAC pour 34° angle IGV
0415
96VC-11
235A
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm
0415
96VC-12
235A
TURB
Capteur de vibration Caractéristiques : Sortie proximitor : 7,87 V/mm Réglages : Entrefer : 1,4 ± 0,05 mm Transmetteur de débit massique gaz Réglages : Réglages usine : 4 ± 0,05 mA pour 0 kg/s 20 ± 0,1 mA pour 10 kg/s
0422
96VM-1
0639
GAS
0462
96WF-1
A035
WI
Transmetteur de débit Réglages : 04 ± 0,2 mA pour 0 m3/h 20 ± 0,2 mA pour 30 ± 0,1 m3/h
0462
96WF-2
A035
WI
Transmetteur de débit Réglages : 04 ± 0,2 mA pour 0 m3/h 20 ± 0,2 mA pour 30 ± 0,1 m3/h
0462
96WF-3
A035
WI
Transmetteur de débit Réglages : 04 ± 0,2 mA pour 0 m3/h 20 ± 0,2 mA pour 30 ± 0,1 m3/h
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
21/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
22
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0425
AAT-1A
637T
TURB
Thermocouple sur air en aval du réfrigérant d'air d'atomisation Caractéristiques : Type K
0425
AAT-2A
637T
TURB
Thermocouple sur air en aval du réfrigérant d'air d'atomisation Caractéristiques : Type K
0434
AH1-1
0908
N/A
Accumulateur sur huile de contrôle Caractéristiques : 17,8 l | Azote Réglages : 51,7 ± 1 bar
0422
AH1-3
0991
N/A
Accumulateur sur huile de contrôle Caractéristiques : 17,8 l Réglages : 51,7 ± 1 bar
0471
AR-20
A040
FILT
Armoire électrique filtre à air
0436
AT-AC-1
1113
ENCL-T
Thermocouple compartiment auxiliaire Caractéristiques : Type K
0436
AT-AC-11
1113
ENCL-T
Thermocouple compartiment gaz Caractéristiques : Type K
0436
AT-LC-1
637T
TURB
Température compartiment puissance Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0436
AT-TC-1
637T
TURB
Température compartiment turbine Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0436
AT-TC-2
1113
ENCL-T
Thermocouple : compartiment turbine Caractéristiques : Type K
0436
AT-TC-3
1113
ENCL-T
Thermocouple : compartiment turbine Caractéristiques : Type K
0436
AT-WI-1
1659
ENCL-WI
Température compartiment injection d'eau compartiment injection d'eau Caractéristiques : Type K
0415
BT-J1-1A,1B
235A
TURB
Thermocouple dual température coussinet du palier n°1 Caractéristiques : Type K
0415
BT-J1-2A,2B
235A
TURB
Thermocouple dual température coussinet du palier n°1 Caractéristiques : Type K
0415
BT-J2-1A,1B
235B
TURB
Thermocouple dual température coussinet du palier n°2 Caractéristiques : Type K
0415
BT-J2-2A,2B
235B
TURB
Thermocouple dual température coussinet du palier n°2 Caractéristiques : Type K
0415
BT-J3-1A,1B
235C
TURB
Thermocouple dual température coussinet du palier n°3 Caractéristiques : Type K
0415
BT-J3-2A,2B
235C
TURB
Thermocouple dual température coussinet du palier n°3 Caractéristiques : Type K
0415
BT-TA1-2A,2B
235A
TURB
Thermocouple dual température patin n°2 de la butée du palier n°1 Caractéristiques : Type K
0415
BT-TA1-5A,5B
235A
TURB
Thermocouple dual température patin n°5 de la butée du palier n°1 Caractéristiques : Type K
0415
BT-TA1-8A,8B
235A
TURB
Thermocouple dual température patin n°8 de la butée du palier n°1 Caractéristiques : Type K
0415
BT-TI1-2A,2B
235A
TURB
Thermocouple dual température patin n°2 de la contre butée du palier n°1 Caractéristiques : Type K
0415
BT-TI1-5A,5B
235A
TURB
Thermocouple dual température patin n°5 de la contre butée du palier n°1 Caractéristiques : Type K
0415
BT-TI1-9A,9B
235A
TURB
Thermocouple dual température patin n°9 de la contre butée du palier n°1 Caractéristiques : Type K
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
22/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Appareils
SH
REV
23
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0425
CA1
0607
N/A
Compresseur principal d'air d'atomisation Caractéristiques : Centrifuge | 2,7 kg/s |6600 tr/min
0425
CA2
1047
N/A
Compresseur d'air d'atomisation de démarrage Caractéristiques : Volumétrique | 510 m3/h | 6200 tr/min
0415
CT-DA-1
637T
TURB
Thermocouple température air sortie du compresseur Caractéristiques : Type K
0415
CT-DA-2
637T
TURB
Thermocouple température air sortie du compresseur Caractéristiques : Type K
0415
CT-IF-1
637T
TURB
Thermocouple température air entrée du compresseur Caractéristiques : Type K
0415
CT-IF-2
637T
TURB
Thermocouple température air entrée du compresseur Caractéristiques : Type K
0492
CT-IF-3/R
637T
TURB
Détecteur de température à résistance Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0421
ET-CRS-11/R
0603
ACCY
Capteur de température 1 stator Ph1 du moteur de lancement Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0421
ET-CRS-12/R
0603
ACCY
Capteur de température 2 stator Ph1 du moteur de lancement Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0421
ET-CRS-21/R
0603
ACCY
Capteur de température 1 stator Ph2 du moteur de lancement Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0421
ET-CRS-22/R
0603
ACCY
Capteur de température 2 stator Ph2 du moteur de lancement Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0421
ET-CRS-31/R
0603
ACCY
Capteur de température 1 stator Ph3 du moteur de lancement Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0421
ET-CRS-32/R
0603
ACCY
Capteur de température 2 stator Ph3 du moteur de lancement Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0477
FA3-1
918T
N/A
Filtre sur air de balayage du combustible liquide Caractéristiques : 5 µm
0425
FA4-1
0983
N/A
Filtre sur air de commande des systèmes d'air d'atomisation et d'air de balayage Caractéristiques : 5 µm
0462
FA8-2
A035
N/A
Filtre à air injection d'eau Caractéristiques : 5 µm
0424
FD1-1
0613
N/A
Répartiteur de débit Caractéristiques : type linéaire : 7 éléments à double pompes | 1650 Hz | 883 l/min à 1650 tr/min
0494
FF11-1
E021
N/A
Filtre Caractéristiques : 910 µm
0494
FF11-2
E021
N/A
Filtre Caractéristiques : 910 µm
0424
FF2-1
1014
N/A
Filtre fuel HP Caractéristiques : Béta 40 = 75
0424
FF2-2
1014
N/A
Filtre fuel HP Caractéristiques : Béta 40=75
0434
FH2-1
1051
N/A
Filtre alimentation huile HP Caractéristiques : Béta 3 > 200
0434
FH2-2
1051
N/A
Filtre alimentation huile HP Caractéristiques : Béta 3 > 200
0424
FH3
0992
N/A
Filtre hydraulique servo vanne fuel liquide (contrôle) Caractéristiques : 40 µm
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
23/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Appareils
SH
REV
24
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0469
FH6-1
0548
N/A
Filtre alimentation bloc de commande hydraulique IGV Caractéristiques : Béta 15 = 75
0422
FH7-1
0507
N/A
Filtre hydraulique du circuit d'alimentation de la servo-valve de la VSR Caractéristiques : 15 µ abs
0422
FH8-1
0509
N/A
Filtre hydraulique alimentation hydraulique vanne control gaz (VGC) Caractéristiques : 15 µ abs
0462
FM1-1
A035
WI
0462
FW1-1
A035
N/A
Filtre haute pression Caractéristiques : Béta 13 = 75
0462
FW1-2
A035
N/A
Filtre cônique amont pompe d'injection d'eau Caractéristiques : Media filtrant 800µm
0462
FW1-3
A035
N/A
Filtre cônique aval débimètre Caractéristiques : Media filtrant 150µm
0421
HM-1
0605
N/A
Convertisseur de couple et inverseur
0469
HM3-1
0548
N/A
Ensemble actionneur système aubes variables entrée compresseur Caractéristiques : Course vérin de 32° à 86°
0425
HX1-1
1003
N/A
Réfrigérant de l'air d'atomisation en amont du compresseur d'air d'atomisation
0416
LT-B1D-1
637T
TURB
Thermocouple retour huile palier #1 Caractéristiques : Type K
0416
LT-B2D-1
637T
TURB
Thermocouple retour huile palier #2 Caractéristiques : Type K
0416
LT-B3D-1
637T
TURB
Thermocouple retour huile palier #3 Caractéristiques : Type K
0416
LT-BT1D-1
637T
TURB
Thermocouple retour huile butées palier #1 Caractéristiques : Type K
0416
LT-G1D-1
ALT.
GENE
Thermocouple retour d'huile palier #1 alternateur et réducteur Caractéristiques : Type K
0416
LT-G2D-1
ALT.
GENE
Thermocouple retour d'huile palier #2 alternateur et réducteur Caractéristiques : Type K
0416
LT-OT-1A
637A
ACCY
Détecteur de température à résistance Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0416
LT-OT-2A
637A
ACCY
Détecteur de température à résistance Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0416
LT-TH-1A,1B
637A
ACCY
Thermocouple huile de lubrification collecteur turbine Caractéristiques : Type K
0416
LT-TH-2A,2B
637A
ACCY
Thermocouple huile de lubrification collecteur turbine Caractéristiques : Type K
0416
LT-TH-3A,3B
637A
ACCY
Thermocouple huile de lubrification collecteur turbine Caractéristiques : Type K
0422
MG1
0512
N/A
Injecteur combustible gaz
0424
PF1
0611
ACCY
Pompe Principale Combustible Liquide Caractéristiques : Pompe à vis | 870,5 l/min | 68,9 bar | 1550 tr/min
0424
PF1-90
0611
N/A
Pompe de lubrification Caractéristiques : Voir le P&ID LMA-37361
0494
PFA-10
E021
N/A
Pompe de chargement Caractéristiques : Pompe volumétrique | 25 l/min
Débimètre injection d'eau Caractéristiques : 3,6 m3/h | 29,5 m3/h | Facteur nominal K : 158,5 impulsions / l
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
24/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Appareils
SH
REV
25
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0494
PFA-11
E021
N/A
Pompe doseuse Caractéristiques : Pompe volumétrique à piston | 4 l/h | 10 bar | 1500 tr/min
0494
PFA-12
E021
N/A
Pompe doseuse Caractéristiques : Volumétrique à piston | 4 l/h | 10 bar | 1500 tr/min
0434
PH1
0627
ACCY
Pompe hydraulique principale Caractéristiques : Type volumétrique à débit variable | 65 l/min | 105 bar | 1422 tr/min
0434
PH2
0628
ACCY
Pompe auxiliaire huile HP Caractéristiques : Volumétrique | 45,4 l/min | 105 bar | 1450 tr/min
0494
PSV-11
E021
N/A
Respirateur du bac 501BA Caractéristiques : Normal : NC Réglages : Surpression : 0.15 bar ; Vide : 0.01 bar
0462
PW1-1
A035
N/A
Groupe moto-pompe injection d'eau
0426
SLI-1
1104
ACCY
Avertisseur lumineux compartiment auxiliaire Caractéristiques : 240 UPS | 50 Hz
0426
SLI-1A
1113
ENCL-T
Avertisseur incendie compartiment auxiliaire Caractéristiques : 24 VDC
0426
SLI-1B
1113
ENCL-T
Avertisseur incendie compartiment TG Caractéristiques : 24 VDC
0426
SLI-1C
1113
ENCL-T
Avertisseur incendie compartiment TG Caractéristiques : 24 VDC
0426
SLI-1D
1195
ENCL-G
Avertisseur incendie compartiment gaz Caractéristiques : Alarme lumineuse | 24 VDC
0426
SLI-1E
1195
ENCL-G
Avertisseur incendie compartiment gaz Caractéristiques : 24 VDC
0426
SLI-2
1104
ACCY
0426
SLI-2B
1113
ENCL-T
Avertisseur incendie compartiment TG Caractéristiques : 24 VDC
0426
SLI-2C
1113
ENCL-T
Avertisseur incendie compartiment TG Caractéristiques : 24 VDC
0426
SLI-2E
1195
ENCL-G
Avertisseur incendie compartiment gaz Caractéristiques : 24 VDC
0426
SLI-3C
1113
ENCL-T
Avertisseur incendie compartiment puissance Caractéristiques : 24 VDC
0415
TT-IB-1
637T
TURB
Thermocouple température tunnel échappement Caractéristiques : Type K
0415
TT-WS1AO-1
637T
TURB
Thermocouple température position extérieure après première roue Caractéristiques : Type K
0415
TT-WS1AO-2
637T
TURB
Thermocouple température position extérieure après première roue Caractéristiques : Type K
0415
TT-WS1FI-1
637T
TURB
Thermocouple température position intérieure avant première roue Caractéristiques : Type K
0415
TT-WS1FI-2
637T
TURB
Thermocouple température position intérieure avant première roue Caractéristiques : Type K
0415
TT-WS2AO-1
637T
TURB
Thermocouple température position extérieure après deuxième roue Caractéristiques : Type K
0415
TT-WS2AO-2
637T
TURB
Thermocouple température position extérieure après deuxième roue Caractéristiques : Type K
Avertisseur lumineux compartiment auxiliaire Caractéristiques : 240 UPS | 50 Hz
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
25/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
26
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0415
TT-WS2FO-1
637T
TURB
Thermocouple température position extérieure avant deuxième roue Caractéristiques : Type K
0415
TT-WS2FO-2
637T
TURB
Thermocouple température position extérieure avant deuxième roue Caractéristiques : Type K
0415
TT-WS3AO-1
637T
TURB
Thermocouple température position extérieure après troisième roue Caractéristiques : Type K
0415
TT-WS3AO-2
637T
TURB
Thermocouple température position extérieure après troisième roue Caractéristiques : Type K
0415
TT-WS3FO-1
637T
TURB
Thermocouple température position extérieure avant troisième roue Caractéristiques : Type K
0415
TT-WS3FO-2
637T
TURB
Thermocouple température position extérieure avant troisième roue Caractéristiques : Type K
0415
TT-XD-1
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-10
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-11
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-12
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-13
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-14
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-15
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-16
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-17
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-18
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-19
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-2
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-20
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-21
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-22
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-23
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-24
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-3
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
26/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
27
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0415
TT-XD-4
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-5
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-6
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-7
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-8
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0415
TT-XD-9
0623
TURB
Thermocouple température gaz d'échappement de la turbine Caractéristiques : Type K
0477
VA13-1
918T
N/A
Vanne d'air de balayage du circuit de combustible gazeux Caractéristiques : Normal : NC Réglages : Temps d'ouverture doit être 35 ± 5 secondes. Temps de fermeture doit être 10 secondes au maximum.
0477
VA13-2
918T
N/A
Vanne d'air de balayage du circuit de combustible gazeux Caractéristiques : Normal : NC Réglages : Temps d'ouverture doit être 35 ± 5 secondes. Temps de fermeture doit être 10 secondes au maximum.
0442
VA17-1
1026
N/A
Vanne purge faux départ Caractéristiques : Normal : NO
0442
VA17-2
1026
N/A
Vanne purge faux départ Caractéristiques : Normal : NO
0442
VA17-5
1026
N/A
Vanne purge caisson échappement faux départ Caractéristiques : Normal : NO
0425
VA18-1
1070
N/A
Vanne d'ajustement de la pression d'air d'atomisation Caractéristiques : Normal : NC
0477
VA19-1
918T
N/A
Vanne d'air de balayage du circuit de combustible liquide Caractéristiques : Normal : C vers L ouvert ; U fermé
0417
VA2-1
1022
N/A
Vanne anti-pompage 11ème étage Caractéristiques : Normal : NO
0417
VA2-2
1022
N/A
Vanne anti-pompage 11ème étage Caractéristiques : Normal : NO
0425
VA22-1
0922
N/A
Vanne type papillon pour isolement entrée d'air du compresseur d'air d'atomisation CA2 Caractéristiques : Normal : NO
0417
VA2-3
1022
N/A
Vanne anti-pompage 11ème étage Caractéristiques : Normal : NO
0417
VA2-4
1022
N/A
Vanne anti-pompage 11ème étage Caractéristiques : Normal : NO
0477
VA36-1
918T
N/A
Vanne pneumatique de dépressurisation rapide Caractéristiques : sous pression: 1 vers 2 ouvert et évent 3 fermé hors pression: 2 ouvert vers l'évent 3
0477
VA36-2
918T
N/A
Vanne pneumatique de dépressurisation rapide Caractéristiques : sous pression: 1 vers 2 ouvert et évent 3 fermé hors pression: 2 ouvert vers l'évent 3
0494
VA99-11
E021
N/A
Vanne pneumatique Caractéristiques : Normal : NO
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
27/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Appareils
SH
REV
28
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0494
VA99-12
E021
N/A
Vanne pneumatique Caractéristiques : Normal : NC
0494
VA99-13
E021
N/A
Vanne pneumatique Caractéristiques : Normal : NO
0434
VAB1
0947
N/A
Purge air sur circuit hydraulique principal
0434
VAB2
0947
N/A
Purge air sur circuit hydraulique auxiliaire
0424
VC3
0516
N/A
Vanne de dérivation de contrôle débit fuel Caractéristiques : Normal : NO | Course = 28,57 mm
0462
VC4-1
A035
N/A
Vanne de régulation d'injection d'eau Caractéristiques : Normal : NC
0462
VCK100
A035
N/A
Clapet anti-retour
0462
VCK110
A035
N/A
Clapet anti-retour
0462
VCK111
A035
N/A
Clapet anti-retour
0424
VCK1-1T14
0961
N/A
Clapet anti-retour sur injecteur pour combustible fuel Caractéristiques : Normal : NC Réglages : Tarage : 8,27 ± 0,34 bar
0477
VCK2-1T14
918T
N/A
Clapet anti-retour sur air de balayage des injecteurs primaires de combustible liquide Caractéristiques : Normal : NC Réglages : Pression d'ouverture : Minimum 0,07 bar
0434
VCK3-1
0947
N/A
Clapet anti-retour pompe principale Caractéristiques : Normal : NC Réglages : Seuil = 1,5 bar
0434
VCK3-2
0947
N/A
Clapet anti-retour pompe auxiliaire Caractéristiques : Normal : NC Réglages : Seuil = 1,5 bar
0417
VCK7-1
1233
N/A
Clapet circuit air refroidissement corps turbine Caractéristiques : Normal : NC Réglages : pression d'ouverture : 7 mbar
0417
VCK7-2
1233
N/A
Clapet circuit air refroidissement corps turbine Caractéristiques : Normal : NC Réglages : pression d'ouverture : 7 mbar
0422
VGC-1
0509
GAS
Vanne de contrôle gaz primaire Caractéristiques : Normal : NC | Course maxi = 38,1 mm
0469
VH3-1A
0548
N/A
Vanne de déclenchement hydraulique IGV
0469
VH3-1B
0548
N/A
Vanne de déclenchement hydraulique IGV
0422
VH5-1
0507
GAS
Vanne de déclenchement hydraulique (VSR-1) - Vanne Stop Gaz Caractéristiques : Normal : NC
0422
VH5-2
0509
GAS
Vanne de déclenchement hydraulique (VGC-1) - Vanne contrôle gaz Caractéristiques : Normal : NC
0422
VM-1
0639
N/A
Débitmètre massique à effet coriolis
0434
VM4
1052
N/A
Vanne transfert pour filtre huile HP
0424
VP-1
0961
N/A
Vanne multiport Caractéristiques : Normal : NC
0424
VP-2
0961
N/A
Vanne multiport Caractéristiques : Normal : NC
0416
VPR2-1
1023
N/A
Vanne de régulation pression alimentation huile de lubrification Caractéristiques : Normal : NC Réglages : Point de consigne : 1,72 +0,13/-0 bar
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
28/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4
DWG NO
137A3171
MLI PID
Appareils
SH
REV
29
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0494
VPR30-11
E021
N/A
Filtre régulateur Caractéristiques : Normal : NO Réglages : 4 ± 0.35 bar
0434
VPR3-1
0627
N/A
Compensateur de pression pompe hydraulique Réglages : 103,4 ± 1,37 bar
0477
VPR44-1
918T
N/A
Filtre détendeur d'air de commande de la vanne d'air de balayage du combustible gazeux Réglages : 2,3 +0/-0,2 bar
0477
VPR44-2
918T
N/A
Filtre détendeur d'air de commande de la vanne d'air de balayage du combustible gazeux Réglages : 2,3 +0/-0,2 bar
0477
VPR54-1
918T
N/A
Filtre détendeur d'air de commande de la vanne d'air de balayage du combustible liquide Réglages : 3,27 +1,7/-0 bar
0462
VPR62-1
A035
N/A
Filtre détendeur (partie de VC4-1) Réglages : 3,1 ± 0,1 bar
0462
VPR62-13
A035
N/A
Filtre détendeur (partie de VS2-2) Réglages : 3,1 ± 0,1 bar
0425
VPR68-1
0922
N/A
Vanne de régulation de pression pour isolation surpresseur AA Réglages : 3,79 ± 0,13 bar (55 ± 2 psi)
0416
VR1
1016
N/A
Vanne de décharge pompe principale huile de lubrification Caractéristiques : Normal : NC Réglages : Ouverture à 6,89 + 0,13/-0 bar
0434
VR21
0947
N/A
Vanne de décharge pompe principale huile HP Caractéristiques : Normal : NC Réglages : 113,7 ± 1,37 bar
0434
VR22
0947
N/A
Vanne de décharge pompe auxiliaire huile HP Caractéristiques : Normal : NC Réglages : 113,7 ± 1,37 bar
0424
VR27
0992
N/A
Soupape de décharge pression alimentation combustible liquide Caractéristiques : Normal : NC Réglages : Tarage : 6,2 ± 0,2 bar
0424
VR4
0992
N/A
Vanne de décharge pompe à fuel Caractéristiques : Normal : NC Réglages : Tarage : 82,7 ± 1,72 bar
0494
VR60-11
E021
N/A
Soupape de sécurité de la pompe Caractéristiques : Normal : NC Réglages : Ouverture à 12 ± 1 bar
0494
VR60-12
E021
N/A
Soupape de sécurité de la pompe PFA-12 Caractéristiques : Normal : NC Réglages : Ouverture à 12 ± 1 bar
0424
VS1
0511
N/A
Vanne arrêt fuel Caractéristiques : Normal : NC
0462
VS2-2
A035
N/A
Vanne d'arrêt injection d'eau Caractéristiques : Normal : NC
0422
VSR-1
0507
GAS
Vanne d'arrêt et réglage gaz Caractéristiques : Normal : NC | Course maxi = 88,9 ± 0,127 mm
0420
VTR1-1
1035
N/A
Vanne thermostatique régulant la température de l'huile de graissage Caractéristiques : Normal : E vers B ouvert, C fermé Réglages : Début d'ouverture à T° d'huile = 54 ± 2°C
0420
VTR2-1
1027
N/A
Vanne thermostatique régulant la température d' air d'atomisation Caractéristiques : Normal : B vers E ouvert, C fermé Réglages : T° air = 107 ± 2 °C
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
29/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
SIZE
A4 MLI PID
DWG NO
137A3171
Appareils
SH
REV
30
MLI
Schéma câblage
F
TBFT-TMP-FR-GTE-0060 Rev : 001
Désignation
0420
WT-TL-1
637T
TURB
RTD température eau pattes turbine Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
0420
WT-TL-2
637T
TURB
RTD température eau pattes turbine Caractéristiques : Platine PT100 | 100 Ohm à 0°C | 0,385 Ohm/°C | -50 à 260 °C
SIZE
CAGE CODE
A4
DWG NO
137A3171 SECTION 01F
SCALE
SHEET
30/30
Doc. Source : TBFT-ISP-FR-GTE-0020 Ce document, propriété exclusive de GE Energy Products France SNC est strictement confidentiel Il ne peut être communiqué, copié ou reproduit sans notre autorisation écrite préalable.
This document, exclusive property of GE Energy Products France SNC. is strictly confidential. It must not be communicated, copied or reproduced without our previous written consent.
E
G ffi c
O ia l
BASIC CONTROL DEVICE FUNCTION NUMBERS AMERICAN NATIONAL STANDARDS INSTITUTE 1
MASTER ELEMENT
50
2
SEQUENCE TIMER
51
AC TIME OVERCURRENT RELAY
3
CHECKING RELAY
52
AC CIRCUIT BREAKER or CONTACTOR
4
MASTER RELAY
55
POWER FACTOR RELAY
5
STOPPING DEVICE
57
SHORT CIRCUITING or GROUNDING DEVICE
6
STARTING CIRCUIT BREAKER
59
OVERVOLTAGE RELAY
8
CONTROL POWER DISCONNECTING DEVICE
60
VOLTAGE or CURRENT BALANCE RELAY
10
UNIT SEQUENCE SWITCH
62
STOPPING or OPENING TIMER RELAY
12
OVERSPEED DEVICE
63
LIQUID or GAS PRESSURE or VACUUM
13
SYNCHRONOUS SPEED DEVICE
64
GROUND PROTECTIVE RELAY
14
SPEED RELAY
65
GOVERNOR
15
SPEED or FREQUENCY MATCHING DEVICE
66
NOTCHING or JOGGING DEVICE
18
ACCELERATING or DECELERATING DEVICE
67
AC DIRECTIONAL OVERCURRENT RELAY
20
SOLENOID VALVE
68
BLOCKING RELAY
21
DISTANCE RELAY
69
PERMISSIVE CONTROL DEVICE
23
TEMPERATURE CONTROL DEVICE
70
ELECTRICALLY OPERATED RHEOSTAT
25
SYNCHRONISM CHECK DEVICE
71
LIQUID or GAS LEVEL RELAY
26
TEMPERATURE SENSING DEVICE
72
DC CIRCUIT BREAKER or CONTACTOR
27
UNDERVOLTAGE
75
POSITION CHANGING MECHANISM
28
FLAME DETECTOR
77
PULSE TRANSMITTER
30
ANNUNCIATOR RELAY
80
LIQUID or GAS FLOW RELAY
32
DIRECTIONAL POWER RELAY
81
FREQUENCY RELAY
33
POSITION SWITCH
82
DC RECLOSING RELAY
34
MASTER SEQUENCE DEVICE
83
AUTOMATIC SELECTIVE CONTROL or TRANSFER RELAY
37
UNDERCURRENT or UNDERPOWER RELAY
84
OPERATING MECHANISM
38
BEARING PROTECTIVE DEVICE
85
CARRIER or PILOT–WIRE RECEIVER RELAY
39
MECHANICAL CONDITION MONITOR
86
LOCK–OUT RELAY
40
FIELD RELAY
87
DIFFERENTIAL PROTECTIVE RELAY
41
FIELD CIRCUIT BREAKER
88
AUXILIARY MOTOR or MOTOR GENERATOR
43
MANUAL TRANSFER or SELECTOR DEVICE
89
LINE SWITCH
45
ATMOSPHERIC CONDITION MONITOR
90
REGULATING DEVICE
46
REVERSE–PHASE or PHASE–BALANCE CURRENT RELAY
91
VOLTAGE DIRECTIONAL RELAY
47
PHASE–SEQUENCE VOLTAGE RELAY
93
FIELD–CHANGING CONTACTOR
48
INCOMPLETE SEQUENCE RELAY
94
TRIPPING or TRIP–FREE RELAY
49
MACHINE or TRANSFORMER THERMAL RELAY
96
TRANSDUCER
A00029b
1
INSTANTANEOUS OVERCURRENT or RATE–of–RISE RELAY
BASIC CONTROL DEVICE FUNCTION NUMBERS
GE Power Systems Training General Electric Company One River Road Schenectady, NY 12345
A00029b
2
BASIC CONTROL DEVICE FUNCTION NUMBERS
GE Power Systems
GLOSSARY OF TERMINOLOGY (Mark IV, Mark V Gas Turbine Control System) An understanding of the Mark IV and V gas turbine control system requires a knowledge of the terminology used in the electrical control system and for the mechanics of the gas turbine. This glossary is divided into part (A) Mark IV and V Electrical Control Terminology, and part (B) Gas Turbine Terminology.
to perform operations which require a fast execution time. Assembler A computer program that converts assembly language programs into a form (machine language) that the computer can understand. The assembler translates mnemonic instruction codes into binary numbers, replaces names with their binary equivalents, and assigns locations in memory to data and instructions.
A. MARK IV AND MARK V ELECTRICAL CONTROL TERMINOLOGY
Assembly Language A programmming language in which the programmer can use mnemonic instruction codes, labels, and names to refer directly to their binary equivalents. The assembler is a low-level language, since each assembly language instruction translates directly into a specific machine language instruction.
Address The identification code that distinguishes one memory location or input/output port from another. Address Bus A bus used to transmit the identification code that distinguishes one memory location or I/O port from another. Algorithm
Asynchronous Operation of a switching network by a free-running signal. Completion of one instruction triggers the next instruction.
Refer to CONTROL ALGORITHM
Back-plane The internal wiring of a module between pins of the cards located in the module. Some modules have a “flow-soldered” back-plane, which is a printed circuit card that the other cards plug into.
Analog A continuous signal or a representation of a quantity that can have any value. Application Application-oriented computer programs, such as the Sequencer Code and Control Algorithms.
Baud A measure of the rate of data flow transfer. The number of signal elements (bits) transmitted per second. (2400 Baud transfers 2400 Bits = 300 Bytes/sec.)
Software which are customized to the needs of each installation. Array Systematic arrangement of numbers or data in tabulated form.
Binary A system of numbers using 2 as a base. (In contrast to the decimal system, which uses 10 as a base).
ASCII Abbreviation for American Standard Code for Information Interchange. Each character is assigned a number between 32 and 127.
Bit A single binary digit which can be in either of two states (0/ or 1). Bootstrap Technique for loading first instructions of a program into memory and then using these instructions to bring in the rest of the program.
ASM-86 A low-level programming language designed for the Intel 8086 microprocessor. ASM-86 is used in the Mark IV computer operating system C00023
1
GLOSSARY OF TERMINOLOGY
GE Power Systems BRAM Battery-backed Random Access Memory is used to retain field editable software during power outages for a given length of time.
control block (instruction-decoding, execution and timing) and I/O. Cycle The process of powering-down, then powering-up a processor; (i.e. moving the toggle switch on the processor’s power supply to first the DISABLE position, then the ENABLE position). The processor will re-initialize when it is powered back up.
Bus A group of parallel lines that connect two or more devices. Byte
A data element consisting of 8 bits.
Checksum A logical sum of data that is included in a record as a guard against recording or transmission errors.
Data Information that is processed by a microprocessor according to its Code. Generally, the microprocessor’s input, output and ‘workspace’ information.
Clock The pulse generator which controls the timing of switching circuits in the microprocessor. Hardware architecture and programming are other factors in determining the rate of data manipulation.
Database The organized collection of Data and Constants that are important to field service personnel. Data Bus A bus used to transfer coded information to and from the CPU memory storage and peripheral devices.
Coding The writing of programs in a language that is comprehensible to a computer system. Cold Junction The junction between the thermocouple wire and the screw terminals on the thermocouple modules generates an EMF at point of termination called the “cold junction”.
Differential Input An analog input which has a high impedance to ground on input wires. Downloading The processor’s operation which copies information from one section of a processor’s Memory into a different section of the same Memory or into another processor’s Memory. If a Controller is ‘cycled’ (powered-down, then powered-up), the Sequencer Code is downloaded from the Communicator to the Controller.
Compiler A program that converts a program in a high-level (i.e. procedure-oriented) language into an assembly or machine language program. Control Algorithm A PLM-86 Application Software program that performs a specific function, such as speedcontrol or vibration protection.
“Dumb Terminal” Terminal for data input/output to/from Host Computer; (by strict definition: No internal data storage/manipulation)
Control Bus The bus carries commands from and to the CPU for control of the operating system (i.e. read, write, etc.).
Editor A program that manipulates text material and allows the user to make corrections, additions, deletions, and other changes.
Control Constants The subset of “Constants” that are used in the Control Algorithms and the Sequencer Code to define gains, time constants, offsets, etc. Each Control Constant can be called by its Signal Name as shown in the Elementary.
EPROM Erasable Programmable Read Only Memory can be erased by exposure to ultraviolet light.
CPU Central Processing Unit, the heart of the computer system, consists of storage elements (registers), arithmetic unit (computation circuits), GLOSSARY OF TERMINOLOGY
EEPROM Electrically Erasable Programmable Read Only Memory is used to store the field edit2
C00023
GE Power Systems able Application Software so that it will not be lost during a power outage.
Interrupt A computer input that temporarily suspends the normal sequence of operations and transfers computer control to an Interrupt Service Routine.
Firmware A method of system control program design in which all control instructions are contained in ROM or PROM.
Interrupt Service Routine A program that performs the actions required to respond to an interrupt.
Handshaking A method of controlling data transfers in which the transmitting device generates a data ready signal. This signal directs the receiving device to accept the data. The receiving device then generates a data accepted signal to inform the transmitting device that it may remove the data and proceed.
IVAR A Database array dedicated to storing integer data. LDATA A Database array dedicated to storing logic data Signal Names, such as “complete sequence” (L3) or “flame detected” (L28FD).
Hardware Physical equipment forming a computer system (as opposed to the Software).
LVAR A Database array dedicated to storing logic data.
Hexadecimal A system of numbers using 16 as a base (In contrast to the decimal system which uses 10 as a base.)
Linking Loader A loader that will enter a series of program and subroutines into memory and provide the required interconnections.
High-Level Language A programming language in which the statements represent procedures rather than single machine instructions. PLM-86 is the high-level language used within the Mark IV system. A high-level language requires a compiler that translates each statement into a series of machine language instructions.
Low-Level Language A language in which each statement is directly translated into a single machine language instruction. MDATA A Database array dedicated to storing pre-defined miscellaneous data Signal Names. MEM A Medium Electronics Module can contain up to 24 circuit cards. The Communicator is a MEM.
IDATA A Database array dedicated to storing integer variable Signal Names, such as speed (TNH) or fuel stroke reference (FSR).
Machine Language The programming language that the computer can directly understand with no translation other than numeric conversions. A machine language program can be loaded into memory and executed. The value of every bit in every instruction in the program must be specified.
Instruction A group of bits that defines a computer operation and is part of the instruction set. Instruction Set The set of general-purpose instructions available with a given computer — the set of inputs to which the CPU will produce a known response during the instruction fetch cycle.
Membrane Switch One of the pushbuttons which are beneath the overlay on the Operator Interface Module.
Interpreter A program that fetches and executes instructions written in a high-level language. An interpreter executes each instruction as soon as it reads the instruction; it does not produce an object program, as a compiler does. C00023
Memory The section of a computer which stores information (i.e. code, data and constants) in binary form. Each item in the Memory has a unique address that the CPU can use to access it. 3
GLOSSARY OF TERMINOLOGY
GE Power Systems Microcomputer A computer whose CPU is a microprocessor plus memory and input/output circuitry.
ences have no effect because the devices are electrically separated. Page A subdivision of Memory containing 64K (i.e. 65,0/0/0/ bytes).
Microprocessor A central processing unit generally consisting of an arithmetic and logic unit, control block and register array, and a memory storage system.
Party Line A large number of devices connected to a single line originating in a CPU. PLM-86 A high-level language designed for systems and application programming of the Intel 8086 microprocessor. Control programs algorithms are written in PL/M-86.
Modem A device that adds or removes a carrier frequency to an existing signal which allows data to be transmitted or received on a high frequency channel.
Port The point where the I/O is in contact with the outside world.
Modular Programming A programming method whereby the entire task is divided into logically separate sections or modules.
Programming The implementation of the control function of a processing system as a sequence of control signals that is organized into words and stored in memory.
MOV A Metal Oxide Veristor. A zener-oxide device that suppresses voltage spikes. Multiplexing A process of transmitting more than one signal at a time on a single link via timesharing (i.e. serial) or frequency-sharing (i.e. parallel).
PROM Programmable Read Only Memory is used to store software which is not field adjustable and will not be lost during a power outage. PROM Programmer A piece of equipment that stores Software in a PROM.
MVAR A Database array dedicated to storing miscellaneous data.
Processor A microcomputer (a microprocessor plus Memory and Input/Output circuitry) used in the Mark IV panel. The Communicator and the Controllers .
Object Program (Object Code) The program that is the output of a translator program (such as an assembler or compiler). Usually a machine language program ready for execution.
Protocol
Off-line A function performed with the turbine stopped and/or the control disconnected from the process.
RAM Random Access Memory can be read and written to during operation and must be backed-up to retain its contents during a power outage.
Operating System System software that controls the overall operation of a computer system and performs such tasks as memory allocation, input and output distribution, interrupt processing, and task scheduling.
Real Time In synchronization with the actual occurrence of events. Real Time Operation A data processing technique which allows the machine to use information as it becomes available, as opposed to batch processing at a time unrelated to the time the information is generated.
Optical Isolation A semiconductor device consisting of an LED and a photodiode or phototransistor in close proximity. Current through the LED causes an internal light emission that forces current flow in the phototransistor. Voltage differGLOSSARY OF TERMINOLOGY
A procedure for data communication.
Refresh The process of restoring the contents of a dynamic memory before they are lost. 4
C00023
GE Power Systems Register A temporary small scale memory used by the CPU for logic, arithmetic or transfer operations.
Subroutine A sub-program that can be reached from one or more places in a main program.
RS232 An IEEE communication standard used for communication between , , , and the panel mounted printer. It is also available for remote communication.
Stack A data structure used for temporary storage which receives data on the top of the stack and pushes existing data further down in the stack. Data is removed from the top of the stack creating a lastin, first-out arrangement.
RS422 An IEEE communication standard used for remote communication.
Stall A cessation of processor operation (due to malfunction).
Rung A series of Sequencer Code commands (i.e. pseudo-contacts) which result in a store statement (i.e. pseudo-coil).
String A sequence of character codes stored sequentially in Memory. The Relay Ladder Diagram Rungs consist of one or more strings.
Sampling Rate The frequency that a given program is run. Some control algorithms are run four times every second.
TTL Transistor-Transistor Logic is the most widely used bi-polarity technology for digital integrated circuits.
SEM A Small Electronics Module contains up to 12 circuit cards. Controllers are SEM’s.
Utility Program A program that provides basic functions, such as loading and saving programs, initiating program execution, observing and changing the contents of memory locations, or setting breakpoints and tracing.
Sequencer Code The set of instructions that performs the turbine’s sequencing functions. Serial Link An interface between two computer systems that permits one of the systems to transmit data to, and receive data from, the other system.
Voting Voting in the Mark IV means that the control will respond to the majority logic from the three Controllers.
Single Ended Input An input which has a high impedance to ground on one of the two incoming wires.
Word Sixteen consecutive bits which the computer can manipulate in a single cycle.
Softswitch One of the six pushbuttons, located at the right of the CRT display, which are assigned a function by the display which currently appears on the screen. Software
C00023
Wire Wrap Wiring within modules is terminated on the card or relay socket pins by wrapping the wire around the pins.
Computer programs.
5
GLOSSARY OF TERMINOLOGY
GE Power Systems Annular Space or Annulus The ring like space between the combustion liner and the flow shield.
GAS TURBINE TERMINOLOGY Accessory Compartment A sheet metal house with access doors which may be located on the same base as the turbine or on a separate base. It contains the mechanical accessories needed to support the prime mover operation.
Anti-Icing System Preheating of the inlet air to prevent ice formation in the inlet system. Atomizing Air High pressure air which is used to break up liquid fuel into small droplets to improve the combustion.
Accessory Coupling A fluid or grease filled flexible coupling which drives the accessory gear from (the forward end of) the prime mover.
Aux. Hydraulic Supply Pump The motor driven high pressure pump used to supply servo pressure during start-up or emergency conditions.
Accessory Gear Encompasses a number of gears which drive most of the gas turbine accessories at the proper speeds and which connects the turbine to its starting device. The gear is driven by the starting device, and then by the turbine when the unit reaches self-sufficient speed. Common items driven by this gear are: liquid fuel pump, water pump, main lube pump, main hydraulic pump, main atomizing air compressor.
Aux. Lube Pump Provides lubricating oil during start-up and shutdown, and serve as a standby to the main pump. An AC motor is usually the drive source. Axial Flow A (gas turbine) compressor which moves air axially through a series of rotor and stator compressor blades. The rotating elements impart momentum to the air mass, and the stator elements convert that momentum to pressure in conjunction with the converging walls of the compressor casing.
Accessory Gear Box Refers to the complete accessory gear assembly. Accumulator A hydro-pneumatic device designed to absorb a hydraulic shock and to deliver a regulated force (in the form of pressure and flow) during transient demands on a system.
Base Load The load at the rated temperature control setpoint at which the turbine can be operated to maintain the recommended parts life expectancy.
Acid Removal Filter The machine part that neutralizes acid in the lube oil supply.
Bearing The stationary machine part which contains the journal bearing liner.
Actuator A self-contained device designed to deliver a controlled or regulated force in order to activate some other device. Aft End
Bearing Feed Header The section of the lube oil piping, downstream of the oil filters, which carries lubrication to the individual turbine bearings.
The exhaust end of the gas turbine.
Bearing Seal A general term identifying a means of preventing oil leakage from a bearing.
Aftercooler The atomizing air cooler downstream of the main atomizing air compressor.
Bellmouth The flared bell-shaped cast inlet which provides an even airflow distribution to the compressor through the inlet guide vanes.
Air Separator The device which removes large particulate matter from an air supply via an inertial or centrifugal force.
Black Start The means of starting a turbine without incoming AC power.
Ambient Air Air surrounding the gas turbine housing which enters the turbine to support combustion. GLOSSARY OF TERMINOLOGY
Blade A rotating or stationary airfoil in an axial compressor. 6
C00023
GE Power Systems Blow Off Valve A valve which bypasses air from the compressor around the regenerator and the high and low pressure turbines (i.e. two (2) shafts gas turbine) to reduce available energy and prevent overspeed during a sudden loss of load. It is primarily used on two shaft, generator drives.
Combustion Liner The chamber where chemical energy is released and added to the gas flow path. Combustion System A system consisting of fuel nozzles, spark plugs, flame detectors, crossfire tubes, combustion liners, transition pieces and a combustion casing or wrapper.
Brittle The loss of resiliency in the parent metal due to aging, extreme cold or chemical action.
Compression Ratio The ratio of the compressor discharge pressure to the inlet pressure.
Brake Horsepower The horsepower developed at the load coupling.
Compressor The mechanical component which is used to increase the pressure of the working medium within its structure.
Buckets Airfoil elements mounted radially on the rotor wheel to transfer energy from the working medium to the turbine rotor.
Compressor Discharge Casing Contains the last stages of the compressor stator blades and is used to:
Burnishing The process of smoothing a metal surface by means of a mechanical action with no loss of material. This normally occurs on plain bearing surfaces.
— Join the compressor and turbine stators — Support the forward end of the combustion wrapper — Provide an inner support for the first stage turbine nozzles.
Bypass Valve A device which regulates the flow of a fluid in: A) A fuel bypass valve on a liquid fuel system using a positive displacement pump or, B) An air control valve used for compressor pulsation protection.
— May provide support for a bearing Control Compt. (Control CAB) The compartment which contains the gas turbine electrical controls and protection equipment.
Centrifugal Separator A device used to remove dust from the gas turbine cooling and sealing air system. Separation is achieved by a centrifugal action.
Cooling and Sealing Air A system which provides air pressure for cooling and sealing various turbine components.
Chamfer A beveled edge (i.e. by the removal of some of the gear material at an angle from the top land to the bottom land at the ends of the teeth.
Cooling Water Pump Provides cooling water flow for the system. A gear box or electric motor drives the pump.
Check Valve A device which allows fluid flow in only one (1) direction.
Cooling Water Radiator The on or off base water/air or water/water heat exchanger.
CO2 Carbon dioxide, used as a fire extinguishing medium.
Coupling A component which connects a driven component to the drive source. Examples: Accessory Gear Coupling, Load Coupling, Pump Coupling, Starting Motor Coupling, etc.
Combustor or Combustion Chamber The mechanical component of the combustion system in which the combustion takes place (increasing the temperature of the working medium). C00023
Coupling Comp. pling. 7
A housing for the load cou-
GLOSSARY OF TERMINOLOGY
GE Power Systems Cranking The turning of the turbine rotor during start-up or shutdown.
Exhaust Frame The machine part which usually support the aft journal bearing. The air discharged from the exhaust diffuser is directed to the turning vanes. Air-cooled, internal struts maintain position of the bearing.
Crossfire Tubes The piping which interconnects the combustion chambers on multiple combustion chamber turbines. These tubes also allow flame propagation from the two (2) spark plug ignited combustors to the other chambers.
Exhaust Hood The component which surrounds the aft bearing area and is bolted to the turbine case aft flange. It assists in guiding air flow in to the turning vanes.
Cycle Thermal The ratio of the net work output to the total heat input = [ Work of Turbine - Work of Efficiency Compressor ]/Heat Input.
Exhaust Plenum An enclosed cavity which receives discharged exhaust gases after the gases exit from the load turbine wheel.
Diaphragm The stationary element containing a set of nozzles used to expand the working medium and direct it against the rotating blades.
Exhaust Ports Machine bosses on the compressor casing which extracts air for cooling and sealing.
Diffuser The section designed to increase the area of the flowpath to convert flow velocity to static fluid pressure.
Exhaust Pressure Drop
Exhaust duct losses.
Exhaust Stack The exhaust assembly which can include silencing sections.
Distance Piece A hollow cylindrical shaft used to couple the axial-flow compressor to the first stage turbine wheel.
Exit Guide Vanes Guide vanes at the exhaust end of the load turbine which direct the gas flow to the exhaust.
Eductor A device used for evacuating an enclosed space usually by means of air purge.
Expansion Joints expansion.
Electrostatic A device used for removing oil particles from an air/oilmixture using the charged particle Precipitator method.
Extraction Valves Devices used to assist in preventing compressor surge by allowing air to be extracted during off-design periods from an intermediate compressor stage.
Emergency Stop An immediate de-activation of the fuel system due to an emergency electrical or mechanical device or done manually.
Filters Components normally used to remove solid particulate matter in a given size range from an air/fluid supply and from lube oil.
Emergency Lube Oil Pump The back-up lube oil pump to the main pump. It uses the 125 Vdc battery to power the motor.
Fin Fan (Cooling Fan) A mechanically or electric motor driven air fan used tocool the water running through the radiators.
Evaporator Cooling Liquid (usually water) is added to an air supply, and the resultant evaporation cools the air mass and increases its mass per unit volume.
Firing Temp The temperature of the air mass at the inlet of the first stage turbine nozzle. Flame Detectors Sensors (usually ultraviolet) used to detect flame.
Exhaust Diffuser The component which slows the exhaust gas exit from the last turbine stage to recover energy, and reduce losses. GLOSSARY OF TERMINOLOGY
Devices that allow thermal
Flow Divider A device which distributers fuel flow equally to the fuel nozzles. 8
C00023
GE Power Systems Fluid gas.
A general term used to describe a liquid or
Heat Exchanger/Cooler The heat transfer equipment used to extract excessive heat from one working fluid and transmit it to another non-working fluid for eventual dissipation to the atmosphere.
Fuel Forwarding Skid The off-base pumping unit used to transfer, condition and control the flow of liquid fuel to the turbine.
Heat Rate The ratio of input energy to output energy (i.e. BTU/BHP-HR).
Fuel, Gas Either natural gas with a high heat content or manufactured gas.
Heat Recovery System The means of recovering heat which would otherwise be lost during the process.
Fuel, Light Distillate (Also known as No. 2 fuel.) A volatile distillate fuel having good combustion properties, clean burning and readily atomized. Preheating is usually not necessary.
Heating Value (i.e. BTU/lb.).
The heat content of a given fuel
High Pressure Turbine The first stage turbine (that drives the compressor on 2-shaft gas turbines).
Fuel Nozzle The device that injects fuel into the combustion chamber. Fuel Oil Stop Valve A spring-closed, hydraulically opened device used as a positive shutoff of liquid fuel.
Hot Gas Path A path of flow of the hot gases consisting of the combustion chambers, transition pieces, turbine nozzles and buckets, and the exhaust section.
Fuel Pump, Main The shaft driven, high pressure, liquid fuel pump.
Hydraulic Ratchet A form of turning gear which turns the rotor slightly at periodic intervals.
Fuel, Residual Low volatility petroleum products remaining at the end of a refinery distillation processes. All residual fuels require heating for pumping, filtering and proper air atomization at the fuel nozzle.
Inductor Alternator A permanent magnet type of AC generator connected to the compressor shaft. Inlet Guide Vane The guide vanes at the inlet to the compressor which direct and control the air flow to the first stage of the axial flow compressor.
Fuel Treatment The process of treating residual fuel to eliminate or inhibit contaminants.
Inlet Plenum An enclosed cavity that directs the inlet air to the gas turbine.
GAC Abbreviation for the Generator Auxiliary Compartment containing high voltage switch gear and excitation.
Inlet Pressure Drop (in inches of water).
Inlet Temperature The inlet air temperature to the gas turbine compressor.
Gib Block A steel block welded to the turbine base which has adjusting bolts for axial and transverse locating of the turbine. Provision is made for a gib key in the gib block.
Journal Bearing The part that supports the weight of the rotating shaft during normal operation. Labyrinth Packing A seal designed with multiple rows of (aluminum alloy) teeth located at the extremities of the bearing assemblies. Sealing air is circulated between the shaft and the seal to prevent oil from passing the seal and spreading along the shaft.
Gib Key The key for the gib block (i.e. described above). It is machined as an integral part of the lower half of the exhaust frame. Heat Consumption The heat consumed at rated output (i.e. BTU/hr.). C00023
The inlet duct pressure drop
9
GLOSSARY OF TERMINOLOGY
GE Power Systems Lagging The thermal and/or acoustic covering or enclosure.
Overspeed Bolt A spring loaded sliding rod, which is located in the accessory gear box monuted on the shaft connected to the turbine rotor, and mechanically senses a rotor overspeed condition and generates a trip independent of the electrical overspeed protection system.
Lifting Trunnion Extensions which are integrally cast as part of the casing and used to hold slings for lifting purposes.
Pad Support pads located on all base mounted assemblies.
Lighting Transformer A device usually associated with backfeeding the generator output of 13.8KV and reducing it to 480/V 3-phase. Load Shaft
Partition The airfoil shaped stator portion of the nozzle assembly.
The low pressure turbine shaft.
Peak Load The load reached at the peak exhaust temperature control setpoint (above the base load setpoint) which produces more power but reduces the life expectancy of the turbine parts.
Load Turbine Nozzle The variable angle nozzle between the high pressure and low pressure turbine wheels on 2-shaft turbines which is to aproportion energy distribution between the turbines. Low Pressure Turbine
Peak Reserve A short term rating (seldom used) for getting maximum power, recognizing that this drastically reduces the life of the hot section turbine parts.
The load turbine.
Lube Oil Header The main lube oil piping which feeds the turbine bearings, gears, coupling, etc.
Platform The portion of a turbine bucket between the airfoil shape and the shank.
LVDT Abbreviation for Linear Variable Differential Transformer.
Plenum An enclosure which contains a volume of air (i.e. inlet) or exhaust gas (i.e. exhaust).
Mist Eliminator A device which removes small oil droplets from the oil tank vent system prior to the discharge of the vapor in to the atmosphere. Model
Power Plant A comprehensive term for the components which are contained in an integrated power system.
Defines the gas turbine frame size.
Pre-cooler The air cooler upstream of the main atomizing air compressor.
Nozzle/Diaphragm Assembly A combination of the nozzle and the air control device between the turbine stages at the inner side wall.
Pre-selected Load An adjustable, pre-designated load point between spinning reserve and base load.
Nozzle Segment A small number of nozzle partitions made as an assembly: multiple assemblies will constitute a complete nozzle assembly.
Pressure Ratio The ratio of the compressor discharge pressure to the inlet pressure.
Off-Base A part which is not mounted on the accessory, turbine or generator base.
Pulsation Protection A mechanical network designed to prevent surge/pulsation during off-speed conditions of the compressor.
On-Base A part which is mounted on th accessory, turbine or generator base.
Pump, Centrifugal A non-positive displacement pump designed to use a rotor impeller in an enclosure as a means of transferring a fluid from one place to another.
Outer Combustion Casing A cover that provides a pressure vessel and an air flow path. GLOSSARY OF TERMINOLOGY
10
C00023
GE Power Systems Pump, Gear A positive displacement pump that consists of a drive gear and driven gear mounted in a housing. The working medium travels from the intake port around the outside of the gear to the outlet port.
Soleplates Individually grouted-in foundation plates used for mounting and supporting the pads of the gas turbine bases. Spinning Reserve The minimum load control point based on generator output.
Regenerative Cycle The working cycle which recovers a portion of the exhaust heat to reduce the cycle heat input required to read cycle operating temperatures. The working medium passes through compressor, regenerator, combustor, turbine and regenerator.
Stage The combination of one row of stator blades or nozzles with one row of rotor blades or buckets. Starting Clutch The (overrunning, hydraulically positioned jaw) clutch which connects the torque converter or turning gear output to the accessory gear box and disengages when the turbine reaches self-sustaining speed.
Regenerator A heat exchanger used to transfer heat from the exhaust gas to the working fluid before it enters the combustor.
Starting Device The machine part used to produce adequate torque for the starting system. Some types of starting devices are:
Rotor The rotating part of an assembly which is usually surrounded by a stator or stationary casing. RTD Abbreviation for a Resistance Temperature Detector.
1. Diesel Engine
SFC Specific fuel consumption (i.e. lbs/BHPHR) defined for a given fuel heating value.
3. Steam Turbine
Shaft Horsepower The power developed at the input or output shaft.
5. Turbine Impingement
2. Electric Motor 4. Natural Gas Expansion Turbine 6. Air motor
Shank The portion of a bucket between the platform and the dovetail.
Stator The stationary part of an assembly usually surrounding a rotating component or rotor.
Shroud A segmented part located adjacent to the blade tips which is used to limit the working fluid leakage.
Stub Shaft A hollow cylindrical section integral with the first stage compressor wheel. Thermocouple A pair of dissimilar metals joined in series to form a closed circuit, which will generate a thermo-electric current when heated.
Silencer A section of the inlet or exhaust of a gas turbine designed to reduce the sound level of air passing through it.
Thrust Bearing An active or inactive machine part which absorbs the axial thrust of the rotating shaft.
Simple Cycle A cycle where the working fluid passes directly through the compressor, combustor and turbine (without heating/cooling).
Tie Bolt A large bolt used to assemble the compressor rotor wheels.
Single Shaft Turbine A gas turbine whose rotating components, (compressor and turbine) are arranged on one shaft. C00023
Torque Converter A hydraulic device coupled to the turbine starting means which transfers and 11
GLOSSARY OF TERMINOLOGY
GE Power Systems amplifies torque causing turbine compressor shaft rotation during start up.
Valve, Relief A valve that automatically maintains a maximum, predetermined pressure by discharging or bypassing the fluid in a system.
Transition Piece A thin walled duct used to conduct the combustion gases from the circular combustion chambers to the annular turbine nozzle passage.
Valve, Servo A hydraulically powered valve with provisions for direct control (i.e. positioning) in direct relation with a primary control of a comparatively low level of force. Used for proportional control.
Turbine Stage A set of stationary nozzles and one row of moving buckets mounted on a wheel. The working medium expands through the stationary nozzle to a lower pressure causing kinetic energy to be transfered to the moving buckets.
Valve, Solenoid A valve specifically designed to control the flow of fluid by means of the magnetic action of an electric coil on a movable core or plunger, which actuates the valve stem or pilot needle. Used for on-off control.
Turbine Wheels Discs on the gas turbine shaft which are used to mount buckets on the wheel periphery.
Valve, Temp. Regulating A self-acting valve designed for controlling the flow of fluids via a thermostatic element located in the fluid.
Turning Gear The machine part which is used to break the turbine away while starting and rotate the shaft during cooldown and inspection.
Vane An airfoil used to direct the flow of air or gas. Water Removal Filter A device which removes suspended water from the lube oil.
Two-shaft Turbine A turbine arrangement where the high pressure and low pressure turbine stages are only coupled aerodynamically and run at different speeds.
Wheelspace Temperature The temperature of the air in close proximity to the surface of the turbine wheel below the platform surface of the turbine buckets.
Valve, Pressure Regulating A valve designed for continuous automatic control of pressure.
GE Power Systems Training General Electric Company One River Road Schenectady, NY 12345
GLOSSARY OF TERMINOLOGY
12
C00023
GEK 95149C Revised, June 2001
GE Power Systems Generator
International Conversion Tables Category ACCELERATION AREA
TORQUE
TORQUE/LENGTH
ELECTRICITY and MAGNETISM
ENERGY (Includes Work)
FORCE
FORCE/LENGTH
HEAT
LENGTH
To convert from Ft/sec2 . . . . . . . . . . . . . . . . . . . . . . . . In/sec2 . . . . . . . . . . . . . . . . . . . . . . . . Ft2 . . . . . . . . . . . . . . . . . . . . . . . . . . . In2 . . . . . . . . . . . . . . . . . . . . . . . . . . . dyne⋅cm . . . . . . . . . . . . . . . . . . . . . . . kilogram-force⋅meter . . . . . . . . . . . . lb-force⋅inch . . . . . . . . . . . . . . . . . . . lbf⋅foot . . . . . . . . . . . . . . . . . . . . . . . . ozf⋅foot . . . . . . . . . . . . . . . . . . . . . . . . lbf⋅ft/in . . . . . . . . . . . . . . . . . . . . . . . . lbf⋅in/in . . . . . . . . . . . . . . . . . . . . . . . . amp hr . . . . . . . . . . . . . . . . . . . . . . . . faraday (chem) . . . . . . . . . . . . . . . . . gauss . . . . . . . . . . . . . . . . . . . . . . . . . gilbert . . . . . . . . . . . . . . . . . . . . . . . . . maxwell . . . . . . . . . . . . . . . . . . . . . . . oersted . . . . . . . . . . . . . . . . . . . . . . . unit pole . . . . . . . . . . . . . . . . . . . . . . . Btu* . . . . . . . . . . . . . . . . . . . . . . . . . . ft⋅lb-force . . . . . . . . . . . . . . . . . . . . . . kilowatt hr . . . . . . . . . . . . . . . . . . . . . watt⋅sec . . . . . . . . . . . . . . . . . . . . . . . ft⋅poundal . . . . . . . . . . . . . . . . . . . . . kg-force . . . . . . . . . . . . . . . . . . . . . . . oz-force . . . . . . . . . . . . . . . . . . . . . . . lb-force . . . . . . . . . . . . . . . . . . . . . . . poundal . . . . . . . . . . . . . . . . . . . . . . . lb-force/in . . . . . . . . . . . . . . . . . . . . . lb-force/ft . . . . . . . . . . . . . . . . . . . . . . Btu* in/sec ft2 deg F . . . . . . . . . . . . Btu* in/hr ft2 deg F . . . . . . . . . . . . . . Btu* /ft2 . . . . . . . . . . . . . . . . . . . . . . . Btu* /hr ft2 deg F . . . . . . . . . . . . . . . Btu*/lbm deg F . . . . . . . . . . . . . . . . . Btu*/sec ft2 deg F . . . . . . . . . . . . . . cal/cm2 . . . . . . . . . . . . . . . . . . . . . . . cal/cm2 sec . . . . . . . . . . . . . . . . . . . . cal/cm sec deg C . . . . . . . . . . . . . . . cal*/g . . . . . . . . . . . . . . . . . . . . . . . . . cal*/g deg C . . . . . . . . . . . . . . . . . . .
To meter/sec2 . . . . . . . . . . . . . . . . . . meter/sec2 . . . . . . . . . . . . . . . . . . meter2 . . . . . . . . . . . . . . . . . . . . . meter2 . . . . . . . . . . . . . . . . . . . . . newton meter . . . . . . . . . . . . . . . newton meter . . . . . . . . . . . . . . . newton meter . . . . . . . . . . . . . . . newton meter . . . . . . . . . . . . . . . newton meter . . . . . . . . . . . . . . . newton m/m . . . . . . . . . . . . . . . . newton m/m . . . . . . . . . . . . . . . . coulomb . . . . . . . . . . . . . . . . . . . . coulomb . . . . . . . . . . . . . . . . . . . . tesla . . . . . . . . . . . . . . . . . . . . . . . amp-turn . . . . . . . . . . . . . . . . . . . weber . . . . . . . . . . . . . . . . . . . . . . amp/meter . . . . . . . . . . . . . . . . . . weber . . . . . . . . . . . . . . . . . . . . . . joule . . . . . . . . . . . . . . . . . . . . . . . joule . . . . . . . . . . . . . . . . . . . . . . . joule . . . . . . . . . . . . . . . . . . . . . . . joule . . . . . . . . . . . . . . . . . . . . . . . joule . . . . . . . . . . . . . . . . . . . . . . . newton . . . . . . . . . . . . . . . . . . . . . newton . . . . . . . . . . . . . . . . . . . . . newton . . . . . . . . . . . . . . . . . . . . . newton . . . . . . . . . . . . . . . . . . . . . newton/meter . . . . . . . . . . . . . . . newton/meter . . . . . . . . . . . . . . . watt/meter K . . . . . . . . . . . . . . . . water/meter K . . . . . . . . . . . . . . . joule/meter2 . . . . . . . . . . . . . . . . . joule/kg K . . . . . . . . . . . . . . . . . . . joule/kg K . . . . . . . . . . . . . . . . . . . watt/meter2 K . . . . . . . . . . . . . . . joule/meter2 . . . . . . . . . . . . . . . . . watt/meter2 . . . . . . . . . . . . . . . . . watt/meter K . . . . . . . . . . . . . . . . joule/kg . . . . . . . . . . . . . . . . . . . . joule/kg K . . . . . . . . . . . . . . . . . . .
Multiply by + 3.048 E-01 2.540 E–02 9.290 E–02 6.452 E–04 1.000 E-07 9.807 E+00 1.130 E-01 1.356 E+00 7.062 E-03 5.338 E+01 4.448 E+00 3.600 E+03 9.650 E+04 1.000 E–04 7.958 E–01 1.000 E–08 7.958 E+01 1.257 E–07 1.054 E+03 1.356 E+00 3.600 E+06 1.000 E+00 4.214 E–02 9.807 E+00 2.780 E–01 4.448 E+00 1.383 E–01 1.751 E+02 1.459 E+01 5.189 E+02 1.441 E–01 1.135 E+04 5.674 E+00 4.184 E+03 2.043 E+04 4.184 E+04 4.184 E+04 4.184 E+02 4.184 E+03 4.184 E+03
foot . . . . . . . . . . . . . . . . . . . . . . . . . . . inch . . . . . . . . . . . . . . . . . . . . . . . . . . foot . . . . . . . . . . . . . . . . . . . . . . . . . . inch . . . . . . . . . . . . . . . . . . . . . . . . . .
meter . . . . . . . . . . . . . . . . . . . . . . meter . . . . . . . . . . . . . . . . . . . . . . millimeter (mm) . . . . . . . . . . . . . . millimeter (mm) . . . . . . . . . . . . . .
3.048 E–01 2.540 E–02 3.048 E+02 25.40 E+00
+E Indicates the power of 10 by which the number must be multiplied, i.e., 4.047E+03 = 4.047 x 103. *Thermochemical
These instructions do not purport to cover all details or variations in equipment nor to provide for every possible contingency to be met in connection with installation, operation or maintenance. Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser’s purposes the matter should be referred to the GE Company. 1999 GENERAL ELECTRIC COMPANY
GEK 95149C Category
International Conversion Tables
To convert from To oz mass (av) . . . . . . . . . . . . . . . . . . . kilogram . . . . . . . . . . . . . . . . . . . . lb-mass (av) . . . . . . . . . . . . . . . . . . . kilogram . . . . . . . . . . . . . . . . . . . . MASS ton (2000 lbm) . . . . . . . . . . . . . . . . . kilogram . . . . . . . . . . . . . . . . . . . . lbm/ft3 . . . . . . . . . . . . . . . . . . . . . . . . kilogram/meter3 . . . . . . . . . . . . . 3 . . . . . . . . . . . . . . . . . . . . . . . . kilogram/meter3 . . . . . . . . . . . . . lbm/in MASS/VOLUME oz-mass (av)/in3 . . . . . . . . . . . . . . . . kilogram/meter3 . . . . . . . . . . . . . (Includes Density) lb-mass (av)/gal . . . . . . . . . . . . . . . . kilogram/meter3 . . . . . . . . . . . . . g/cm3 . . . . . . . . . . . . . . . . . . . . . . . . . kilogram/meter3 . . . . . . . . . . . . . Btu*/sec . . . . . . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . Btu*/min . . . . . . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . Btu*/hr . . . . . . . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . Cal*/sec . . . . . . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . Cal*/min . . . . . . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . POWER ft⋅lb force/hr . . . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . ft⋅lb force/min . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . ft⋅lb force/sec . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . hp (elec) . . . . . . . . . . . . . . . . . . . . . . watt . . . . . . . . . . . . . . . . . . . . . . . . atm (760 Torr) . . . . . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . bar . . . . . . . . . . . . . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . dyne/cm2 . . . . . . . . . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . gram (force)/cm2 . . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . in of Hg (60 F) . . . . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . PRESSURE in of water (60 F) . . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . (Force/Area) lb-force/ft2 . . . . . . . . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . lbf/ft2 . . . . . . . . . . . . . . . . . . . . . . . . . kg/m2 . . . . . . . . . . . . . . . . . . . . . . lbf/in2 (psi) . . . . . . . . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . lbf/in2 . . . . . . . . . . . . . . . . . . . . . . . . . kg/cm2 . . . . . . . . . . . . . . . . . . . . . Torr (mm Hg, 0 C) . . . . . . . . . . . . . . pascal . . . . . . . . . . . . . . . . . . . . . degree Celsius (°C) . . . . . . . . . . . . . degree Kelvin (K) . . . . . . . . . . . . TEMPERATURE degree Farenheit (°F) . . . . . . . . . . . degree Celsius . . . . . . . . . . . . . . degree Celsius . . . . . . . . . . . . . . . . . degree Farenheit . . . . . . . . . . . . ft/hr . . . . . . . . . . . . . . . . . . . . . . . . . . meter/sec . . . . . . . . . . . . . . . . . . . ft/min . . . . . . . . . . . . . . . . . . . . . . . . . meter/sec . . . . . . . . . . . . . . . . . . . VELOCITY ft/sec . . . . . . . . . . . . . . . . . . . . . . . . . meter/sec . . . . . . . . . . . . . . . . . . . (Includes Speed) in/sec . . . . . . . . . . . . . . . . . . . . . . . . . meter/sec . . . . . . . . . . . . . . . . . . . ft2/sec . . . . . . . . . . . . . . . . . . . . . . . . meter2/sec . . . . . . . . . . . . . . . . . . lbm/ft sec . . . . . . . . . . . . . . . . . . . . . . pascal–sec . . . . . . . . . . . . . . . . . VISCOSITY lbf sec/ft2 . . . . . . . . . . . . . . . . . . . . . . pascal–sec . . . . . . . . . . . . . . . . . ft3 . . . . . . . . . . . . . . . . . . . . . . . . . . . meter3 . . . . . . . . . . . . . . . . . . . . . gallon (US) . . . . . . . . . . . . . . . . . . . . meter3 . . . . . . . . . . . . . . . . . . . . . VOLUME 3 . . . . . . . . . . . . . . . . . . . . . . . . . meter3 . . . . . . . . . . . . . . . . . . . . . inch (Includes Capacity) liter . . . . . . . . . . . . . . . . . . . . . . . . . . meter3 . . . . . . . . . . . . . . . . . . . . . oz (US fluid) . . . . . . . . . . . . . . . . . . . meter3 . . . . . . . . . . . . . . . . . . . . . ft3/min . . . . . . . . . . . . . . . . . . . . . . . . meter3/sec . . . . . . . . . . . . . . . . . . ft3/sec . . . . . . . . . . . . . . . . . . . . . . . . meter3/sec . . . . . . . . . . . . . . . . . . VOLUME/TIME in3/min . . . . . . . . . . . . . . . . . . . . . . . . meter3/sec . . . . . . . . . . . . . . . . . . (Includes Flow) gal/min . . . . . . . . . . . . . . . . . . . . . . . . meter3/sec . . . . . . . . . . . . . . . . . . +E Indicates the power of 10 by which the number must be multiplied, i.e., 4.047E+03 = 4.047 x 103. *Thermochemical
Multiply by + 2.835 E–02 4.536 E–01 9.072 E+02 1.602 E+01 2.768 E+04 1.730 E+03 1.198 E+02 1.000 E+03 1.054 E+03 1.757 E+01 2.929 E–01 4.184 E+00 6.973 E–02 3.766 E–04 2.260 E–02 1.356 E+00 7.460 E+02 1.013 E+05 1.000 E+05 1.000 E–01 9.807 E+01 3.377 E+03 2.488 E+02 4.788 E+01 4.882 E+00 6.895 E+03 7.037 E–02 1.333 E+02 TK = tC + 273.15 tC = (tF - 32)/1.8 tF = (tC ⋅ 1.8)+32 8.467 E–05 5.080 E–03 3.048 E–01 2.540 E–02 9.290 E–02 1.488 E+00 4.788 E+01 2.832 E–02 3.785 E–03 1.639 E–05 1.000 E–03 2.957 E–05 4.719 E–04 2.832 E–02 2.731 E–07 6.309 E–05
GE Power Systems General Electric Company One River Road, Schenectady, NY 12345 518 • 385 • 2211 TX: 145354
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/3
DESCRIPTION
LUBRICATING OIL SYSTEM 1
DEFINITION
The lube oil system is designed for insuring the following functions : • • • •
To lubricate the shaft line including the accessory gear box To provide oil for the Hydraulic system To provide oil for the Trip oil system To provide oil for the torque converter
The lubricating oil system is a close loop where oil flow is built up from the oil tank located in the lower part of the accessory base by : • A shaft driven main pump • An Alternative Current motor driven auxiliary pump for starting and shutdown sequences • A Direct Current motor driven emergency pump for emergency shutdown Lubricating oil conditioning includes : • • • • •
Oil tank warming up to keep acceptable oil viscosity while the unit is at standstill Oil flow cooling down to evacuate heat from the bearings Oil flow filtering Oil Header Pressure regulating at constant pressure Oil mist elimination
Bearings feeding and return lines are concentric lines, feeding line is installed in return line. The lubricating oil flows back in the tank by gravity. Part of the gas turbine bearing sealing air provided by the compressor returns with the oil in the oil tank and is evacuated to the atmosphere through the oil mist eliminator. Oil mist elimination consist of two redundant assembly. 2
COMPONENT FUNCTION
23QA-1
Prevents motor from internal condensation while not running.
23QT-1
Warms up the lube oil.
23QV-1
Prevents motor from internal condensation while not running.
23QV-2
Prevents motor from internal condensation while not running.
63QA-2
Detects the low lube oil pressure.
63QQ-1
Detects the clogging of lube oil filter.
63QQ-8
Detects the clogging of the filter.
All right reserved Copyright – Droits de reproduction réservés OMMD_0416_9E_E0601_EN Revision : A
Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
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DESCRIPTION
63QQ-10
Detects low performance of oil mist eliminator.
63QT-2A
Detects the low lube oil pressure.
88QA-1
Drives the auxiliary lube oil pump .
88QE-1
Drives the emergency lube oil pump.
88QV-1
Drives the oil mist eliminator fan.
88QV-2
Drives the oil mist eliminator fan.
96QA-2
Measures the lube oil pressure.
96QL-1
Measures the lube oil level tank.
96QT-2B
Measures the lube oil pressure.
96QV-1
Measures the air pressure in the lube oil tank.
LT-B1D-1
Measures the lube oil #1 bearing drain temperature.
LT-B2D-1
Measures the lube oil #2 bearing drain temperature.
LT-B3D-1
Measures the lube oil #3 bearing drain temperature.
LT-BT1D-1
Measures the lube oil #1 bearing drain temperature.
LT-G1D-1
Measures the lube oil #1 generator bearing drain temperature.
LT-G2D-1
Measures the lube oil #2 generator bearing drain temperature.
LT-OT-1A
Measures the lube oil temperature in the tank.
LT-OT-2A
Measures the lube oil temperature in the tank.
LT-TH-1A,1B
Measures the lube oil header temperature.
LT-TH-2A,2B
Measures the lube oil header temperature.
LT-TH-3A,3B
Measures the lube oil header temperature.
VCK20-1
Prohibits air recirculation.
VCK20-2
Allows maintenance activity while GT running.
VCK20-3
Prohibits air recirculation.
VCK20-2
Allows maintenance activity while GT running.
VCK20-12
Allows maintenance activity while GT running.
All right reserved Copyright – Droits de reproduction réservés OMMD_0416_9E_E0601_EN Revision : A
Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 3/3
DESCRIPTION
VCK20-13
Regulates the oil tank vacuum pressure.
VPR2-1
Regulates the lube oil header pressure.
VR1
Protects the lube oil system against overpressure.
3
ADDITIONAL INFORMATION
Lubricating oil heater : When the heater is heating, starting manually or not, the auxiliary lube oil pump is running automatically Auxiliary and emergency pump test : A test valve associated with a push button valve connected upstream the VPR2-1 regulating valve allows testing sequence of both pumps while the gas turbine is running. When the test is completed and the test valve closed, auxiliary pump stops automatically, the emergency pump needs a stop order at the MCC panel to stop. The auxiliary and emergency pump test must be demonstrated once a month. Emergency oil pump – Loss of AC power : The emergency lube oil pump starts automatically only during loss of AC power at the shaft line run down. Run down may be resulting of normal or emergency shut down or loss of turning gear sequence. If loss of AC power remains after complete shaft stop, the emergency oil pump runs three minutes every fifteen minutes to cool down the bearings until AC power comes back. Refer to Special sequences. Oil sampling : Two valves connected both sides of the filter allows filtered oil and not filtered oil sampling. Oil characteristics must be checked once every three months. Oil flowing : Sight glasses are fitted at filter vent, cooler vent, bearing return lines. They allow the operator to check oil flowing, especially after manual operation related to those components. Oil characteristics : Lubricating oil characteristics must comply to GEK 32568.
All right reserved Copyright – Droits de reproduction réservés OMMD_0416_9E_E0601_EN Revision : A
Date : 01/2007
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DESCRIPTION
HYDRAULIC SUPPLY SYSTEM 1
DEFINITION
The hydraulic supply system is designed to provide high pressure oil at constant pressure to control : • • •
The gas fuel flow and gas fuel pressure regulating valves The liquid fuel bypass regulating valve and stop valve The compressor inlet guide vanes
The hydraulic supply system is a closed loop where the oil pressure is built up from lubricating oil header by : • •
A shaft driven main pump. An electrical motor driven auxiliary pump for starting and shut down sequences
Hydraulic oil supply conditioning includes : • • •
Automatic purging Dual filtering Accumulator
Hydraulic oil flows back to the lubricating oil tank by gravity. 2
COMPONENT FUNCTION
23HQ-1
Prevents motor from internal condensation while not running.
63HF-1
Detects the clogging of the filter.
63HQ-1
Detects the low hydraulic oil pressure.
88HQ-1
Drives the hydraulic supply oil pump.
AH1-1
Absorbs and compensates the pressure variation.
FH2-1
Filters the hydraulic supply oil.
FH2-2
Filters the hydraulic supply oil.
PH1
Provides main hydraulic supply.
PH2
Provides auxiliary hydraulic supply.
VAB1
Purge automatically the main hydraulic pump circuit.
All right reserved Copyright – Droits de reproduction réservés OMMD_0434_9E_E0601_EN Revision : A
Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 2/2
DESCRIPTION
VAB2
Purge automatically the auxiliary hydraulic pump circuit.
VCK3-1
Prohibits the return of the main pump oil flow.
VCK3-2
Prohibits the return of the auxiliary pump oil flow.
VM4
Allows manual filter transfer.
VPR3-1
Regulates the HP pump oil pressure.
VR21
Protects system against overpressure.
VR22
Adjusts the pump outlet pressure.
3
ADDITIONAL INFORMATION
Auxiliary pump safety valve : The safety valve of the auxiliary pump regulates the hydraulic pressure during start up and shut down sequence. It is normal to find an oil flow at the outlet of this safety valve.
All right reserved Copyright – Droits de reproduction réservés OMMD_0434_9E_E0601_EN Revision : A
Date : 01/2007
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
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DESCRIPTION
INLET GUIDE VANES SYSTEM 1
DEFINITION
The inlet guide vanes system is designed to adjust the compressor airflow according to compressor and combustion needs. The compressor inlet guide vanes system is actuated with hydraulic supply. The oil returns to the lubricating oil tank by gravity. 2
COMPONENT FUNCTION
20TV-1
Allows oil supply feeding of IGV.
90TV-1
Controls the IGV position.
96TV-1
Measures the IGV angle.
96TV-2
Measures the IGV angle.
FH6-1
Filters the hydraulic supply oil.
HM3-1
Represents the IGV assembly.
VH3-1A
Controls the operation of IGV .
VH3-1B
Controls the operation of IGV .
3
ADDITIONAL INFORMATION
None.
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Date : 01/2007
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
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DESCRIPTION
COOLING & SEALING AIR SYSTEM 1
DEFINITION
The cooling & sealing air system is designed for insuring the following functions : • • • • • • • •
To cool down the turbine exhaust frame and turbine casing To cool down the turbine stage nozzle To provide gas turbine bearing’s sealing air To protect the compressor during starting and shut down sequences To measure the compressor discharge pressure To provide instrument air or air supply for other systems To cool down the third bearing vibration sensors To purge gas fuel or liquid fuel or water injection lines when they are not used
The cooling & sealing air system is an open loop where : •
• 2
The cooling air for the turbine exhaust frame and for the turbine casing is provided by two electrically driven blowers. Cooling air is then evacuated through the # 3 bearing tunnel for the exhaust frame cooling and inside the turbine enclosure for the cooling of turbine casing. Each blower delivers 50% of the requested cooling flow. The gas turbine bearing sealing air from the compressor flows back in the oil tank and is evacuated through the oil mist eliminator vent. COMPONENT FUNCTION
20CB-1
Controls the bleed valves.
23TK-1
Prevents motor from internal condensation while not running.
23TK-2
Prevents motor from internal condensation while not running.
33CB-1
Indicates the valve open position.
33CB-2
Indicates the valve open position.
33CB-3
Indicates the valve open position.
33CB-4
Indicates the valve open position.
63TK-1
Detects the blower outlet pressure.
63TK-2
Detects the blower outlet pressure.
88TK-1
Drives the fan.
88TK-2
Drives the fan.
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Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 2/2
DESCRIPTION
96CD-1A
Measures the compressor discharge pressure.
96CD-1B
Measures the compressor discharge pressure.
96CD-1C
Measures the compressor discharge pressure.
VA2-1
Connects the compressor concerned stage at atmospheric pressure.
VA2-2
Connects the compressor concerned stage at atmospheric pressure.
VA2-3
Connects the compressor concerned stage at atmospheric pressure.
VA2-4
Connects the compressor concerned stage at atmospheric pressure.
VCK7-1
Prohibits the running blower air flow to return in the stand by blower.
VCK7-2
Prohibits the running blower air flow to return in the stand by blower.
3
ADDITIONAL INFORMATION
Compressor bleed valves : The four compressor bleed valves remain open during start up and shut down sequences to protect the compressor from surging. A position fault, indicated by the Speedtronic®, must be analyzed and rectified before the next starting sequence. Turbine exhaust frame cooling : Cooling down is achieved by two blowers, each one providing 50% of air flow. If one blower fails, the unit is able to run with a load limited by the gas turbine third bearing tunnel temperature.
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Date : 01/2007
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/2
DESCRIPTION
ATOMIZING AIR SYSTEM 1
DEFINITION
Atomization is the process whereby a volume of liquid is converted into a multiplicity of very small droplet by air stream. The atomizing air system is designed for insuring the following functions : • •
To atomize the liquid fuel To purge the liquid fuel lines when the gas turbine burns gas fuel
The atomizing air system is an open loop where the air from the axial compressor is cooled down and then pressurized by the shaft driven main compressor. An electrical motor driven booster built up the atomizing air pressure during starting sequence. The atomizing air system includes a piloted bypass valve to adapt atomizing air pressure and flow according to liquid or gas fuel burning conditions. 2
COMPONENT FUNCTION
20AA-1
Controls the VA18 valve.
20AB-1
Controls the VA22 valve.
23AB-1
Prevents motor from internal condensation while not running.
88AB-1
Drives the AA booster.
96AD-1
Measures the AA compressor differential pressure.
AAT-1A
Measures the inlet air temperature of main atomizing air compressor CA1.
AAT-2A
Measures the inlet air temperature of main atomizing air compressor CA1.
CA1
Provides atomizing air.
CA2
Provides atomizing air during starting sequence.
FA4-1
Filters the control air.
HX1-1
Cools down the atomizing air.
VA18-1
Lowers the main compressor pressure ratio.
VA22-1
Cuts off the booster while the unit is at full speed.
VPR68-1
Regulates the air pressure.
All right reserved Copyright – Droits de reproduction réservés OMMD_0425_9E_E0601_EN Revision : A
Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 2/2
DESCRIPTION
3
ADDITIONAL INFORMATION
Permanent purging : Permanent atomizing air purging is provided through small orifices and silencers at compressor upstream. Air ejector : An air ejector installed on the top of the accessory gear box receives air flow from the atomizing air system to create a gear box vacuum pressure. Compressor washing : Manual valves are provided to isolate atomizing air lines during compressor Off line washing sequence.
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/2
DESCRIPTION
FUEL PURGE SYSTEM 1
DEFINITION
The fuel purge system is designed to purge : • •
The liquid fuel lines when the unit is running with gas fuel The gas fuel lines when the unit is running with liquid fuel
The fuel purge system is an open loop where : •
•
Purging air flow for liquid fuel lines is provided by atomizing air system through a three ways control valve Purging air flow for gas line is provided from the axial compressor through two purging valves installed in serial to guaranty gas tightness Control air is provided by atomizing air and axial compressor
2
COMPONENT FUNCTION
•
20PG-1
Controls the VA13-1 valve.
20PG-2
Controls the VA13-2 valve.
20PL-1
Controls the VA19-1 valve.
20VG-2
Vents the VA13 inter-valve space.
33PG-1
Indicates Valve VA13-1 Close Position.
33PG-2
Indicates Valve VA13-1 open Position.
33PG-3
Indicates Valve VA13-2 closed Position.
33PG-4
Indicates Valve VA13-2 open Position.
63PG-1
Detects the pressure of VA13-1 and VA13-2 inter-valves cavity.
63PL-21
Detects the low nozzle air purge pressure.
FA3-1
Filters the purge air.
VA13-1
Allows gas system purging.
VA13-2
Allows gas system purging.
VA19-1
Allows liquid fuel system purging.
VA36-1
Allows slow opening time and fast closing time for VA13-1 valve.
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Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 2/2
DESCRIPTION
VA36-2
Allows slow opening time and fast closing time for VA13-2 valve.
VCK2-1T14
Prohibits liquid fuel to return in purge line.
VPR44-1
Regulates the air pressure.
VPR44-2
Regulates the air pressure.
VPR54-1
Regulates the air pressure.
3
ADDITIONAL INFORMATION
Telltale leak-off : A telltale leak-off allows the operator the check liquid fuel leaks when the gas turbine is operating with liquid fuel. Liquid fuel leaks at this level represents a VCK2 defect and must be investigated and corrected quickly. Gas fuel purge : When the gas turbine is operating with gas fuel the two purge valves are closed and the solenoid valve in between the two gas purge valves is open. A pressure switch detects any built up pressure due to a tightness seal defect. In this event, corrective action must be undertaken quickly.
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/2
DESCRIPTION
GAS FUEL SYSTEM 1
DEFINITION
The gas fuel system providing gas fuel for the combustion chambers is designed for insuring the following functions : • • • •
To fire, warm up and accelerate the unit up to nominal speed To power the unit up to base load To shut down and trip the unit To measure the gas flow
The gas fuel system is an open loop including : • • • • • •
A speed/stop ratio valve to adjust the gas pressure versus the gas turbine speed and to stop the unit A control valve to adjust the gas flow Temporary filters for first commissioning and permanent filters Piloted inter-valves venting system A gas flow meter Hydraulic accumulator
2
COMPONENT FUNCTION
20FGC-1
Controls the gas valve.
20FGS-1
Controls the operation of VSR valve.
20VG-1
Vents the inter-valve space.
33VG-11
Indicates the vent valve closed position.
63FG-1
Detects a low gas supply pressure.
63FG-2
Detects a low gas supply pressure.
65GC
Controls the valve position.
90SR-1
Controls the valve position.
96FG-1
Measures the gas inlet pressure.
96FG-2A
Measures the inter-valve gas pressure.
96FG-2B
Measures the inter-valve gas pressure.
96FG-2C
Measures the inter-valve gas pressure.
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Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 2/2
DESCRIPTION
96GC-1,2
Measures the valve stroke.
96SR-1,2
Measures the valve stroke.
96VM-1
Measures the gas flow.
AH1-3
Absorbs and compensates the pressure variation.
FH7-1
Filters the hydraulic supply oil.
FH8-1
Filters the hydraulic supply oil.
MG1
Represents the gas nozzles.
VGC-1
Regulates the gas flow.
VH5-1
Controls the operation of VSR valve.
VH5-2
Controls the operation of VGC valve.
VM-1
Measures the gas fuel mass flow upstream VSR.
VSR-1
Adjusts the gas pressure and cuts off the gas flow for shut down sequence.
3
ADDITIONAL INFORMATION
Gas : The gas system as well as the control’s parameters are calculated according to the gas composition included in the Control Specification. Gas calorific value, gas density and gas temperature at the gas turbine inlet piping are corresponding to a Wobbe index. Wobbe index must remain within ± 5% of contractual Wobbe index to guaranty reliable operation of the gas turbine.
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : B Page : 1/3
DESCRIPTION
LIQUID FUEL SYSTEM 1
DEFINITION
The liquid fuel system providing liquid fuel for the combustion chambers is designed for insuring the following functions : • • •
Fire, warm up and accelerate the unit up to nominal speed Power the unit up to base load Shut down and trip the unit
The liquid fuel system is an open loop including : • • • • • • • •
A safety valve to stop the fuel flow A shaft driven main fuel pump A control valve to adjust the fuel flow by bypassing the main fuel pump An electrical clutch to drive the main fuel pump High pressure filters A flow divider to distribute equal flow in each combustion chamber Purge valves to drain with distillate the remaining heavy fuel after a gas turbine trip Turbine casing and exhaust casing drain valves to drain the unburned liquid fuel at false starts
Due to liquid fuel characteristics, the liquid fuel pump is lubricated by a separate system from the gas turbine lubricating oil, including : • • • • •
A lubricating oil tank One AC driven lubricating oil pump One DC driven lubricating pump One cooler Dual filters
2
COMPONENT FUNCTION
20CF-1
Controls the fuel pump clutch.
20FL-1
Controls the liquid fuel stop valve.
20PF-100
Controls the multi-port valve VP1/VP2.
33FL-1
Indicates the closed position of the liquid fuel stop valve.
33PF-1
Indicates the valve closed position.
33PF-2
Indicates the valve closed position.
63LF-3
Detects the clogging of the filter.
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Date : 02/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
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DESCRIPTION
65FP
Controls the bypass valve position.
77FD-1
Measures FD1-1 speed.
77FD-2
Measures FD1-1 speed.
77FD-3
Measures FD1-1 speed.
88FM
Starts the flow divider.
96FL-2A
Measures liquid fuel module inlet pressure.
96FL-2B
Measures liquid fuel module inlet pressure.
96FP-1
Measures the bypass control valve position.
96FP-2
Measures the bypass control valve position.
FD1-1
Splits the liquid fuel into equal flow for each combustion chamber.
FF2-1
Filters the liquid fuel flow at flow divider upstream .
FF2-2
Filters the liquid fuel flow at flow divider upstream .
FH3
Filters the hydraulic supply oil.
PF1
Provides the liquid fuel pressure.
VA17-1
Drains out the liquids.
VA17-2
Drains out the liquids.
VA17-5
Drains out the liquids.
VC3
Regulates the liquid fuel flow.
VCK1-1T14
Prohibits the air or liquid fuel flow to return in the line and prohibits normal liquid fuel flow to enter the combustion chamber at low pressure.
VP-1
Allows drainage of liquid fuel flow.
VP-2
Allows drainage of liquid fuel flow.
VR27
Protects system against overpressure.
VR4
Protects the fuel pump against overpressure.
VS1
Cuts off the liquid fuel flow.
All right reserved Copyright – Droits de reproduction réservés OMMD_0424_9E_E0601_EN Revision : B
Date : 02/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : B Page : 3/3
DESCRIPTION
3
ADDITIONAL INFORMATION
Nozzle pressure : A manual selector is provided to measure individual nozzle pressure. The maximum allowed pressure spread between the nozzles cannot exceed 10 bars. High spread configuration must be analyzed and rectified urgently. Purge valve : The gas turbine cannot be fired with heavy fuel. A set of purge valves is installed to drain the remaining heavy fuel after a gas turbine trip on load with heavy fuel. The purge sequence is initiated automatically straight away after a trip and is completed when the fuel line contains 100% of distillate. A sight glass allows visual flow check.
All right reserved Copyright – Droits de reproduction réservés OMMD_0424_9E_E0601_EN Revision : B
Date : 02/2007
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Servovalve Overview Moog CONTROLS
TORQUE MOTOR
COILS TOP POLE PIECE
PERMANENT MAGNET
ARMATURE FLAPPER MOTOR SHIM
FLEXURE SLEEVE
FILTER
NOZZLE
BOTTOM POLE PIECE
ORIFICE, INLET
FEEDBACK SPRING
SPOOL STOP
BUSHING (SLEEVE)
SPOOL (SLIDE) ORIFICE, RETURN
END CAP
1350 PSI DRAIN BODY (HOUSING)
LVDT
TO < RST >
MOOG2 9/97
SUPPLY PRESSURE
CONTROL PORT PRESSURES
FILTERED 1st STAGE SUPPLY PRESSURE
RETURN PRESSURE
1st STAGE CONTROL PRESSURE
INTERNAL DRAIN PRESSURE
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/3
DESCRIPTION
ADDITIVE INJECTION SKID 1
DEFINITION
The vanadium inhibitor injection system is designed to inject additive product in the liquid fuel system. The vanadium inhibitor injection system includes : • • • • • • •
A tank forwarding pump A vanadium inhibitor main tank A small capacity storage buffer tank A strainer A set of two electrically driven dosing pumps, rated 100% each A flow meter A manual valve to measure the vanadium inhibitor flow
The cycle of the vanadium inhibitor is as follow : • • • • •
Delivered at site in drums, Transferred from drums to the main tank manually using the forwarding pump, Circulating by gravity from main tank to buffer tank Feeding the dosing pump from buffer tank Injected in the gas turbine liquid fuel system at filtering skid level
2
COMPONENT FUNCTION
20IA-11
Controls the VA99-12 valve.
63AF-11
Detects the pressure in the circuit.
71FA-11
Detects super lubricant low level.
71FA-12
Detects super lubricant level.
88FA-10
Drives the unloading pump.
88FA-11
Drives the dosing pump.
88FA-12
Drives the dosing pump.
FF11-1
Filters the super lubricant.
FF11-2
Filters the super lubricant.
PFA-10
Allows tank feeding.
All right reserved Copyright – Droits de reproduction réservés OMMD_0494_9E_E0601_EN Revision : A
Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
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DESCRIPTION
PFA-11
Feeds the fuel system with the additive product.
PFA-12
Feeds the fuel system with the additive product.
PSV-11
Protects the tank against overpressure.
VA99-11
Is used with VA99-13 valve to manually adjust the flow of the pump.
VA99-12
Is used to fill up the buffer tank.
VA99-13
Is used with VA99-11 valve to manually adjust the flow of the pump.
VPR30-11
Regulates the control air pressure.
VR60-11
Protects system against overpressure.
VR60-12
Protects system against overpressure.
3
ADDITIONAL INFORMATION
Vanadium inhibitor flow : Vanadium inhibitor requested flow depends of the characteristics of the liquid fuel and the inhibitor used. The general formula is Q additive (Liter/h) = [ ρadditive (kg/L) × Q fuel (kg/h) × (3V(PPM)+Ni+Zn/2)] [106 × Mgadditive Concentration] ρadditive is the density of the vanadium inhibitor in kg/liter Q fuel is the nominal liquid fuel flow of the gas turbine in kg/hour V is the vanadium content in the liquid fuel in ppm Ni is the Nickel content in the liquid fuel in ppm Zn is the Zinc content in the liquid fuel in ppm Vanadium inhibitor flow manual measurement : A manual valve is provided to proceed to flow measurement. Once this valve is depressed, the main and the buffer tanks are isolated and the dosing pump feeds up from the vertical piping installed in between the two tanks. A pressure gage scaled in meter show the consummated volume. Using a stopwatch during the test allows the operator to calculate the flow. For this 11.3 mm diameter vertical piping. The formula is : Flow in liter/hour = (3.601 x ∆P) / t ∆P is the level difference in the vertical pipe given by the pressure gage scaled in meter t is the time corresponding to ∆P Note : the duration of this test cannot be higher than 15 sec, due to the small capacity of the vertical piping
All right reserved Copyright – Droits de reproduction réservés OMMD_0494_9E_E0601_EN Revision : A
Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 3/3
DESCRIPTION
The additive product flow can be adjusted by acting on the vernier (the vernier allowing the adjustment of the dosing pump flow must be on the hold% position). Vanadium inhibitor characteristics: GE recommend to use the following product : • BAKER PETROLITE KI200 or KI110 • TURBOTECT T134 or T131 Other product must comply with GEK 28150 and be approved by GE.
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/1
DESCRIPTION
COOLING WATER SYSTEM 1
DEFINITION
The cooling water system is designed for insuring cooling down of : • • • • •
The lubricating oil The atomizing air system The flame detectors The turbine supports The liquid fuel shaft driven pump
The above equipment are part of the installation’s cooling water closed loop. 2
COMPONENT FUNCTION
VTR1
Prohibits water circulation in the cooler for low oil temperature.
VTR2-1
Prohibits water circulation in the cooler for low air temperature.
WT-TL-1
Measures the water temperature of the Turbine supports.
WT-TL-2
Measures the water temperature of the Turbine supports.
3
ADDITIONAL INFORMATION
Cooling water characteristics : Cooling water characteristics must comply to GEI 41004H Lubricating oil temperature : During gas turbine operation the lubricating oil temperature is between 49°C and 70°C (120°F – 158°F) according to the water flow through the heat exchanger and the site ambient air temperature.
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Date : 01/2007
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/1
DESCRIPTION
TURBINE AND/OR COMPRESSOR WASHING SYSTEM 1
DEFINITION
The compressor washing system is designed for insuring the following functions : • •
To clean the compressor at stand still (Off line) To clean the compressor at nominal speed (On line)
A module not included in this chapter provides the clean washing water flow. 2
COMPONENT FUNCTION
20TW-1
Controls the water flow for compressor washing.
20TW-3
Controls the water flow for compressor washing.
43TW-1/PB
Controls the 20TW-1 valve.
71FF-4
Detects flange leakage.
71FF-5
Detects flange leakage.
71FF-6
Detects flange leakage.
VA17-1
Drains out the liquids.
VA17-2
Drains out the liquids.
VA17-5
Drains out the liquids.
3
ADDITIONAL INFORMATION
On line water wash : During On line water wash with the shaft line at nominal speed the water is evacuated with gas turbine exhaust gas. Off line water wash : Off line water wash is carried out when the unit is cold and needs manual configuration for water wash valves. Please refer to the maintenance manual. Water characteristics : The washing water must comply to GEI 41042
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Date : 01/2007
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GEK 110220b Revised March 2004
GE Energy
Gas Turbine Compressor Water Wash System
These instructions do not purport to cover all details or variations in equipment nor to provide for every possible contingency to be met in connection with installation, operation or maintenance. Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser's purposes the matter should be referred to the GE Company. © 2002 General Electric Company
GEK 110220b
Gas Turbine Compressor Water Wash System
I. GENERAL Gas turbines can experience a loss of performance during operation as result of deposits of contaminants on internal components. This loss is indicated by a decrease in power output and an increase in heat rate. The deposits of atmospheric contaminants on compressor parts occurs with the ingestion of air. The ingested air may contain dirt, dust, insects, and hydrocarbon fumes. A large portion of these can be removed before they get to the compressor by inlet air filtration. The dry contaminants that pass through the filters as well as wet contaminants, such as hydrocarbon fumes, have to be removed from the compressor by washing with a water-detergent solution followed by a water rinse. A. On-Base Supplied Equipment The on-base turbine equipment supplied with this compressor wash system consists of piping from the purchaser's connection on the base, air operated water injection valve(s), and the appropriate spray manifold(s). Drains from the inlet plenum, combustion area, exhaust frame, and the exhaust plenum are also provided. The new false drain system includes a pneumatically operated FSD valves with limit switches for position detection. These new valves shall use customer supplied instrument air and therefore require solenoid activation. The system also utilizes an RTD (Resistive Thermal Device) for measuring temperatures inside the FSD piping arrangement. This same piping serves dual functions of removal of fuel oil during false starts and/or removal of water during off-line water washes. The schematic for this on-base water wash equipment is located in the Reference Drawing sections of this manual. B. Off-Base Equipment The off-base portion of the water wash system, known as the water wash skid, contains both a water tank and a detergent tank. The water tank is equipped with temperature sensors and electric heaters to maintain proper water temperatures. The skid is equipped with a centrifugal water pump motor (88TW-1) and a venturi used with the water pump to mix detergent solution. Also included on the skid are the various control panels to initiate wash and to manually start/stop the appropriate devices. All equipment is made of corrosion resistant material. The schematic for the water wash skid is included in the Reference Drawings section of this manual. All devices are set to give proper temperature, pressure, and flow. The settings for these devices can be found in the device summary for the corresponding system. C. Functional Description During the washing operation, water or wash solution is delivered through customer piping to the gas turbine in the proper mix ratio. The wash water solution is delivered to the turbine unit at the proper pressure, temperature, and flow rate to wash the gas turbine compressor. Refer to the system schematic in the Reference Drawing section for proper pressure(s), temperature(s), and flow rate(s) for this gas turbine. 1.
2
Water used for washing turbine parts should be reasonably clean so that it does not cause fouling or corrosion in itself. Distilled or deionized water is recommended. Water quality requirements are listed in Table 1 of GEK-107122 (Latest Revision). Oily or varnished oil deposits on internal
Gas Turbine Compressor Water Wash System
GEK 110220b
gas turbine parts require that a detergent solution be used during the washing operation. The detergent shall meet the requirements of GEK-107122 (Latest Revision), Appendix 1. 2.
Compressor Washing Frequency The frequency of compressor washing depends upon the severity and type of atmospheric contamination that fouls the compressor and reduces performance. The recommended method for establishing the frequency is to monitor gas turbine performance, comparing the routine performance with the baseline performance to observe the performance trends. If the performance has fallen significantly, and compressor fouling is suspected, it must be verified by visual inspection. This visual inspection should include the compressor inlet, bellmouth, inlet guide vanes and the first and, possibly, the second stage of the compressor blades.
NOTE Inspection should be made for the source of the oily deposits. If possible, corrective action should be taken. D. Washing System Operation 1.
General a. Off-line Water Wash Off-line water washing should be scheduled during a normal shutdown, if possible. This will allow enough time for the internal machine temperature to drop to the required levels for the washing. The time required to cool the machine can be shortened by maintaining the unit at crank speed. During this cooling of the turbine, the wash water may be heated to the proper level. Refer to GEK-107122 (Latest Revision) for gas turbine compressor liquid washing recommendations b. On-line Water Wash The period between off-line water washes can be extended via frequent on-line washing. When the compressor is suspected of being heavily fouled, an off-line wash should be performed. The on-line compressor wash system allows an operator to water wash the turbine compressor without having to shut down the turbine. The method of washing is similar in many ways to the off-line system. Both systems use the same pump, 88TW-1, and piping to supply high quality wash solution to the compressor. When the supply pipe reaches the vicinity of the turbine base, it splits into two branches, one for the off-line system and one for the on-line system. Each branch contains a stop valve, flow control orifice, manifold(s) and spray nozzles. There are significant differences, though, between the two systems. GE recommends against the use of detergents during on-line washing, while the use of detergents during off-line washing are encouraged. The on-line wash water requirements differ from that of off-line wash 3
GEK 110220b
Gas Turbine Compressor Water Wash System solution and must meet the requirements of Table 1 of GEK-107122 (Latest Revision) for on-line washing. Finally, the on-line system proceeds automatically after it is manually initiated; whereas, the off-line system requires operator intervention before and after the wash.
NOTE When using a detergent solution for on-line washing, it is recommended that the wash be followed by enough rinse water to remove the detergent residue from the wash nozzles at the spray manifold. This will prevent the detergent solutions from drying and clogging the nozzles. 2.
Mandatory Precautions Before water washing of the compressor begins, the turbine blading temperature must be low enough so that the water does not cause thermal shock.
CAUTION The differential temperature between the wash water and the interstage wheelspace temperature must not be greater than 120°F (67°C) to prevent thermal shock to the hot gas parts. The maximum wheelspace temperature as per TIL 1196–1 must be no greater than 150°F (65.5°C) as measured by the digital thermocouple readout system on the turbine control panel. To reduce this difference, the wash water may be heated and the turbine kept on crank until the wheelspace temperatures drop to an acceptable level. The wheelspace temperatures are read in the control room.
CAUTION If, during operation, there has been an increase in exhaust temperature spread above the normal 15°F to 30°F (8.3°C to 16.6°C), the thermocouples in the exhaust plenum should be examined. If they are coated with ash, the ash should be removed. Radiation shields should also be checked. If they are not radially oriented relative to the turbine, they should be repositioned per the appropriate drawing. If the thermocouples are coated with ash, or if the radiation shields are not properly oriented, a correct temperature reading will not be obtained. If neither of the above conditions exists and there is no other explanation for the temperature spread, consult the General Electric Service Engineering representative.
4
Gas Turbine Compressor Water Wash System
GEK 110220b
***WARNING*** THE WATER WASH OPERATION INVOLVES WATER UNDER HIGH-PRESSURE. CAUTION MUST BE EXERCISED TO ENSURE THE PROPER POSITIONING OF ALL VALVES DURING THIS OPERATION. SINCE THE WATER MAY ALSO BE HOT, NECESSARY PRECAUTIONS SHOULD BE TAKEN IN HANDLING VALVES, PIPES, AND POTENTIALLY HOT SURFACES. NOTE Before water washing the compressor, inspect the inlet plenum and gas turbine bellmouth for large accumulations of atmospheric contaminants that could be washed into the compressor. The deposits can be removed by washing with a garden hose. II. FALSE START DRAIN SYSTEM The false start drain system shall be designed in accordance with the latest version of GEK 110885 and GEK 110886. After a failure to fire on liquid fuel, the liquid fuel must be completely drained from the system. TIL 1424-1R2 shall be followed after a failure to fire on liquid fuel. The false start drain valves are instrument air operated with a open and closed limit switch. The liquid fuel from the combustion cans will drain from a common header for the lower combustion cans through the false start drain valve (VA17-1A). The position of this valve is controlled by a solenoid valve (20TFD-1). The limit switches (33TFD-1 and 33TFD-2) are used to verify valve position and take action if required.
5
GEK 110220b
Gas Turbine Compressor Water Wash System
GE Energy General Electric Company www.gepower.com
6
GEK 28166A Revised January 1997
GE Power Systems Gas Turbine
Field Performance Testing Procedure
These instructions do not purport to cover all details or variations in equipment nor to provide for every possible contingency to be met in connection with installation, operation or maintenance. Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser’s purposes the matter should be referred to the GE Company. 1997 GENERAL ELECTRIC COMPANY
GEK 28166A
Field Performance Testing Procedure TABLE OF CONTENTS
I. GENERAL . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3
II. PURPOSE OF TEST . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3
III. TEST PROCEDURE . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . A. Fuel Consumption . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
3 4
IV. EVALUATION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
6
V. CONCLUSION . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
6
GAS TURBINE PERFORMANCE DATA . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7–11
Figure 1.
2
FIGURE Gas Flow Measurement Instrumentation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . .
5
Field Performance Testing Procedure
GEK 28166A
I. GENERAL This instruction specifies the methods and equipment to be used during field performance tests of heavy-duty gas turbines using station instrumentation. It applies only to turbine generator power plants. II. PURPOSE OF TEST The primary purpose of the test shall be the measurement of turbine or generator output and fuel heat consumption at one or more load conditions. Sufficient supporting data shall be recorded to enable the “as tested” performance to be corrected to the standard conditions so that an accurate comparison may be made between tested and base line machine capability and heat rate at specified conditions. The attached data sheets should be used to record the test data. They are designed to provide the information required to evaluate the aero-thermodynamic performance of the gas turbine only. Any other operating data should be taken separately to prevent interference with the timing required for the performance test. III. TEST PROCEDURE These testing procedures are patterned after those specified and described by the American Society of Mechanical Engineers Power Test Code PTC-22-1966, “Gas Turbine Power Plants,” with the following additions and/or exceptions. Figures in parentheses refer to the relevant paragraph in the code. Past experience has shown that a gas turbine operator and four (4) test assistants are required for testing. One day of setup time and one day of testing are usually needed per machine. A test point will consist of four sets of instrument readings taken at 10-minute intervals over a 30-minute time span after steady-state conditions have been established (3.12). The machine will be considered to be in a steady-state condition when turbine wheelspace temperatures do not change more than 5°F (2.77°C) in 15 minutes prior to the test point. Past experience has shown that test points for gas turbines that cover longer than a half-hour time span are apt to experience changes in inlet air temperatures, which change the operating characteristics of the power plant and make the test less accurate. Speed measurements may not be required when a single-shaft generator drive unit is connected into a large power system. When the power system is small or frequency variations of more than 0.5% occur, then turbine speed (or frequency) must be measured by an electronic tachometer or equivalent. Average generator output must be measured by a polyphase watt-hour meter (4.24). Load is to be calculated by carefully timing, with stopwatch or equivalent, a fixed number of disc revolutions throughout the test point, averaging those times and calculating the resulting average power output by applying the appropriate factor (pri. Kh) stamped on the face of the meter. Power Ouput + n revolutions ) Pri K h ) (3, 600/1, 000) Sec. for n rev. where;
3
GEK 28166A
Field Performance Testing Procedure Pri K h + PTR ) CTR ) meter K PTR + Potential Instrument Transformer Ratio CTR + Current Instrument Transformer Ratio
Ideally, the total number of disc revolutions should be counted for the entire test point. This is, however, a tedious task and seldom worthwhile. Instead, a count of 20 revolutions should be made continuously throughout the point with the only interruption being the recording of the elapsed time for each group of revolutions. Gas turbine exhaust temperature will be measured by the unit control thermocouples mounted in the exhaust plenum (4.56). It is essential that the temperature-indicating system be adjusted and calibrated in place with a known millivolt source prior to the test so that it reports reliable data. If more than 25% of the control thermocouples are inoperative, the performance test should not be conducted. When liquid-in-glass manometers are used, bores of smaller than 5/16 inch (0.079 cm) will be permitted (4.59). Barometric pressure at the gas turbine site shall be measured with a mercury or aneroid barometer. A minimum reading accuracy of 0.01 inch (0.03 cm) Hg is required (4.65). As stated in paragraph 5.33 of the code, inlet air relative humidity has negligible effects on power output and heat consumption. It will therefore be ignored for performance evaluation. A. Fuel Consumption For units designed to burn more than one type of fuel, liquid fuel generally yields higher test accuracy and repeatability and should therefore be preferred. If there is a choice of liquid fuels, lighter fuels yield more accurate test results. 1. Liquid Fuel Liquid fuel flow is to be measured by a positive displacement meter which has been calibrated. The total fuel consumed during the exact 30-minute test as measured with a stopwatch must be recorded. The fuel temperature at the meter must also be measured. A sample of the fuel consumed during the test must be taken for laboratory measurement of higher heating value (HHV) and specific gravity. The lower heating value (LHV) will be determined by the method specified in paragraph 4.45 of PTC 22-1966. If the fuel is drawn from a large storage tank, a single sample will suffice for several test points; however, if variations in fuel characteristics are suspected, a fuel sample should be taken for each test point. Fuel samples of one pint are sufficient for HHV and specific gravity measurement.
4
Field Performance Testing Procedure
GEK 28166A
The heat consumption will be calculated using Heat Consumption (Btu/hr) + gal/min ) 8.33 lb/gal (H 2O) ) Specific Gravity (Oil) at metering temp. ) Heating Value * Btu/lb ) 60 min/hr. 2. Gas Fuel Gas fuel is to be measured with a flat-plate orifice installed in accordance with ASME or AGA standards. See Figure 1. The upstream pressure will be measured with a precision test gauge, the pressure drop with a manometer, the gas temperature with a thermometer or thermocouple. A gas sample must be taken from the fuel system during the test for laboratory measurement of higher heating value and specific gravity. A ratio (HHV/LHV) of 1.11 will be used to calculate the lower heating value. Calculation of gas flow will be done in accordance with ASME or AGA standards as described in ASME PTC 19.5; 4-1959 or AGA Report #3. Inlet air temperature will be measured with at least two thermometers or thermocouples installed in the inlet plenum near the gas turbine compressor inlet. The compressor inlet air temperature must be measured with an accuracy of ±1.0°F (.5°C) (4.55).
5 to 10 D
Gas D
d
Flow Thermometer well D. Pipe inside diameter d. Orifice diameter
Pressure connections shown as flange taps. List tap location on front of sheet. Give dimensions if not flange taps.
∆P
Indicate manometer type and fluid used for ∆ P measurement; mercury, water, or mercury with scale in water.
Figure 1. Gas Flow Measurement Instrumentation. *Use HHV or LHV as specified by rating.
5
GEK 28166A
Field Performance Testing Procedure If waste heat recovery equipment is used, turbine exhaust static pressure at or near the gas turbine flange must be measured using at least four-disc type static pressure probes. When the tests are performed at “Base” and “Peak” mode, the gas turbine control system must be adjusted to operate at the correct average gas turbine exhaust temperature for the test conditions, as defined by the appropriate control curve.
IV. EVALUATION Test results are based on the averaged data taken during the test. The averaged results are corrected to the standard conditions using the appropriate correction curves for the installation. Performance as indicated by determining the heat rate based on the test results is defined by: Heat Rate +
Heat Consumption Power Output
When decisions are required based on test results, one should recognize the tolerance due to measurement uncertainties associated with each particular test result. The tolerances around the test results are defined as twice the estimated standard deviation (2 Σ), computed from the tolerances associated with each measured test parameter and the influence of that parameter on the calculation of the corrected test results. The resulting performance tolerances of a single unit station instrumentation test, when performed as described in this document are Power output: ± 3.01% Heat rate (oil fuel): ± 2.09% Heat rate (gas fuel): ± 2.32% V. CONCLUSION This procedure may be used to periodically measure unit performance in order to establish trends and to determine the effectiveness of compressor cleaning. This data should be retained for historical reference.
6
Field Performance Testing Procedure
GEK 28166A
GAS TURBINE PERFORMANCE DATA CUSTOMER___________________________________________________ STATION______________________________________________________ Unit ID Gas Turbine S/N Generator S/N Fired Hours Fired Starts Reading Number Starting Time of Reading
Date Operating Mode Data Page Test Number
1 ______
2 ______
3 ______
4 ______
______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______
Barometric Pressure Inches of Mercury
______
______
______
______
Compressor Discharge Pressure PSIG Unit Gauge
______
______
______
______
Precision Gauge
______
______
______
______
______ ______ ______
______ ______ ______
______ ______
______ ______
Ambient Condition Compressor Inlet Temp. °F
Fuel Measurement - Oil* Fuel Meter Reading - Gal. ______ ______ Elapsed Time - Min. ______ ______ Fuel Temperature °F ______ ______ Fuel Meter Type & S/N______________________________________ Lube Oil Turbine Header Temp. °F. Lube Oil Tank Temp. °F
______ ______
______ ______
Recorded By ______________________________________ *For Gas Fuel use data under Fuel Consumption
7
GEK 28166A
Field Performance Testing Procedure GAS TURBINE PERFORMANCE DATA CUSTOMER___________________________________________________ STATION______________________________________________________
Unit ID Gas Turbine S/N Generator S/N
Date Operating Mode Data Page Test Number
Reading Number Starting Time of Reading Wheelspace Temperatures °F Comp. Disch. Left Comp. Disch. Right 1st Stage Forward 1st Stage Forward 1st Stage Aft 1st Stage Aft 2nd Stage Forward 2nd Stage Forward 2nd Stage Aft 2nd Stage Aft 3rd Stage Aft 3rd Stage Aft When 3rd Stage Forward Applicable 3rd Stage Forward
1 ______
2 ______
3 ______
4 ______
______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Exhaust Temperatures - Control T/C °F 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. 12.
______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______ ______
Exhaust Average Electrical
______
______
______
______
Calculated
______
______
______
______
Recorded By ______________________________________
8
Field Performance Testing Procedure
GEK 28166A
GAS TURBINE PERFORMANCE DATA CUSTOMER___________________________________________________ STATION______________________________________________________ Unit ID Gas Turbine S/N Generator S/N
Date Operating Mode Data Page Test Number
Reading Number Starting Time of Reading
1 ______
2 ______
3 ______
4 ______
Turbine Panel Board Set Point VCE
______ ______
______ ______
______ ______
______ ______
Generator Panel Board Megawatts
______
______
______
______
WHM (sec/20 rev)
Record WHM Time on Pg. 10 ______ ______ ______
______
______
______
______
______
______ ______ ______
______ ______ ______
______ ______ ______
______ ______ ______
______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______
______ ______ ______ ______ ______ ______
Megavars Generator Voltage, KV Phase 1-2 Phase 2-3 Phase 3-1 Generator Amperes, KA Phase 1 Phase 2 Phase 3 Excitation Voltage Excitation Amperes Frequency, Hertz
Recorded By ______________________________________
9
GEK 28166A
Field Performance Testing Procedure GAS TURBINE PERFORMANCE DATA CUSTOMER___________________________________________________ STATION______________________________________________________
Unit ID Gas Turbine S/N Generator S/N
Date Operating Mode Data Page Test Number
Power Measurement (Cont’d) WHM (Sec/20 Revs.)
Begin Test End Test
Repeatedly Time 20 Revolutions of Watt Hour Meter Disc During Entire Test Period Pri Kh Factor 1) ______ 5) _______
2) _______ 6) _______
3) _______ 7) _______
4) _______ 8) _______
Auxiliary WHM (Sec/Rev.) 1) _______ 2) _______
3) _______
4) _______
Pri Kh Factor Comment/Calculations
Recorded By ______________________________________
10
Field Performance Testing Procedure
GEK 28166A
GAS TURBINE PERFORMANCE DATA CUSTOMER___________________________________________________ STATION______________________________________________________ Unit ID Gas Turbine S/N Generator S/N
Date Operating Mode Test Number Data Page
Fuel Gas Flow (Record data every two minutes) Time __________ __________ __________ __________ __________ __________ __________ __________ __________ __________
Pressure __________ __________ __________ __________ __________ __________ __________ __________ __________ __________
∆P __________ __________ __________ __________ __________ __________ __________ __________ __________ __________
Temp __________ __________ __________ __________ __________ __________ __________ __________ __________ __________
__________ __________ __________ __________ __________
__________ __________ __________ __________ __________
__________ __________ __________ __________ __________
__________ __________ __________ __________ __________
Pipe Size
Pressure Tap Location
Orifice Size
Pressure Measured Upstream or Downstream of Orifice
Fuel Heating Value Specific Gravity *See Figure 1, Gas Flow Measurement Instrumentation Recorded By ______________________________________
11
GE Power Systems
Iss. Date 11/77 Reformat 1/93
General Electric Company One River Road, Schenectady, NY 12345 518 • 385 • 2211 TX: 145354
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/2
DESCRIPTION
WATER INJECTION SYSTEM 1
DEFINITION
The water injection system is designed to reduce the NOx level when the gas turbine is burning liquid fuel. The water injection system is an open loop where water flow is built up by an electrically driven water pump. The system includes : • • • • •
Temporary and permanent filters A water flow regulating valve to adjust the water flow according to the fuel flow A flow meter A stop valve to cut off the water flow A pump cooler to allow pump cooling down
Injection water flow is injected in the combustion chambers and evacuated in the atmosphere through the exhaust duct. The total water injection flow is distributed in the gas turbine through two manifolds, one for gas turbine low load and one for additional flow for higher load and full load. Flow regulating valve and stop valve are piloted using instrument air. 2
COMPONENT FUNCTION
20WN-1
Allows water injection in the combustion chambers.
20WN-2
Controls the VS2-2 valve.
23WN-1
Prevents motor from internal condensation while not running.
33WN-1
Indicates the valve open position.
33WN-2
Indicates the valve closed position.
33WN-3
Indicates the open position of the valve.
33WN-4
Indicates the closed position of the valve.
63WN-1
Detects low inlet pump pressure.
63WN-2
Detects low pump discharge pressure.
63WN-3
Detects low pump discharge pressure.
96WF-1 to 3
Measures the injection water flow.
88WN-1
Drives the water pump.
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Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
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DESCRIPTION
90WN-1
Converts 4-20mA signal into a pneumatic signal for valve position setting.
FA8-2
Filters the control air.
FM1-1
Measures the injection water flow.
FW1-1
Filters the injection water flow.
FW1-2
Filters the injection water flow at the pump upstream.
FW1-3
Filters the injection water flow at the nozzle upstream.
PW1-1
Provides the injection water pressure.
VC4-1
Regulates the water flow.
VCK100
Prohibits water return in the flow.
VCK110
Prohibits water return in the flow.
VCK111
Prohibits water return in the flow.
VPR62-1
Regulates the air pressure.
VPR62-13
Regulates the air pressure.
VS2-2
Cuts off the injection water flow big flow line.
3
ADDITIONAL INFORMATION
Water characteristics : Water characteristics must comply with GEK 101944
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DESCRIPTION
TURBINE CONTROL DEVICES SYSTEM 1
DEFINITION
Turbine and compressor control and protection sensors are grouped as a single system including : • • • • • • •
Turbine speed sensors Ignition transformers, spark plugs and flame detectors Vibrations sensors Compressor temperature measurement Turbine cooling temperature measurement Gas turbine exhaust temperature measurement Turbine bearings oil and metal temperature measurement
2
COMPONENT FUNCTION
28FD-10
Detects flame in the secondary zone of chamber combustion n°10.
28FD-11
Detects flame in the secondary zone of chamber combustion n°11.
28FD-4
Detects flame in the secondary zone of chamber combustion n°4.
28FD-5
Detects flame in the secondary zone of chamber combustion n°5.
30SG-1
Gathers the alarms.
39V-1A
Measures vibrations on the hat of bearing n°1.
39V-1B
Measures vibrations on the hat of bearing n°1.
39V-2A
Measures vibrations on the flange of oil return piping of bearing n°2.
39V-3A
Measures vibrations on the hat of bearing n°3.
39V-3B
Measures vibrations on the hat of bearing n°3.
39VS-11
Measures the movement of the rotor in the plan X,Y of bearing n°1.
39VS-12
Measures the movement of the rotor in the plan X,Y of bearing n°1.
39VS-21
Measures the movement of the rotor in the plan X,Y of bearing n°2.
39VS-22
Measures the movement of the rotor in the plan X,Y of bearing n°2.
39VS-23
Measures the movement of the rotor in the plan X,Y of bearing n°2.
39VS-24
Measures the movement of the rotor in the plan X,Y of bearing n°2.
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Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 2/4
DESCRIPTION
39VS-31
Measures the movement of the rotor in the plan X,Y of bearing n°3.
39VS-32
Measures the movement of the rotor in the plan X,Y of bearing n°3.
77HT-1
Measures shaft line speed specific circuit of overspeed.
77HT-2
Measures shaft line speed specific circuit of overspeed.
77HT-3
Measures shaft line speed specific circuit of overspeed.
77NH-1
Measures the shaft line speed.
77NH-2
Measures the shaft line speed.
77NH-3
Measures the shaft line speed.
77RP-11
Detects the shaft position.
95SG-13
Provides high voltage for ignition to the spark plug.
95SG-14
Provides high voltage for ignition to the spark plug.
95SP-13
Realizes ignition of combustion.
95SP-14
Realizes ignition of combustion.
96VC-11
Measures the axial movement of the turbine rotor.
96VC-12
Measures the axial movement of the turbine rotor.
BT-J1-1A,1B
Measures temperature of Bearing bushing n°1.
BT-J1-2A,2B
Measures temperature of Bearing bushing n°1.
BT-J2-1A,1B
Measures temperature of Bearing bushing n°2.
BT-J2-2A,2B
Measures temperature of Bearing bushing n°2.
BT-J3-1A,1B
Measures temperature of Bearing bushing n°3.
BT-J3-2A,2B
Measures temperature of Bearing bushing n°3.
BT-TA1-2A,2B Measures temperature of pad n°2 of thrust bearing n °1. BT-TA1-5A,5B Measures temperature of pad n°5 of thrust bearing n °1. BT-TA1-8A,8B Measures temperature of pad n°8 of thrust bearing n °1. BT-TI1-2A,2B
Measures temperature of pad n°2 of cou nter thrust bearing n°1.
BT-TI1-5A,5B
Measures temperature of pad n°5 of cou nter thrust bearing n°1.
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Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 3/4
DESCRIPTION
BT-TI1-9A,9B
Measures temperature of pad n°8 of cou nter thrust bearing n°1.
CT-DA-1
Measures air temperature of the outlet of compressor.
CT-DA-2
Measures air temperature of the outlet of compressor.
CT-IF-1
Measures air temperature of the inlet of compressor.
CT-IF-2
Measures air temperature of the inlet of compressor.
TT-IB-1
Measures air temperature in exhaust tunnel.
TT-WS1A0-1
Measures wheel space temperature, external position after first wheel.
TT-WS1A0-2
Measures wheel space temperature, external position after first wheel.
TT-WS1FI-1
Measures wheel space temperature, internal position before first wheel.
TT-WS1FI-2
Measures wheel space temperature, internal position before first wheel.
TT-WS2A0-1
Measures wheel space temperature, external position after second wheel.
TT-WS2A0-2
Measures wheel space temperature, external position after second wheel.
TT-WS2F0-1
Measures wheel space temperature, external position before second wheel.
TT-WS2F0-2
Measures wheel space temperature, external position before second wheel.
TT-WS3A0-1
Measures wheel space temperature, external position after third wheel.
TT-WS3A0-2
Measures wheel space temperature, external position after third wheel.
TT-WS3F0-1
Measures wheel space temperature, external position before third wheel.
TT-WS3F0-2
Measures wheel space temperature, external position before third wheel.
TT-XD-1 to 24
Measures temperature of GT exhaust.
3
ADDITIONAL INFORMATION
Gas turbine speed : Magnetic pick up sensors measure the pulse given by the toothed wheel fitted at compressor shaft front end. The frequency in Hz is equal to the speed in RPM due to the 60 tooth of the wheel. Vibration measurements : Seismic sensors and proximity probes measure the shaft vibrations. The vibration map after commissioning load tests represents the original vibration signature.
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Date : 01/2007
G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 4/4
DESCRIPTION
Gas turbine cooling : Gas turbine cooling is monitored by wheel space thermocouples. Two thermocouples situated at the same wheel space level should measure similar temperature. A temperature difference between two thermocouples in the same wheel space, detected by the Speedtronic® , represents a cooling fault or a measurement fault which must be analyzed and rectified quickly. Gas turbine exhaust temperature : TT-XD thermocouples measure gas turbine exhaust temperature. An exhaust spread, detected by the Speedtronic® , represents a combustion fault or a measurement fault and must be analyzed and rectified quickly.
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Date : 01/2007
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DESCRIPTION
STARTING MEANS SYSTEM 1
DEFINITION
The starting means system is designed for insuring the following functions : • • •
To break away and crank the shaft line up to nominal speed To allow the shaft line cooling down To crank the unit for Off line washing
The starting means includes : • • •
A main electrical cranking motor loaded at 150% of nominal power at maximum torque An electrical turning gear motor A torque converter including an auxiliary two ways electrical motor to drive the variable inlet guide vanes to adjust the output torque during starting sequences.
Lube oil from auxiliary lube oil pump feeds the torque converter during cranking sequences 2
COMPONENT FUNCTION
20TU-1
Allows oil supply feeding of torque converter.
23CR-1
Prevents motor from internal condensation while not running.
23CR-2
Prevents motor from internal condensation while not running.
23CR-3
Prevents motor from internal condensation while not running.
23TG-1
Prevents motor from internal condensation while not running.
33TC-1
Indicates the closed position of the converter supply oil valve.
33TM-5
Detects the stroke corresponding to minimum torque.
33TM-6
Detects the stroke corresponding to maximum torque.
88CR-1
Provides the power to crank the shaft line.
88TG-1
Rotates the turbine shaft at low speed during its cooling down.
88TM-1
Controls the position of the converter adjustable vanes.
96TM-1
Indicates the position of the adjustable vanes of the converter.
ET-CRS-11/R
Measures the stator temperature.
ET-CRS-12/R
Measures the stator temperature.
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DESCRIPTION
ET-CRS-21/R
Measures the stator temperature.
ET-CRS-22/R
Measures the stator temperature.
ET-CRS-31/R
Measures the stator temperature.
ET-CRS-32/R
Measures the stator temperature.
HM1
Represents the torque converter unit.
3
ADDITIONAL INFORMATION
Cranking motor : The starting sequence should be limited to three per hour to limit the effect of starting current and the thermal effect of load current. Clutch : There is no mechanical clutch between the starting means and the gas turbine. Therefore the accessory gearbox drives the torque converter output shaft while the gas turbine is running. The starting means may run at low speed while the gas turbine is running at nominal speed due to the dragging effect. Torque converter : Maintenance frequency must follow the instruction from supplier documentation.
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DESCRIPTION
FIRE PROTECTION SYSTEM 1
DEFINITION
The fire protection system is designed for insuring the following functions : • • • • •
To detect fire automatically To trip the unit and extinguish fire quickly To keep low concentration of combustive agent after fire To inform the operator To allow manual fire fighting release
In the enclosures listed here below : • • • •
Auxiliaries Gas turbine Load Gas
Fire fighting is achieved using carbon dioxide (CO2) 2
COMPONENT FUNCTION
43CP-1
Releases manually the fire protection in zone 1.
43CP-2
Releases manually the fire protection in zone 1.
43CP-3
Releases manually the fire protection in zone 1.
43CP-4
Releases manually the fire protection in zone 1.
43CP-5
Releases manually the fire protection in zone 2.
43CP-6
Releases manually the fire protection in zone 1.
43CP-7
Releases manually the fire protection in zone 1.
45FA-1A
Detects a high temperature in the compartment.
45FA-1B
Detects a high temperature in the compartment.
45FA-2A
Detects a high temperature in the compartment.
45FA-2B
Detects a high temperature in the compartment.
45FA-6A
Detects a high temperature in the compartment.
45FA-6B
Detects a high temperature in the compartment.
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DESCRIPTION
45FA-7A
Detects a high temperature in the compartment.
45FA-7B
Detects a high temperature in the compartment.
45FA-10A
Detects a high temperature in the compartment.
45FA-10B
Detects a high temperature in the compartment.
45FA-11A
Detects a high temperature in the compartment.
45FA-11B
Detects a high temperature in the compartment.
45FA-12A
Detects a high temperature in the compartment.
45FA-12B
Detects a high temperature in the compartment.
45FA-13A
Detects a high temperature in the compartment.
45FA-13B
Detects a high temperature in the compartment.
45FT-1A
Detects a high temperature in the compartment.
45FT-1B
Detects a high temperature in the compartment.
45FT-2A
Detects a high temperature in the compartment.
45FT-2B
Detects a high temperature in the compartment.
45FT-3A
Detects a high temperature in the compartment.
45FT-3B
Detects a high temperature in the compartment.
45FT-8A
Detects a high temperature in the compartment.
45FT-8B
Detects a high temperature in the compartment.
45FT-9A
Detects a high temperature in the compartment.
45FT-9B
Detects a high temperature in the compartment.
5E-1
Initiates manually an emergency trip.
5E-2
Initiates manually an emergency trip.
SLI-1
Gives a visual fire alarm.
SLI-1A
Gives a visual fire alarm.
SLI-1B
Gives a visual fire alarm.
SLI-1C
Gives a visual and audible fire alarm.
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DESCRIPTION
SLI-1D
Gives a visual fire alarm.
SLI-1E
Gives a visual and audible fire alarm.
SLI-2
Gives a visual fire alarm.
SLI-2B
Gives a visual fire alarm.
SLI-2C
Gives a visual and audible fire alarm.
SLI-2E
Gives a visual and audible fire alarm.
SLI-3C
Gives a visual and audible fire alarm.
3
ADDITIONAL INFORMATION
Compartments access: Access inside the compartments at any time must be under strict control using access permit or work permit to guaranty operator safety regarding potential risk including carbon dioxide emission. Fire alarm : Fire alarm appears before fire trip. Any alarm must be investigated and rectified quickly Carbon dioxide emission : After carbon dioxide emission and confirmation that fire risk do not exist any more, the compartment ventilation must be activated the clear the inside atmosphere. Concentration measurement must be carried out to confirm safe access. Local carbon dioxide vacuum must be undertaken if the concentration remains important.
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DESCRIPTION
HEATING AND VENTILATION SYSTEM 1
DEFINITION
The heating and ventilation system is designed for insuring the following functions : • • •
To evacuate the hot air from inside the compartment to outside To heat the enclosure when the unit is not operating To dilute gas leak to avoid hazardous area in the enclosures listed here below : • • • • •
Auxiliaries Gas turbine Load gear Gas valves Water injection
Enclosure purpose is : • • • • •
To protect personnel from high temperature and fire risks. To provide proper cooling and ventilation for the equipment. To provide attenuation of the noise generated by the equipment To contain fire fighting medium To provide weather protection for the equipment.
Redundant electrically driven fans provide airflow. Ventilation airflow direction is according to the need of each enclosure. Flap at ventilation air intake are use to restrict airflow while the ventilation is not in operation and to participate to fire fighting effectiveness. Electrical heaters are provided in enclosures for heating the ambient air. 2
COMPONENT FUNCTION
20BA-30
Controls the opening of the bypass flap.
20BA-31
Controls the opening of the bypass flap.
20BT-30
Controls the opening of the bypass flap.
20BT-40
Controls the opening of the bypass flap.
20JS-30
Keeps the flap closed.
20VG-30
Controls the opening of the bypass flap.
20VL-30
Controls the opening of the bypass flap.
23BT-1,2
Prevents motor from internal condensation while not running.
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DESCRIPTION
23HA-1
Heats the compartment.
23HA-2
Heats the compartment.
23HA-3
Heats the compartment.
23HA-4
Heats the compartment.
23HA-11
Heats the compartment.
23HA-12
Heats the compartment.
23HT-1
Heats the compartment.
23HT-2
Heats the compartment.
23HT-3
Heats the compartment.
23HT-4
Heats the compartment.
23VG-1
Prevents motor from internal condensation while not running.
23VG-2
Prevents motor from internal condensation while not running.
33BA-1
Indicates the flap closed position.
33BA-2
Indicates the flap closed position.
33BT-1
Indicates the flap closed position.
33BT-2
Indicates the flap closed position.
33BT-3
Indicates the flap closed position.
33DT-1
Indicates the door closed position.
33DT-2
Indicates the door closed position.
33DT-3
Indicates the door closed position.
33DT-4
Indicates the door closed position.
33DT-11
Indicates the door closed position.
33DT-12
Indicates the door closed position.
33DT-13
Indicates the door closed position.
33DT-14
Indicates the door closed position.
33JS-1
Indicates the flap closed position.
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DESCRIPTION
33JS-2
Indicates the flap closed position.
33VG-1
Indicates the flap closed position.
33VG-2
Indicates the flap closed position.
33VL-1
Indicates the flap closed position.
33VL-2
Indicates the flap closed position.
49HA-12
Protects the heater against overload.
63BA-30
Detects the clogging of the compartment air inlet filters.
63BA-31
Detects the clogging of the compartment air inlet filters.
63BT-30
Detects the clogging of the compartment air inlet filters.
63BT-40
Detects the clogging of the compartment air inlet filters.
63JS-30
Detects the ventilation air flow.
63VG-30
Detects the clogging of the compartment air inlet filters.
63VL-30
Detects the clogging of the compartment air inlet filters.
88BA-1
Drives the fan.
88BA-2
Drives the fan.
88BT-1
Drives the fan.
88BT-2
Drives the fan.
88JS-1
Drives the fan.
88JS-2
Drives the fan.
88VG-1
Drives the fan.
88VG-2
Drives the fan.
88VL-1
Drives the fan.
88VL-2
Drives the fan.
95BA-1
Detects the ventilation air flow.
95BA-2
Detects the ventilation air flow.
95BA-3
Detects the ventilation air flow.
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DESCRIPTION
95BT-1
Detects the ventilation air flow.
95BT-2
Detects the ventilation air flow.
95BT-3
Detects the ventilation air flow.
95BT-4
Detects the ventilation air flow.
95BT-5
Detects the ventilation air flow.
95BT-6
Detects the ventilation air flow.
95VL-1
Detects the ventilation air flow.
95VL-2
Detects the ventilation air flow.
95VL-3
Detects the ventilation air flow.
AT-AC-1
Measures the ambient temperature in the compartment.
AT-AC-11
Measures the ambient temperature in the compartment.
AT-LC-1
Measures the ambient temperature in the compartment.
AT-TC-1
Measures the ambient temperature in the compartment.
AT-TC-2
Measures the ambient temperature in the compartment.
AT-TC-3
Measures the ambient temperature in the compartment.
AT-WI-1
Measures the ambient temperature in the compartment.
3
ADDITIONAL INFORMATION
Compartments access : Access inside the compartments at any time must be under strict control using access permit or work permit to guaranty operator safety regarding potential risk including carbon dioxide emission. Carbon dioxide emission : After carbon dioxide emission and confirmation that fire risk do not exist any more, the compartment ventilation must be activated the clear the inside atmosphere. Concentration measurement must be carried out to confirm safe access. Unit cooling down sequence : During cooling down period using turning gear, all the turbine compartment doors must remain closed to avoid cool air excess flow distribution near the gas turbine casing.
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/1
DESCRIPTION
AIR FILTER SYSTEM 1
DEFINITION
The flow inlet & exhaust is designed for insuring the following functions : • • •
To supply the gas turbine with filtered air flow To reduce the compressor air inlet acoustical level To protect the air inlet duct against high pressure drop
2
COMPONENT FUNCTION
27TF-1
Gathers the air filter alarms.
63CA-1
Detects the compressed air low pressure.
63CS-2A
Detects high pressure drop in the air inlet duct.
63CS-2B
Detects high pressure drop in the air inlet duct.
96CS-3
Measures the pressure drop downstream of the air inlet silencer.
96RH
Measures the ambient air temperature and humidity.
96TF-1
Measures the air filter pressure drop.
AR_20
Represents the air filter electrical system.
3
ADDITIONAL INFORMATION
None
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/2
DESCRIPTION
GAS DETECTION SYSTEM 1
DEFINITION
The gas detection system is designed to detect gas fuel leaks inside • • •
The auxiliary compartment The gas turbine compartment. The gas compartment
The gas detection system include gas detector installed inside the ventilation air duct. 2
COMPONENT FUNCTION
45HA-1
Detects a gas concentration in auxiliary compartment.
45HA-2
Detects a gas concentration in auxiliary compartment.
45HA-3
Detects a gas concentration in auxiliary compartment.
45HA-4
Detects a gas concentration in the ventilation duct.
45HA-5
Detects a gas concentration in the ventilation duct.
45HA-6
Detects a gas concentration in the ventilation duct.
45HA-10
Detects a gas concentration in the ventilation duct.
45HA-11
Detects a gas concentration in the ventilation duct.
45HA-12
Detects a gas concentration in the ventilation duct.
45HT-1
Detects a gas concentration in gas turbine compartment.
45HT-2
Detects a gas concentration in gas turbine compartment.
45HT-3
Detects a gas concentration in gas turbine compartment.
45HT-4
Detects a gas concentration in the ventilation duct.
45HT-5
Detects a gas concentration in the ventilation duct.
45HT-6
Detects a gas concentration in the ventilation duct.
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DESCRIPTION
3
ADDITIONAL INFORMATION
Gas detection alarm : A gas leak detection alarm signal must be considered as high priority. It confirms a gas fuel leak in the enclosure. Access to this enclosure must be prohibited for safety reason. Corrective action must be undertaken quickly.
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G GEE EEnneerrggyy PPrroodduuccttss –– EEuurrooppee OPERATION AND MAINTENANCE MANUAL
Rev : A Page : 1/1
DESCRIPTION
PERFORMANCE MONITORING SYSTEM 1
DEFINITION
The performance monitoring system is designed to measure : • • •
The inlet plenum air temperature The atmospheric pressure The differential pressure between compressor air inlet duct and compressor bell mouth
2
COMPONENT FUNCTION
96AP-1A
Measures atmospheric pressure.
96AP-1B
Measures atmospheric pressure.
96AP-1C
Measures atmospheric pressure.
96BD-1
Measures the difference between the air inlet of GT and the bell of GT intake.
96CS-1
Measures the differential pressure between the air inlet of GT and the atmosphere.
CT-IF-3/FR
Measures air temperature of the inlet of compressor.
3
ADDITIONAL INFORMATION
None
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GER-3567H
GE Power Systems
GE Gas Turbine Performance Characteristics Frank J. Brooks GE Power Systems Schenectady, NY
GE Gas Turbine Performance Characteristics Contents Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 Thermodynamic Principles . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 The Brayton Cycle. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 Thermodynamic Analysis. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 6 Combined Cycle . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 Factors Affecting Gas Turbine Performance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Air Temperature and Site Elevation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Humidity. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Inlet and Exhaust Losses . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 9 Fuels. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 Fuel Heating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Diluent Injection . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Air Extraction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Performance Enhancements . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Inlet Cooling . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Steam and Water Injection for Power Augmentation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 Peak Rating . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 Performance Degradation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 Verifying Gas Turbine Performance . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 Summary . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 15 List of Figures. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16 List of Tables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 16
GE Power Systems GER-3567H (10/00) ■
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GE Gas Turbine Performance Characteristics
GE Power Systems GER-3567H (10/00) ■
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GE Gas Turbine Performance Characteristics Introduction GE offers both heavy-duty and aircraft-derivative gas turbines for power generation and industrial applications. The heavy-duty product line consists of five different model series: MS3002, MS5000, MS6001, MS7001 and MS9001. The MS5000 is designed in both single- and two-shaft configurations for both generator and mechanical-drive applications. The MS5000 and MS6001 are gear-driven units that can be applied in 50 Hz and 60 Hz markets. GE Generator Drive Product Line Model Fuel ISO Base Rating (kW) PG5371 (PA) PG6581 (B) PG6101 (FA) PG7121 (EA) PG7241 (FA) PG7251 (FB) PG9171 (E) PG9231 (EC) PG9351 (FA)
Gas Dist. Gas Dist. Gas Dist. Gas Dist. Gas Dist. Gas Dist. Gas Dist. Gas Dist. Gas Dist.
26,070. 25,570. 42,100. 41,160. 69,430. 74,090. 84,360. 87,220. 171,700. 183,800. 184,400. 177,700. 122,500. 127,300. 169,200. 179,800. 255,600. 268,000.
tions the product line covers a range from approximately 35,800 hp to 345,600 hp (26,000 kW to 255,600 kW). Table 1 provides a complete listing of the available outputs and heat rates of the GE heavy-duty gas turbines. Table 2 lists the ratings of mechanical-drive units, which range from 14,520 hp to 108,990 hp (10,828 kW to 80,685 kW). The complete model number designation for each heavy-duty product line machine is provided in both Tables 1 and 2. An explanation of
Heat Rate (Btu/kWh)
Heat Rate (kJ/kWh)
Exhaust Flow (lb/hr) x10-3
Exhaust Flow (kg/hr) x10-3
Exhaust Temp (degrees F)
Exhaust Temp (degrees C)
Pressure Ratio
12,060. 12,180. 10,640. 10,730. 10,040. 10,680. 10,480. 10,950. 9,360. 9,965. 9,245. 9,975. 10,140. 10,620. 9,770. 10,360. 9,250. 9,920.
12,721 12,847 11,223 11,318 10,526 10,527 11,054 11,550 9,873 10,511 9,752 10,522 10,696 11,202 10,305 10,928 9,757 10,464
985. 998. 1158. 1161. 1638. 1704. 2361. 2413. 3543. 3691. 3561. 3703. 3275. 3355. 4131. 4291. 5118. 5337.
446 448 525 526 742 772 1070 1093 1605 1672 1613 1677 1484 1520 1871 1944 2318 2418
905. 906. 1010. 1011. 1101. 1079. 998. 993. 1119. 1095. 1154. 1057. 1009. 1003. 1034. 1017. 1127. 1106.
485 486 543 544 594 582 536 537 604 591 623 569 543 539 557 547 608 597
10.6 10.6 12.2 12.1 14.6 15.0 12.7 12.9 15.7 16.2 18.4 18.7 12.6 12.9 14.4 14.8 15.3 15.8 GT22043E
Table 1. GE gas turbine performance characteristics - Generator drive gas turbine ratings All units larger than the Frame 6 are directdrive units. The MS7000 series units that are used for 60 Hz applications have rotational speeds of 3600 rpm. The MS9000 series units used for 50 Hz applications have a rotational speed of 3000 rpm. In generator-drive applica-
GE Power Systems GER-3567H (10/00) ■
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the model number is given in Figure 1. This paper reviews some of the basic thermodynamic principles of gas turbine operation and explains some of the factors that affect its performance.
1
GE Gas Turbine Performance Characteristics Mechanical Drive Gas Turbine Ratings Model
Year
ISO Rating
ISO Rating
Heat
Heat
Mass
Mass
Exhaust
Exhaust
Continuous
Continuous
Rate
Rate
Flow
Flow
Temp
Temp (degrees C)
(kW)
(hp)
(Btu/shp-hr)
(kJ/kWh)
(lb/sec)
(kg/sec)
(degrees F)
M3142 (J)
1952
11,290
15,140
9,500
13,440
117
53
1,008
542
M3142R (J)
1952
10,830
14,520
7,390
10,450
117
53
698
370
M5261 (RA)
1958
19,690
26,400
9,380
13,270
205
92
988
531
M5322R (B)
1972
23,870
32,000
7,070
10,000
253
114
666
352
M5352 (B)
1972
26,110
35,000
8,830
12,490
273
123
915
491
M5352R (C)
1987
26,550
35,600
6,990
9,890
267
121
693
367
M5382 (C)
1987
28,340
38,000
8,700
12,310
278
126
960
515
M6581 (B)
1978
38,290
51,340
7,820
11,060
295
134
1,013
545
Table 2. GE gas turbine performance characteristics - Mechanical drive gas turbine ratings
GT25385A
MS7000 PG
7
12
1
(EA)
Application
Series
Power
Number of Shafts
Model
M - Mech Drive PG - Pkgd Gen
Frame Approx 1 or 2 3,5,7 Output 6,9 Power in Hundreds, Thousands, or 10 Thousands of Horsepower
R - Regen Blank - SC
GT23054A
Figure 1. Heavy-duty gas turbine model designation
Thermodynamic Principles A schematic diagram for a simple-cycle, singleshaft gas turbine is shown in Figure 2. Air enters the axial flow compressor at point 1 at ambient conditions. Since these conditions vary from day to day and from location to location, it is convenient to consider some standard conditions for comparative purposes. The standard conditions used by the gas turbine industry are 59 F/15 C, 14.7 psia/1.013 bar and 60% relative humidity, which are established by the International Standards Organization (ISO) and frequently referred to as ISO conditions. GE Power Systems GER-3567H (10/00) ■
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Air entering the compressor at point 1 is compressed to some higher pressure. No heat is added; however, compression raises the air temperature so that the air at the discharge of the compressor is at a higher temperature and pressure. Upon leaving the compressor, air enters the combustion system at point 2, where fuel is injected and combustion occurs. The combustion process occurs at essentially constant pressure. Although high local temperatures are reached within the primary combustion zone (approaching stoichiometric conditions), the 2
GE Gas Turbine Performance Characteristics Fuel Combustor
Exhaust
2 4
Compressor 3
Generator
1
Turbine Inlet Air
GT08922A
Figure 2. Simple-cycle, single-shaft gas turbine combustion system is designed to provide mixing, burning, dilution and cooling. Thus, by the time the combustion mixture leaves the combustion system and enters the turbine at point 3, it is at a mixed average temperature. In the turbine section of the gas turbine, the energy of the hot gases is converted into work. This conversion actually takes place in two steps. In the nozzle section of the turbine, the hot gases are expanded and a portion of the thermal energy is converted into kinetic energy. In the subsequent bucket section of the turbine, a portion of the kinetic energy is transferred to the rotating buckets and converted to work. Some of the work developed by the turbine is used to drive the compressor, and the remainder is available for useful work at the output flange of the gas turbine. Typically, more than 50% of the work developed by the turbine sections is used to power the axial flow compressor. As shown in Figure 2, single-shaft gas turbines are configured in one continuous shaft and, therefore, all stages operate at the same speed. These units are typically used for generatordrive applications where significant speed variation is not required. GE Power Systems GER-3567H (10/00) ■
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A schematic diagram for a simple-cycle, twoshaft gas turbine is shown in Figure 3. The lowpressure or power turbine rotor is mechanically separate from the high-pressure turbine and compressor rotor. The low pressure rotor is said to be aerodynamically coupled. This unique feature allows the power turbine to be operated at a range of speeds and makes twoshaft gas turbines ideally suited for variablespeed applications. All of the work developed by the power turbine is available to drive the load equipment since the work developed by the high-pressure turbine supplies all the necessary energy to drive the compressor. On two-shaft machines the starting requirements for the gas turbine load train are reduced because the load equipment is mechanically separate from the high-pressure turbine.
The Brayton Cycle The thermodynamic cycle upon which all gas turbines operate is called the Brayton cycle. Figure 4 shows the classical pressure-volume (PV) and temperature-entropy (TS) diagrams for this cycle. The numbers on this diagram cor3
GE Gas Turbine Performance Characteristics Fuel Combustor
Exhaust
Compressor
HP
LP
Load
Turbine Inlet Air Figure 3. Simple-cycle, two-shaft gas turbine
GT08923C
air at point 1 on a continuous basis in exchange for the hot gases exhausted to the atmosphere at point 4. The actual cycle is an “open” rather than “closed” cycle, as indicated.
respond to the numbers also used in Figure 2. Path 1 to 2 represents the compression occurring in the compressor, path 2 to 3 represents the constant-pressure addition of heat in the combustion systems, and path 3 to 4 represents the expansion occurring in the turbine.
Every Brayton cycle can be characterized by two significant parameters: pressure ratio and firing temperature. The pressure ratio of the cycle is the pressure at point 2 (compressor discharge pressure) divided by the pressure at point 1 (compressor inlet pressure). In an ideal cycle,
The path from 4 back to 1 on the Brayton cycle diagrams indicates a constant-pressure cooling process. In the gas turbine, this cooling is done by the atmosphere, which provides fresh, cool
3
2 P
Fuel
4
2
4
1 3
V 3
1
T
4 2
1 S
GT23055A
Figure 4. Brayton cycle
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GE Gas Turbine Performance Characteristics this pressure ratio is also equal to the pressure at point 3 divided by the pressure at point 4. However, in an actual cycle there is some slight pressure loss in the combustion system and, hence, the pressure at point 3 is slightly less than at point 2. The other significant parameter, firing temperature, is thought to be the highest temperature reached in the cycle. GE defines firing temperature as the mass-flow mean total temperature
OPEN LOOP AIR-COOLED NOZZLE
sented as firing temperature by point 3 in Figure 4. Steam-cooled first stage nozzles do not reduce the temperature of the gas directly through mixing because the steam is in a closed loop. As shown in Figure 5, the firing temperature on a turbine with steam-cooled nozzles (GE’s current “H” design) has an increase of 200 degrees without increasing the combustion exit temperature.
ADVANCED CLOSED LOOP STEAM-COOLED NOZZLE
200F More Firing Temp. at Same NOx Production Possible
GT25134
Figure 5. Comparison of air-cooled vs. steam-cooled first stage nozzle at the stage 1 nozzle trailing edge plane. Currently all first stage nozzles are cooled to keep the temperatures within the operating limits of the materials being used. The two types of cooling currently employed by GE are air and steam. Air cooling has been used for more than 30 years and has been extensively developed in aircraft engine technology, as well as the latest family of large power generation machines. Air used for cooling the first stage nozzle enters the hot gas stream after cooling down the nozzle and reduces the total temperature immediately downstream. GE uses this temperature since it is more indicative of the cycle temperature repreGE Power Systems GER-3567H (10/00) ■
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An alternate method of determining firing temperature is defined in ISO document 2314, “Gas Turbines – Acceptance Tests.” The firing temperature here is a reference turbine inlet temperature and is not generally a temperature that exists in a gas turbine cycle; it is calculated from a heat balance on the combustion system, using parameters obtained in a field test. This ISO reference temperature will always be less than the true firing temperature as defined by GE, in many cases by 100 F/38 C or more for machines using air extracted from the compressor for internal cooling, which bypasses the combustor. Figure 6 shows how these various temperatures are defined. 5
GE Gas Turbine Performance Characteristics
Turbine Inlet Temperature - Average Gas Temp in Plane A. (TA) Firing Temperature - Average Gas Temp in Plane B. (TB)
CL
ISO Firing Temperature - Calculated Temp in Plane C. TC = f(Ma , Mf)
GE Uses Firing Temperature TB • Highest Temperature at Which Work Is Extracted GT23056
Figure 6. Definition of firing temperature
Thermodynamic Analysis Classical thermodynamics permit evaluation of the Brayton cycle using such parameters as pressure, temperature, specific heat, efficiency factors and the adiabatic compression exponent. If such an analysis is applied to the Brayton cycle, the results can be displayed as a plot of cycle efficiency vs. specific output of the cycle. Figure 7 shows such a plot of output and
efficiency for different firing temperatures and various pressure ratios. Output per pound of airflow is important since the higher this value, the smaller the gas turbine required for the same output power. Thermal efficiency is important because it directly affects the operating fuel costs. Figure 7 illustrates a number of significant points. In simple-cycle applications (the top curve), pressure ratio increases translate into efficiency gains at a given firing temperature.
GT17983A
Figure 7. Gas turbine thermodynamics GE Power Systems GER-3567H (10/00) ■
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GE Gas Turbine Performance Characteristics The pressure ratio resulting in maximum output and maximum efficiency change with firing temperature, and the higher the pressure ratio, the greater the benefits from increased firing temperature. Increases in firing temperature provide power increases at a given pressure ratio, although there is a sacrifice of efficiency due to the increase in cooling air losses required to maintain parts lives. In combined-cycle applications (as shown in the bottom graph in Figure 7 ), pressure ratio increases have a less pronounced effect on efficiency. Note also that as pressure ratio increases, specific power decreases. Increases in firing temperature result in increased thermal efficiency. The significant differences in the slope of the two curves indicate that the optimum cycle parameters are not the same for simple and combined cycles. Simple-cycle efficiency is achieved with high pressure ratios. Combined-cycle efficiency is obtained with more modest pressure ratios and greater firing temperatures. For example, the MS7001FA design parameters are 2420 F/1316 C firing temperature and 15.7:1 pressure ratio;
while simple-cycle efficiency is not maximized, combined-cycle efficiency is at its peak. Combined cycle is the expected application for the MS7001FA.
Combined Cycle A typical simple-cycle gas turbine will convert 30% to 40% of the fuel input into shaft output. All but 1% to 2% of the remainder is in the form of exhaust heat. The combined cycle is generally defined as one or more gas turbines with heat-recovery steam generators in the exhaust, producing steam for a steam turbine generator, heat-to-process, or a combination thereof. Figure 8 shows a combined cycle in its simplest form. High utilization of the fuel input to the gas turbine can be achieved with some of the more complex heat-recovery cycles, involving multiple-pressure boilers, extraction or topping steam turbines, and avoidance of steam flow to a condenser to preserve the latent heat content. Attaining more than 80% utilization of the fuel input by a combination of electrical power generation and process heat is not unusual. Exhaust HRSG ST Turb
Fuel
Gen Gen
Comb
Comp Air
Turb
Gen
Gas Turbine
GT05363C
Figure 8. Combined cycle
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GE Gas Turbine Performance Characteristics parameters and component efficiencies as well as air mass flow.
Combined cycles producing only electrical power are in the 50% to 60% thermal efficiency range using the more advanced gas turbines.
Correction for altitude or barometric pressure is more straightforward. The air density reduces as the site elevation increases. While the resulting airflow and output decrease proportionately, the heat rate and other cycle parameters are not affected. A standard altitude correction curve is presented in Figure 10.
Papers dealing with combined-cycle applications in the GE Reference Library include: GER-3574F, “GE Combined-Cycle Product Line and Performance”; GER-3767, “Single-Shaft Combined-Cycle Power Generation Systems”; and GER-3430F, “Cogeneration Application Considerations.”
Humidity
Factors Affecting Gas Turbine Performance
Similarly, humid air, which is less dense than dry air, also affects output and heat rate, as shown in Figure 11. In the past, this effect was thought to be too small to be considered. However, with the increasing size of gas turbines and the utilization of humidity to bias water and steam injection for NOx control, this effect has greater significance.
Air Temperature and Site Elevation Since the gas turbine is an air-breathing engine, its performance is changed by anything that affects the density and/or mass flow of the air intake to the compressor. Ambient weather conditions are the most obvious changes from the reference conditions of 59 F/15 C and 14.7 psia/1.013 bar. Figure 9 shows how ambient temperature affects the output, heat rate, heat consumption, and exhaust flow of a single-shaft MS7001. Each turbine model has its own temperature-effect curve, as it depends on the cycle
It should be noted that this humidity effect is a result of the control system approximation of firing temperature used on GE heavy-duty gas turbines. Single-shaft turbines that use turbine exhaust temperature biased by the compressor pressure ratio to the approximate firing temperature will reduce power as a result of
130
120
110
Heat Rate Percent Design
100
90
Exhaust Flow Heat Cons. Output
80
70
Compressor Inlet Temperature
0
20
40
60 °F
80
100
120
-18
-7
4
16 °C
27
38
49
GT22045D
Figure 9. Effect of ambient temperature
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GE Gas Turbine Performance Characteristics
GT18848B
Figure 10. Altitude correction curve
GT22046B
Figure 11. Humidity effect curve increased ambient humidity. This occurs because the density loss to the air from humidity is less than the density loss due to temperature. The control system is set to follow the inlet air temperature function. By contrast, the control system on aeroderivatives uses unbiased gas generator discharge temperature to approximate firing temperature. The gas generator can operate at different speeds from the power turbine, and the power will actually increase as fuel is added to raise the GE Power Systems GER-3567H (10/00) ■
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moist air (due to humidity) to the allowable temperature. This fuel increase will increase the gas generator speed and compensate for the loss in air density.
Inlet and Exhaust Losses Inserting air filtration, silencing, evaporative coolers or chillers into the inlet or heat recovery devices in the exhaust causes pressure losses in the system. The effects of these pressure losses are unique to each design. Figure 12 shows 9
GE Gas Turbine Performance Characteristics 4 Inches (10 mbar) H2O Inlet Drop Produces: 1.42% Power Output Loss 0.45% Heat Rate Increase 1.9 F (1.1 C) Exhaust Temperature Increase 4 Inches (10 mbar) H2O Exhaust Drop Produces: 0.42% Power Output Loss 0.42% Heat Rate Increase 1.9 F (1.1 C) Exhaust Temperature Increase
GT18238C
Figure 12. Pressure drop effects (MS7001EA) the effects on the MS7001EA, which are typical for the E technology family of scaled machines (MS6001B, 7001EA, 9001E).
Fuels Work from a gas turbine can be defined as the product of mass flow, heat energy in the combusted gas (Cp), and temperature differential across the turbine. The mass flow in this equation is the sum of compressor airflow and fuel flow. The heat energy is a function of the elements in the fuel and the products of combustion. Tables 1 and 2 show that natural gas (methane) produces nearly 2% more output than does distillate oil. This is due to the higher specific heat in the combustion products of natural gas, resulting from the higher water vapor content produced by the higher hydrogen/carbon ratio of methane. This effect is noted even though the mass flow (lb/h) of methane is lower than the mass flow of distillate fuel. Here the effects of specific heat were greater than and in opposition to the effects of mass flow. Figure 13 shows the total effect of various fuels on turbine output. This curve uses methane as the base fuel. Although there is no clear relationship between fuel lower heating value (LHV) and output, it is GE Power Systems GER-3567H (10/00) ■
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possible to make some general assumptions. If the fuel consists only of hydrocarbons with no inert gases and no oxygen atoms, output increases as LHV increases. Here the effects of Cp are greater than the effects of mass flow. Also, as the amount of inert gases is increased, the decrease in LHV will provide an increase in output. This is the major impact of IGCC type fuels that have large amounts of inert gas in the fuel. This mass flow addition, which is not compressed by the gas turbine’s compressor, increases the turbine output. Compressor power is essentially unchanged. Several side effects must be considered when burning this kind of lower heating value fuels: ■ Increased turbine mass flow drives up compressor pressure ratio, which eventually encroaches on the compressor surge limit ■ The higher turbine power may exceed fault torque limits. In many cases, a larger generator and other accessory equipment may be needed ■ High fuel volumes increase fuel piping and valve sizes (and costs). Low- or medium-Btu coal gases are frequently supplied at high temperatures, which further increases their volume flow 10
GE Gas Turbine Performance Characteristics 60 100% H2
30
20
10
LHV-Btu/lb (Thousands)
Kcal/kg (Thousands)
50
40
30 100% CH4
20 100% CH4H10
10 75% N2 - 25% CH4 75% CO2 - 25% CH4
100% CO 0
100
105
110
115
120
125
Output - Percent
130 GT25842
Figure 13. Effect of fuel heating value on output ■ Lower-Btu gases are frequently saturated with water prior to delivery to the turbine. This increases the combustion products heat transfer coefficients and raises the metal temperatures in the turbine section which may require lower operating firing temperature to preserve parts lives ■ As the Btu value drops, more air is required to burn the fuel. Machines with high firing temperatures may not be able to burn low Btu gases ■ Most air-blown gasifiers use air supplied from the gas turbine compressor discharge ■ The ability to extract air must be evaluated and factored into the overall heat and material balances As a result of these influences, each turbine model will have some application guidelines on flows, temperatures and shaft output to preserve
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its design life. In most cases of operation with lower heating value fuels, it can be assumed that output and efficiency will be equal to or higher than that obtained on natural gas. In the case of higher heating value fuels, such as refinery gases, output and efficiency may be equal to or lower than that obtained on natural gas.
Fuel Heating Most of the combined cycle turbine installations are designed for maximum efficiency. These plants often utilize integrated fuel gas heaters. Heated fuel results in higher turbine efficiency due to the reduced fuel flow required to raise the total gas temperature to firing temperature. Fuel heating will result in slightly lower gas turbine output because of the incremental volume flow decrease. The source of heat for the fuel typically is the IP feedwater. Since use of this energy in the gas turbine fuel heating system is thermodynamically advantageous, the combined cycle efficiency is improved by approximately 0.6%.
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GE Gas Turbine Performance Characteristics Diluent Injection Since the early 1970s, GE has used water or steam injection for NOx control to meet applicable state and federal regulations. This is accomplished by admitting water or steam in the cap area or “head-end” of the combustion liner. Each machine and combustor configuration has limits on water or steam injection levels to protect the combustion system and turbine section. Depending on the amount of water or steam injection needed to achieve the desired NOx level, output will increase because of the 130
Generally, up to 5% of the compressor airflow can be extracted from the compressor discharge casing without modification to casings or on-base piping. Pressure and air temperature will depend on the type of machine and site conditions. Air extraction between 6% and 20% may be possible, depending on the machine and combustor configuration, with some modifications to the casings, piping and controls. Such applications need to be reviewed on a case-by-case basis. Air extractions above 20% will require extensive modification to the turbine casing and unit configuration. Figure 15
With 5% Steam Injection
120 110
Output %
100 90
No Steam Injection
3% 1%
80 70
40
60
4
16
80
100
120
27
38
49
ºF ºC
Compressor Inlet Temperature GT18851A
Figure 14. Effect of steam injection on output and heat rate additional mass flow. Figure 14 shows the effect of steam injection on output and heat rate for an MS7001EA. These curves assume that steam is free to the gas turbine cycle, therefore heat rate improves. Since it takes more fuel to raise water to combustor conditions than steam, water injection does not provide an improvement in heat rate.
Air Extraction In some gas turbine applications, it may be desirable to extract air from the compressor.
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GT22048-1C
Figure 15. Effect of air extraction on output and heat rate shows the effect of air extraction on output and heat rate. As a “rule of thumb,” every 1% in air extraction results in a 2% loss in power.
Performance Enhancements Generally, controlling some of the factors that affect gas turbine performance is not possible. The planned site location and the plant configuration (such as simple- or combined-cycle) determine most of these factors. In the event additional output is needed, several possibilities to enhance performance may be considered.
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GE Gas Turbine Performance Characteristics Inlet Cooling The ambient effect curve (see Figure 9) clearly shows that turbine output and heat rate are improved as compressor inlet temperature decreases. Lowering the compressor inlet temperature can be accomplished by installing an evaporative cooler or inlet chiller in the inlet ducting downstream of the inlet filters. Careful application of these systems is necessary, as condensation or carryover of water can exacerbate compressor fouling and degrade performance. These systems generally are followed by moisture separators or coalescing pads to reduce the possibility of moisture carryover. As Figure 16 shows, the biggest gains from evaporative cooling are realized in hot, low-humidity climates. It should be noted that evaporative cooling is limited to ambient temperatures of 59 F/15 C and above (compressor inlet temperature >45 F/7.2 C) because of the potential for icing the compressor. Information contained in Figure 16 is based on an 85% effective evaporative cooler. Effectiveness is a measure of how close the cooler exit temperature approaches the ambient wet bulb tempera-
Figure 16. Effect of evaporative cooling on output and heat rate ture. For most applications, coolers having an effectiveness of 85% or 90% provide the most economic benefit. Chillers, unlike evaporative coolers, are not limited by the ambient wet bulb temperature. The achievable temperature is limited only by the capacity of the chilling device to produce coolant and the ability of the coils to transfer heat. Cooling initially follows a line of constant 100% RH
Psychrometric Chart (Simplified)
GT22419-1D
40
.020 60% RH
35
.015 30
40% RH
Btu Per Pound of Dry Air
Evaporative Cooling Process
25 .010
Specific Humidity
20% RH
20 Inlet Chilling Process 15
.005 10% RH
Dry Bulb Temperature
°F 40
60
80
100
120
°C 4
16
27
38
49
.000
GT21141D
Figure 17. Inlet chilling process GE Power Systems GER-3567H (10/00) ■
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GE Gas Turbine Performance Characteristics specific humidity, as shown in Figure 17. As saturation is approached, water begins to condense from the air, and mist eliminators are used. Further heat transfer cools the condensate and air, and causes more condensation. Because of the relatively high heat of vaporization of water, most of the cooling energy in this regime goes to condensation and little to temperature reduction.
Steam and Water Injection for Power Augmentation Injecting steam or water into the head end of the combustor for NOx abatement increases mass flow and, therefore, output. Generally, the amount of water is limited to the amount required to meet the NOx requirement in order to minimize operating cost and impact on inspection intervals. Steam injection for power augmentation has been an available option on GE gas turbines for over 30 years. When steam is injected for power augmentation, it can be introduced into the compressor discharge casing of the gas turbine as well as the combustor. The effect on output and heat rate is the same as that shown in Figure 14. GE gas turbines are designed to allow up to 5% of the compressor airflow for steam injection to the combustor and compressor discharge. Steam must contain 50 F/28 C superheat and be at pressures comparable to fuel gas pressures. When either steam or water is used for power augmentation, the control system is normally designed to allow only the amount needed for NOx abatement until the machine reaches base (full) load. At that point, additional steam or water can be admitted via the governor control.
Peak Rating The performance values listed in Table 1 are base load ratings. ANSI B133.6 Ratings and
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Performance defines base load as operation at 8,000 hours per year with 800 hours per start. It also defines peak load as operation at 1250 hours per year with five hours per start. In recognition of shorter operating hours, it is possible to increase firing temperature to generate more output. The penalty for this type of operation is shorter inspection intervals. Despite this, running an MS5001, MS6001 or MS7001 at peak may be a cost-effective way to obtain more kilowatts without the need for additional peripheral equipment. Generators used with gas turbines likewise have peak ratings that are obtained by operating at higher power factors or temperature rises. Peak cycle ratings are ratings that are customized to the mission of the turbine considering both starts and hours of operation. Firing temperatures between base and peak can be selected to maximize the power capabilities of the turbine while staying within the starts limit envelope of the turbine hot section repair interval. For instance, the 7EA can operate for 24,000 hours on gas fuel at base load, as defined. The starts limit to hot section repair interval is 800 starts. For peaking cycle of five hours per start, the hot section repair interval would occur at 4,000 hours, which corresponds to operation at peak firing temperatures. Turbine missions between five hours per start and 800 hours per start may allow firing temperatures to increase above base but below peak without sacrificing hours to hot section repair. Water injection for power augmentation may be factored into the peak cycle rating to further maximize output.
Performance Degradation All turbomachinery experiences losses in performance with time. Gas turbine performance degradation can be classified as recoverable or non-recoverable loss. Recoverable loss is usually
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GE Gas Turbine Performance Characteristics associated with compressor fouling and can be partially rectified by water washing or, more thoroughly, by mechanically cleaning the compressor blades and vanes after opening the unit. Non-recoverable loss is due primarily to increased turbine and compressor clearances and changes in surface finish and airfoil contour. Because this loss is caused by reduction in component efficiencies, it cannot be recovered by operational procedures, external maintenance or compressor cleaning, but only through replacement of affected parts at recommended inspection intervals. Quantifying performance degradation is difficult because consistent, valid field data is hard to obtain. Correlation between various sites is impacted by variables such as mode of operation, contaminants in the air, humidity, fuel and dilutent injection levels for NOx. Another problem is that test instruments and procedures vary widely, often with large tolerances. Typically, performance degradation during the first 24,000 hours of operation (the normally recommended interval for a hot gas path inspection) is 2% to 6% from the performance test measurements when corrected to guaranteed conditions. This assumes degraded parts are not replaced. If replaced, the expected performance degradation is 1% to 1.5%. Recent field experience indicates that frequent off-line water washing is not only effective in reducing recoverable loss, but also reduces the rate of non-recoverable loss. One generalization that can be made from the data is that machines located in dry, hot climates typically degrade less than those in humid climates.
Verifying Gas Turbine Performance Once the gas turbine is installed, a performance test is usually conducted to determine
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power plant performance. Power, fuel, heat consumption and sufficient supporting data should be recorded to enable as-tested performance to be corrected to the condition of the guarantee. Preferably, this test should be done as soon as practical, with the unit in new and clean condition. In general, a machine is considered to be in new and clean condition if it has less than 200 fired hours of operation. Testing procedures and calculation methods are patterned after those described in the ASME Performance Test Code PTC-22-1997, “Gas Turbine Power Plants.” Prior to testing, all station instruments used for primary data collection must be inspected and calibrated. The test should consist of sufficient test points to ensure validity of the test set-up. Each test point should consist of a minimum of four complete sets of readings taken over a 30-minute time period when operating at base load. Per ASME PTC-221997, the methodology of correcting test results to guarantee conditions and measurement uncertainties (approximately 1% on output and heat rate when testing on gas fuel) shall be agreed upon by the parties prior to the test.
Summary This paper reviewed the thermodynamic principles of both one- and two-shaft gas turbines and discussed cycle characteristics of the several models of gas turbines offered by GE. Ratings of the product line were presented, and factors affecting performance were discussed along with methods to enhance gas turbine output. GE heavy-duty gas turbines serving industrial, utility and cogeneration users have a proven history of sustained performance and reliability. GE is committed to providing its customers with the latest in equipment designs and advancements to meet power needs at high thermal efficiency.
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GE Gas Turbine Performance Characteristics List of Figures Figure 1. Heavy-duty gas turbine model designation Figure 2. Simple-cycle, single-shaft gas turbine Figure 3. Simple-cycle, two-shaft gas turbine Figure 4. Brayton cycle Figure 5. Comparison of air-cooled vs. steam-cooled first stage nozzle Figure 6. Definition of firing temperature Figure 7. Gas turbine thermodynamics Figure 8. Combined cycle Figure 9. Effect of ambient temperature Figure 10. Altitude correction curve Figure 11. Humidity effect curve Figure 12. Pressure drop effects (MS7001EA) Figure 13. Effect of fuel heating value on output Figure 14. Effect of steam injection on output and heat rate Figure 15. Effect of air extraction on output and heat rate Figure 16. Effect of evaporative cooling on output and heat rate Figure 17. Inlet chilling process
List of Tables Table 1. GE gas turbine performance characteristics - Generator drive gas turbine ratings Table 2. GE gas turbine performance characteristics - Mechanical drive gas turbine ratings
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UOGTNODLN Revision D, July 1999
GE Power Systems Gas Turbine
Unit Operation/Turbine (Gas) (Applicability MS 5001P, 6001B, 7001EA, 7001FA, 9001E Non Dry Low NOx)
I. REFERENCE DATA AND PRECAUTIONS A. Operator Responsibility It is essential that the turbine operators be familiar with the information contained in the following operation text, the Control Specification drawings (consult the Control System Settings drawing for the index of Control Specification drawings), the Piping Schematic drawings including the Device Summary (consult the Control System Settings Drawing for the index by model list and drawing number of applicable schematics), the SPEEDTRONIC control sequence program and the SPEEDTRONIC Mark V Users’ Manual (GEH 5979). The operator must also be aware of the power plant devices which are tied into the gas turbine mechanically and electrically and could affect normal operation. No starts should be attempted whether on a new turbine or a newly overhauled turbine until the following conditions have been met: 1. Requirements listed under CHECKS PRIOR TO OPERATION have been met. 2. Control systems have been functionally checked for proper operation before restarting. 3. All GENERAL OPERATING PRECAUTIONS have been noted. It is extremely important that gas turbine operators establish proper operating practices. We emphasize adherence to the following: 1. Respond to Annunciator Indicators — Investigate and correct the cause of the abnormal condition. This is particularly true for the protection systems, such as low oil pressure, overtemperature, vibration, overspeed etc. 2. Check of Control Systems — After any type of control maintenance is completed, whether repair or replacement of parts, functionally check control systems for proper operation. This should be done prior to restart of the turbine. It should not be assumed that reassembly, “as taken apart” is adequate without the functional test. 3. Monitor Exhaust Temperature During All Phases of Startup — The operator is alerted to the following:
These instructions do not purport to cover all details or variations in equipment nor to provide for every possible contingency to be met in connection with installation, operation or maintenance. Should further information be desired or should particular problems arise which are not covered sufficiently for the purchaser’s purposes the matter should be referred to the GE Company. 1999 GENERAL ELECTRIC COMPANY
UOGTNODLN
Unit Operation/Turbine (Gas) CAUTION Overtemperature can damage the turbine hot gas path parts.
Monitor exhaust temperature for proper control upon first startup and after any turbine maintenance is performed. Trip the turbine if the exhaust temperature exceeds the normal trip level, or increases at an unusual rate. A particularly critical period for overtemperature damage to occur is during the startup phase before the turbine reaches governing speed. At this time air flow is low and the turbine is unable to accelerate away from excess fuel. B. General Operating Precautions 1. Temperature Limits Refer to the Control Specifications for actual exhaust temperature control settings. It is important to define a “baseline value” of exhaust temperature spread with which to compare future data. This baseline data is established during steady state operation after each of the following conditions: a. Initial startup of unit b. Before and after a planned shut-down c. Before and after planned maintenance An important point regarding the evaluation of exhaust temperature spreads is not necessarily the magnitude of the spread, but the change in spread over a period of time. The accurate recording and plotting of exhaust temperatures daily can indicate a developing problem. Consult Control Specification-Settings Drawings for maximum allowable temperature spreads and wheelspace temperature operating limits. The wheelspace thermocouples, identified together with their nomenclature, are on the Device Summary. A bad thermocouple will cause a “High Wheelspace Differential Temperature” alarm. The faulty thermocouple should be replaced at the earliest convenience. When the average temperature in any wheelspace is higher then the temperature limit set forth in the table, it is an indication of trouble. High wheelspace temperature may be caused by any of the following faults: 1. Restriction in cooling air lines 2. Wear of turbine seals 3. Excessive distortion of the turbine stator 4. Improper positioning of thermocouple 5. Malfunctioning combustion system 6. Leakage in external piping 7. Excessive distortion of exhaust inner diffuser
UOGTNODLN–2
Unit Operation/Turbine (Gas)
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Check wheelspace temperatures very closely on initial startup. If consistently high, and a check of the external cooling air circuits reveals nothing, it is permissible to increase the size of the cooling air orifices slightly. Consult with a GE Company field representative to obtain recommendations as to the size that an orifice should be increased. After a turbine overhaul, all orifices should be changed back to their original size, assuming that all turbine clearances are returned to normal and all leakage paths are corrected. CAUTION Wheelspace temperatures are read on the CRT. Temperatures in excess of the maximum are potentially harmful to turbine hot-gas-path parts over a prolonged period of time. Excessive temperatures are annunciated but will not cause the turbine to trip. High wheelspace temperature readings must be reported to the GE technical representative as soon as possible. 2. Pressure Limits Refer to the Device Summary for actual pressure switch settings. Lube oil pressure in the bearing feed header is a nominal value of 25 psig (172.36 kPa). The turbine will trip at 8 psig (55.16 kPa). Pressure variations between these values will result from entrapped particulate matter within the lube oil filtering system. 3. Vibration Limits The maximum overall vibration velocity of the gas turbine should never exceed 1.0 inch (2.54 cm) per second in either the vertical or horizontal direction. Corrective action should be initiated when the vibration levels exceed 0.5 inch (1.27 cm) per second as indicated on the SPEEDTRONIC CRT. If doubt exists regarding the accuracy of the reading or if more accurate and specific vibration readings are desired a vibration check is recommended using vibration test equipment. 4. Load Limit The maximum load capability of the gas turbine is given in the control specification. For the upper limits of generator capability, refer to the Reactive Capability Curve. 5. Overloading of Gas Turbine, Facts Involved and Policy It is GE practice to design gas turbines with margins of safety to meet the contract commitments and to secure long life and trouble-free operation. So that maximum trouble-free operation can be secured, GE designs these machines with more than ample margins on turbine bucket thermal and dynamic stresses, compressor and turbine wheel stresses, generator ventilation, coolers, etc. As a result, these machines are designed somewhat better than is strictly necessary, because of the importance of reliability of these turbines to our customers and to the electrical industry. It cannot be said, therefore, that these machines cannot be safely operated beyond the load limits. Such operation, however, always encroaches upon the design margins of the machines with a conse-
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Unit Operation/Turbine (Gas) quent reduction in reliability and increased maintenance. Accordingly, any malfunction that occurs as a result of operation beyond contract limits cannot be the responsibility of the GE Company. The fact that a generator operates at temperature rises below the 185F° (85C°) for the rotor and 140F° (60C°) for the stator permitted by the AIEE Standards does not mean that it can be properly run with full safety up to these values by overloading beyond the nameplate rating. These standards were primarily set up for the protection of insulation from thermal deterioration on small machines. The imbedded temperature detectors of the stator register a lower temperature than the copper because of the temperature drop through the insulation from the copper to the outside of the insulation, where the temperature detectors are located. There are also conditions of conductor expansion, insulation stress, etc., which impose limitations. These factors have been anticipated in the “Vee” curves and reactive capability curves which indicate recommended values consistent with good operating practice. The “Vee” curves and reactive capability curves form part of the operating instructions for the generator and it is considered unwise to exceed the values given. The gas turbine-generator sets may require gearing between the gas turbine and the generator. Where a reduction (or speed-increasing) gear is required between the gas turbine and generator, the gear is rated at the maximum capability of the gas turbine, or the maximum kVa capability of the generator, whichever is less. If the gas turbine-generator set is operated beyond the maximum rating of the gear, the gear will also be overloaded with corresponding increased maintenance and reduced length of life. The gas turbines are mechanically designed so that (within prescribed limits), advantage can be taken of the increased capability over nameplate rating, which is available at lower ambient temperatures (because of increased air density), without exceeding the maximum allowable turbine inlet temperature. The load limit of the gas turbine-generator must not be exceeded, even when the ambient temperature is lower than that at which the load limit of the gas turbine is reached. Under these conditions, the gas turbine will operate at this load with a lower turbine inlet temperature and the design stresses on the load coupling and turbine shaft will not be exceeded. If the turbine is overloaded so that the turbine exhaust temperature schedule is not followed for reasons of malfunctioning or improper setting of the exhaust temperature control system, the maximum allowable turbine inlet temperature or the maximum allowable exhaust temperature, or both, will be exceeded and will result in a corresponding increase in maintenance and, in extreme cases, might result in failure of the turbine parts. The exhaust temperature control system senses the turbine exhaust temperature and introduces proper bias to limit the fuel flow so that neither the maximum allowable turbine inlet temperature nor the maximum allowable turbine exhaust temperature is exceeded.
6. Fire Protection System Operating Precautions The fire protection system, when actuated, will cause several functions to occur in addition to actuating the media discharge system. The turbine will trip, an audible alarm will sound, and the alarm message will be displayed on the CRT. The ventilation openings in the compartments will be closed by a pressure-operated latch and the damper in the turbine shell cooling discharge will be actuated.
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The annunciator audible alarm may be silenced by clicking on the alarm SILENCE target. The alarm message can be cleared from the ALARM list on the CRT after the ACKNOWLEDGE target and the ALARM RESET target are actuated, but only after the situation causing the alarm has been corrected. The fire protection system must be replenished and reset before it can automatically react to another fire. Reset must be made after each activation of the fire protection system which includes an initial discharge followed by an extended discharge period of the fire protection media. Fire protection system reset is accomplished by resetting the pressure switch located on the fire protection system. Ventilation dampers, automatically closed by a signal received from the fire protection system, must be reopened manually in all compartments before restarting the turbine. CAUTION Failure to reopen compartment ventilation dampers will severely shorten the service life of major accessory equipment. Failure to reopen the load coupling compartment dampers will materially reduce the performance of the generator. 7. Combustion System Operating Precautions
* * * WARNING * * * Sudden emission of black smoke may indicate a possibility of outer casing failure or other serious combustion problems. In such an event : a. Immediately shut down the turbine. b. Allow no personnel inside the turbine compartment until turbine is shut down. c. Caution all personnel against standing in front of access door openings into pressurized compartments. d. Perform a complete combustion system inspection. To reduce the possibility of combustion outer casing failure, the operator should adhere to the following: a. During operation, exhaust temperatures are monitored by the SPEEDTRONIC control system. The temperature spread is compared to allowable spreads with alarms and/or protective trips resulting if the allowable spread limits are exceeded. b. After a trip from 75% load or above, observe the exhaust on startup for black or abnormal smoke and scan the exhaust thermocouples for unusually high spreads. Record temperature spread during a normal startup to obtain base line signature for comparison. Excessive tripping should be investigated and eliminated. c. Adhere to recommended inspection intervals on combustion liners, transition pieces and fuel nozzles. Operating a turbine with non-operational exhaust thermocouples increases the risk of turbine overfiring and prevents diagnosis of combustion problems by use of temperature differential readings.
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To prevent the above described malfunctions the operator should keep the number of non-operational exhaust thermocouples to a maximum of two but no more than one of any three adjacent thermocouples. CAUTION Operation of the gas turbine with a single faulty thermocouple should not be neglected, as even one faulty thermocouple will increase the risk of an invalid “combustion alarm” and/or “Trip”. The unit should not be shut down just for replacement of a single faulty thermocouple. However, every effort should be made to replace the faulty thermocouples when the machine is down for any reason.
Adherence to the above criteria and early preventive maintenance should reduce distortions of the control and protection functions and the number of unnecessary turbine trips. 8. Cooldown/Shutdown Precautions CAUTION In the event of an emergency shutdown in which internal damage of any rotating equipment is suspected, do not turn the rotor after shutdown. Maintain lube oil pump operation, since lack of circulating lube oil following a hot shutdown will result in rising bearing temperatures which can result in damaged bearing surfaces. If the malfunction that caused the shutdown can be quickly repaired, or if a check reveals no internal damage affecting the rotating parts, reinstate the cooldown cycle.
If there is an emergency shutdown and the turbine is not turned with the rotor turning device, the following factors should be noted: a. Within 20 minutes, maximum, following turbine shutdown, the gas turbine may be started without cooldown rotation. Use the normal starting procedure. b. After a shutdown of between 20 minutes and 48 hours, a restart should not be attempted unless the gas turbine rotor has been turned from one to two hours prior to the startup attempt. c. If the unit has been shut down and not turned at all, it must be shut down for approximately 48 hours before it can be restarted without danger of shaft bow.
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Where the gas turbine has not been on rotor turning operation after shutdown and a restart is attempted, as under conditions (a) and (b) above, the operator should maintain a constant check on vibration velocity as the unit is brought up to its rated speed. If the vibration velocity exceeds one inch per second at any speed, the unit should be shut down and the shaft rotated for at least one hour before a second starting attempt is made. If seizure occurs during the turning operation of the gas turbine, the turbine should be shut down and remain idle for at least 30 hours, or until the rotor is free. The turbine may be rotated at any time during the 30-hour period if it is free; however, audible checks should be made for rubs. NOTE The vibration velocity must be measured at points near the gas turbine bearing caps. II. PREPARATIONS FOR NORMAL LOAD OPERATION A. Standby Power Requirements Standby AC power insures the immediate startup capability of particular turbine equipment and related control systems when the start signal is given. Functions identified by asterisk are also necessary for unit environmental protection and should not be turned off except for maintenance work on that particular function. Standby AC power is required for: 1. Lube oil heaters, which when used in conjunction with the lube oil pumps, heat and circulate turbine lube oil at low ambient temperatures to maintain proper oil viscosity. 2. *Control panel heating. 3. *Generator heating. 4. Lube oil pumps. Auxiliary pump should be run at periodic intervals to prevent rust formation in the lube oil system. 5. Fuel oil heaters, where used. These heaters used in conjunction with the fuel oil pumps, heat and circulate fuel oil at low ambient temperatures to maintain proper fuel oil viscosity. 6. Compartment heating. 7. *Operation of control compartment air conditioner during periods of high ambient temperature to maintain electrical equipment insulation within design temperature limits. 8. *Battery charging (where applicable). 9. Heating diesel engine cooling water to assure quick starting capability. (Applicable to diesel engine starting only.) If a black start is required, it is recommended that the turbine be started and loaded within one hour of losing AC power.
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B. Checks Prior to Operation The following checks are to be made before attempting to operate a new turbine or an overhauled turbine. It is assumed that the turbine has been assembled correctly, is in alignment and that calibration of the SPEEDTRONIC system has been performed per the Control Specifications. A standby inspection of the turbine should be performed with the lube oil pump operating and emphasis on the following areas: 1. Check that all piping and turbine connections are securely fastened and that all blinds have been removed. Most tube fittings incorporate a stop collar which insures proper torquing of the fittings at initial fitting make up and at reassembly. These collars fit between the body of the fitting and the nut and contact in tightening of the fitting. The stop collar is similar to a washer and can be rotated freely on unassembled fittings. During initial assembly of a fitting with a stop collar, tighten the nut until it bottoms on the collar. The fitting has to be sufficiently tightened until the collar cannot be rotated by hand. This is the inspection for a proper fitting assembly. For each remake of the fitting, the nut should again be tightened until the collar cannot be rotated. 2. Inlet and exhaust plenums and associated ducting are clean and rid of all foreign objects. All access doors are secure. 3. Where fuel, air or lube oil filters have been replaced check that all covers are intact and tight. 4. Verify that the lube oil tank is within the operating level and if the tank has been drained that it has been refilled with the recommended quality and quantity of lube oil. If lube oil flushing has been conducted verify that all filters have been replaced and any blinds if used, removed. 5. Check operation of auxiliary and emergency equipment, such as lube oil pumps, water pumps, fuel forwarding pumps, etc. Check for obvious leakage, abnormal vibration (maximum 3 mils), noise or overheating. 6. Check lube oil piping for obvious leakage. Also using provided oil flow sights, check visually that oil is flowing from the bearing drains. The turbine should not be started unless flow is visible at each flow sight. 7. Check condition of all thermocouples and/or resistance temperature detectors (RTDs) on the CRT. Reading should be approximately ambient temperature. 8. Check spark plugs for proper arcing.
* * * WARNING * * * Do not test spark plugs where explosive atmosphere is present.
If the arc occurs anywhere other than directly across the gap at the tips of the electrodes, or if by blowing on the arc it can be moved from this point, the plug should be cleaned and the tip clearance adjusted. If necessary, the plug should be replaced. Verify the retracting piston for free operation. 9. Devices requiring manual lubrication are to be properly serviced. 10. Determine that the cooling water system has been properly flushed and filled with the recommended coolant. Any fine powdery rust, which might form in the piping during short time exposure to atmosphere, can be tolerated. If there is evidence of a scaly rust, the cooling system should be power flushed until all scale is removed. If it is necessary to use a chemical cleaner, most automobile cool-
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ing system cleaners are acceptable and will not damage the carbon and rubber parts of the pump mechanical seals or rubber parts in the piping. Refer to “Cooling Water Recommendations for Combustion Gas Turbine Closed Cooling Systems” included under tab titled Fluid Specifications. Note the following regarding antifreeze. CAUTION Do not change from one type antifreeze to another without first flushing the cooling system very thoroughly. Inhibitors used may not be compatible and can cause formation of gums, in addition to destroying effectiveness as an inhibitor. Consult the antifreeze vendor for specific recommendations. Following the water system refill ensure that water system piping, primarily pumps and flexible couplings, do not leak. It is wise not to add any corrosion inhibitors until after the water system is found to be leak free. 11. Turbines having a diesel engine starting means should have the engine tested using the diesel test pushbutton in the accessory compartment. 12. The use of radio transmitting equipment in the vicinity of open control panels is not recommended. Prohibiting such use will assure that no extraneous signals are introduced into the control system that might influence the normal operation of the equipment. 13. Check the Cooling and Sealing Air Piping against the assembly drawing and piping schematic, to ensure that all orifice plates are of designated size and in designated positions. 14. At this time all annunciated ground faults should be cleared. It is recommended that units not be operated when a ground fault is indicated. Immediate action should be taken to locate all grounds and correct the problems. C. Checks During Start Up and Initial Operation The following is a list of important checks to be made on a new or newly overhauled turbine with the OPERATION SELECTOR in various modes. The Control Specifications — Control Systems Adjustments should be reviewed prior to operating the turbine. CAUTION Where an electric motor is used as the starting means refer to the Control Specifications for maximum operating time. When a unit has been overhauled those parts or components that have been removed and taken apart for inspection/repair should be critically monitored during unit startup and operation. This inspection should include: leakage check, vibration, unusual noise, overheating, lubrication. 1. Crank a. Listen for rubbing noises in the turbine compartment and in the reduction gear compartment especially in the load tunnel area. A soundscope or some other listening type device is suggested. Shutdown and investigate if unusual noise occurs.
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Unit Operation/Turbine (Gas) b. Check for unusual vibration. c. Inspect for water system leakage.
2. Fire
* * * WARNING * * * Due to the complexity of gas turbine fuel systems, it is imperative for everyone to exercise extreme caution in and near any turbine compartment, fuel handling system, or any other enclosures or areas containing fuel piping or fuel system components. Do not enter the turbine compartment unless absolutely necessary. When it is necessary, exercise caution when opening and entering the compartment. Be aware of the possibility of fuel leaks, and be prepared to shut down the turbine and take action if a leak is discovered. At any time, if/when entering the turbine compartment or when in the vicinity of the fuel handling system or other locations with fuel piping, fuel system components, or fuel system connections, while the turbine is operating, implement the following: Conduct an environmental evaluation of the turbine compartment, fuel handling system, or specific area. Pay particular attention to all locations where fuel piping/components/connections exist. Follow applicable procedures for leak testing. If fuel leaks are discovered, exit the area quickly, shut the turbine down, and take appropriate actions to eliminate the leak(s). Require personnel entering the turbine comparrtment to be fitted with the appropriate personal protective equipment, i.e., hard hat, safety glasses, hearing protection, harness/manline (optional depending on space constraints), heat resistant/flame retardant coveralls and gloves. Establish an attendant to maintain visual contact with personnel inside the turbine compartment and radio communications with the control room operator. During the first start-up after a disassembly, visually check all connections for fuel leaks. Preferably check the fittings during the warm-up period when pressures are low. Visually inspect the fittings again at full speed, no load, and at full load. Do not attempt to correct leakage problems by tightening fittings and/or bolting while lines are fully pressurized. Note area in question and, depending on severity of leak, repair at next shutdown, or if required shut unit down immediately. Attempts to correct leakage problem on pressurized lines could lead to sudden and complete failure of component and resulting damage to equipment and personnel injury.
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a. Bleed fuel oil filters, if appropriate. Then check entire fuel system and the area immediately around the fuel nozzle for leaks. In particular check for leaks at the following points: Turbine Compartment (1) Fuel piping/tubing to fuel nozzle (2) Fuel check valves (3) Atomizing air manifold and associated piping (when used) (4) Gas manifold and associated piping (when used) Accessory Compartment or Fuel Module (1) Flow divider (when used) (2) Fuel and water pumps (3) Filter covers and drains CAUTION Elimination of fuel leakage in the turbine compartment is of extreme importance as a fire preventive measure. b. Monitor FLAME status on the processor to verify all flame detectors are correctly indicating flame. Two sight glasses are included as part of the unit startup kit. Use of sight glasses to be limited to initial startup and special requirements, as opposed to normal operation. Following initial startup remove sight glasses and plug opening. c. Monitor the turbine control system readings on the processor for unusual exhaust thermocouple temperature, wheelspace temperature, lube oil drain temperature, highest to lowest exhaust temperature spreads and “hot spots” i.e. combustion chamber(s) burning hotter than all the others. d. Listen for unusual noises and rubbing. e. Monitor for excessive vibration. 3. Automatic, Remote On initial startup, permit the gas turbine to operate for a 30 to 60 minute period in a full speed, no load condition. This time period allows for uniform and stabilized heating of the parts and fluids. Tests and checks listed below are to supplement those recorded in Control Specification — Control System Adjustments. Record all data for future comparison and investigation. a. Continue monitoring for unusual rubbing noises and shutdown immediately if noise persists. b. Monitor lube oil tank, header and bearing drain temperatures continually during the heating period. Refer to the Schematic Piping Diagram — Summary Sheets for temperature guidelines. Adjust VTRs if required.
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Unit Operation/Turbine (Gas) c. At this time a thorough vibration check is recommended, using vibration test equipment such as IRD equipment (IRD Mechanalysis, Inc.) or equivalent with filtered or unfiltered readings. It is suggested that horizontal, vertical and axial data be recorded for the: (1) accessory gear (when used) forward and aft sides (2) all accessible bearing covers on the turbine (3) turbine forward compressor casing (4) turbine support legs (5) reduction gear (when used) forward and aft sides, gear and pinion (6) bearing covers on the load equipment d. Check wheelspace, exhaust and control thermocouples for proper indication on the CRT. Record these values for future reference. e. Flame detector operation should be tested per the Control Specification — Control System Adjustments. f. Utilize all planned shutdowns in testing the Overspeed Trip System per the Control Specifications — Control System Adjustments. Refer to Special Operations section of this text. g. Monitor CRT display data for proper operation.
III. OPERATING PROCEDURES A. General The following instructions pertain to the operation of a model series 5001, 6001, 7001EA or 9001E gas turbine unit designed for generator drive application. These instructions are based on use of Mark V SPEEDTRONIC turbine control panels. Functional description of the CRT Main Display follows; however, panel installation, calibration, and maintenance are not included. Operational information includes startup and shutdown sequencing in the AUTO mode of operation. The most common causes of alarm messages can be found in the concluding section. It is not intended to cover initial turbine operation herein; rather, it will be assumed that initial startup, calibration and checkouts have been completed. The turbine is in the cooldown or standby mode ready for normal operation with AC and DC power available for all pumps, motors, heaters, and controls and all annunciator drops are cleared. Refer to the Control Specifications in this volume, and the previously furnished Control Sequence Program (CSP) for additional operating sequence information and related diagrams.
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B. Start-Up 1. General Operation of a single turbine/generator unit may be accomplished either locally or remotely. The following description lists operator, control system and machine actions or events in starting the gas turbine. Reference the section “Description of Panels and Terms — Turbine Control Panel” for description of turbine panel devices. The following assumes that the unit is off of cooldown, and in a ready to start condition. 2. Starting Procedure a. Using the cursor positioning device, select “MAIN” display from the DEMAND DISPLAY menu. (1) The display will indicate speed, temperature, various conditions etc. Three lines displayed on the CRT will read: SHUTDOWN STATUS OFF COOLDOWN OFF b. Select “AUTO” and “EXECUTE” (1) The CRT display will change to: STARTUP STATUS READY TO START AUTO c. Select “START” and “EXECUTE” (1) Unit auxiliaries will be started including a motor driven lube oil pump used to establish lube oil pressure. The CRT message SEQ IN PROGRESS will appear. (2) If the starting clutch is not engaged, the rotor turning device will operate until the clutch engages. With the clutch engaged, the lube oil pressure and all other permissives satisfied, the master protective logic (L4) will be satisfied. The CRT display will change to: STARTUP STATUS STARTING AUTO; START (3) Where a diesel engine is utilized as starting equipment, the starting diesel will start and run at idle for two minutes to warm up. At the end of the diesel warmup period, the rotor turning device will operate continuously and the diesel will accelerate. Where an electric motor is utilized as starting equipment, the motor will start immediately.
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Unit Operation/Turbine (Gas) (4) The turbine shaft will begin to rotate and accelerate. When the unit reaches approximately 10 rpm, the turning device will be turned off. The CRT display will change to STARTUP STATUS/CRANKING. The zero speed signal “14HR” will be displayed. (5) When the unit reaches approximately 20% speed, the minimum speed signal “14HM” will be displayed on the CRT. (For machines with cooling water fan motors receiving power from the generator terminals via the UCAT transformer, field flashing will be initiated to build up generator voltage to power the fans; otherwise, field flashing to build up generator voltage will occur at operating speed.) (6) If the unit configuration requires purging of the gas path prior to ignition, the starting device will crank the gas turbine at purge speed for a period of time determined by the setting of the purge timer. See Control Specifications-Settings Drawing for purge timer settings. (7) FSR will be set to firing value. (FSR, Fuel Stroke Reference, is the electrical signal that determines the amount of fuel delivered to the turbine combustion system.) Ignition sequence is initiated. The CRT display will change to START UP STATUS/FIRING. (8) When flame is established, the CRT display will indicate flame in those combustors equipped with flame detectors. (9) FSR is set back to warm-up value, and the CRT display will indicate STARTUP STATUS/WARMING UP. If the flame goes out during the 60 second firing period, FSR will be reset to firing value. (At the end of the ignition period, if flame has not been established, the unit will remain at firing speed.) At this time the operator may shut the unit down or attempt to fire again. To fire again select CRANK on the Main Display. The purge timer and firing timer are reinitialized. The purge timer will begin to time. Reselecting AUTO will cause the ignition sequence to repeat itself after the purge timer has timed out. If the unit is being operated remotely (REMOTE having previously been selected on the Main Display), and no fire has been established at the end of the ignition period, the unit will be purged of unburned fuel. At the end of the purge period (normally 1 to 2 minutes) ignition will be attempted again. If flame is not established at this time, the starting sequence will be terminated and the unit will shutdown. At the end of the warmup period, with flame established, FSR will begin increasing. The CRT will indicate STARTUP STATUS/ACCELERATING and the turbine will increase in speed. At approximately 50% speed, the accelerating speed signal “14HA” will be displayed on the CRT. (10) The turbine will continue to accelerate. When it reaches about 60% speed, the starting device will disengage and shutdown (if the starting device is a diesel engine, it will cooldown at idle speed before shutting down). The CRT will indicate the change in status from STARTUP CONTROL to SPEED CONTROL at approximately 60% speed. (11) When the turbine reaches operating speed, the operating speed signal “14HS” will be displayed on the CRT. The motor-driven lube oil pump will shutdown, since lube oil is being supplied by the shaft driven pump. Field flashing is terminated. If the synchronizing selector switch (43S) on the generator control panel is in the OFF position and REMOTE is not selected on the CRT, as the turbine reaches operating speed, CRT will now read:
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RUN STATUS FULL SPEED NO LOAD AUTO; START If the synchronizing selector switch on the generator panel is in the AUTO position or REMOTE is selected on the CRT automatic synchronizing is initiated. The CRT will read SYNCHRONIZING. The turbine speed is matched to the system (to less than 1/3 Hz difference) and when the proper phase relationship is achieved the generator breaker will close. The machine will load to Spinning Reserve unless a load control point BASE, PEAK or PRESELECTED LOAD has been selected. The CRT will display SPINNING RESERVE, once the unit has reached this load point. C. Synchronizing When a gas turbine-driven synchronous generator is connected into a power transmission system, the phase angle of the generator going on-line must correspond to the phase angle of the existing line voltage at the moment of its introduction into the system. This is called synchronizing. CAUTION Before initiating synchronization procedures, be sure that all synchronization equipment is functioning properly, and that the phase sequence of the incoming unit corresponds to the existing line phase sequence and the potential transformers are connected correctly to proper phases. Initial synchronization and checkout after performing maintenance to synchronizing equipment should be performed with the breaker racked out. NOTE Synchronizing cannot take place unless AUTO or REMOTE has been selected on the CRT Main Display and the turbine has reached full speed. Generator synchronization can be accomplished either automatically or manually. Manual synchronization is accomplished by the following procedure: 1. Place the synchronizing selector switch on the generator panel (43S) in the MANUAL position. 2. Select AUTO on the CRT Main Display. 3. Select START and EXECUTE on the CRT Main Display. This will start the turbine and accelerate it to full speed as previously described. At this point the CRT will indicate RUN STATUS, FULL SPEED NO LOAD. 4. Compare the generator voltage with the line voltage. (These voltmeters are located on the generator control panel.) 5. Make any necessary voltage adjustment by operating the RAISE- LOWER (90R4) switch on the generator panel until the generator voltage equals the line voltage.
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6. Compare the generator and line frequency on the synchroscope (located on the generator control panel). If the pointer is rotating counterclockwise, the generator frequency is lower than the line frequency and should be raised by increasing the turbine-generator speed. The brightness of the synchronizing lights will change with the rotation of the synchroscope. When the lights are their dullest the synchroscope will be at the 12 o’clock position. The lights should not be used to synchronize but only to verify proper operation of the synchroscope. 7. Adjust the speed until the synchroscope rotates clockwise at approximately five seconds per revolution or slower. 8. The generator circuit breaker “close” signal should be given when it reaches a point approximately one minute before the 12 o’clock position. This allows for a time lag for the breaker contacts to close after receiving the close signal. Automatic synchronization is accomplished by the following steps: 1. Place the synchronizing selector switch (43S) in the AUTO position. 2. Select AUTO on the CRT Main Display. 3. Select START on the CRT Main Display. This procedure will start the turbine, and upon attainment of “complete sequence”, match generator voltage to line voltage (if equipped with optional voltage matching), synchronize the generator to the line frequency, and load the generator to the preselected value. A “breaker closed” indicator will actuate when the generator circuit breaker has closed placing the synchronized unit on-line. Once the generator has been connected to the power system, the turbine fuel flow may be increased to pick up load, and the generator excitation may be adjusted to obtain the desired KVAR value.
* * * WARNING * * * Failure to synchronize properly may result in equipment damage and/or failure, or the creation of circumstances which could result in the automatic removal of generating capacity from the power system. In those cases where out-of-phase breaker closures are not so serious as to cause immediate equipment failure or system disruption, cumulative damage may result to the on-coming generator. Repeated occurrences of out-of-phase breaker closures can eventually result in generator failure because of the stresses created at the time of closure. Gear damage may result on load packages with a reduction gear in the gas turbine-generator train. Such damage may occur separately or in conjunction with generator damage from out-of-phase breaker closure. Damage may be to the gear teeth or to the quill shaft (if there is a quill shaft). Out-of-phase breaker closure of a magnitude sufficient to cause either immediate or cumulative equipment damage mentioned above will usually result in annunciator drops to notify the operator of the problem. The following alarms have been displayed at various occurrences of known generator breaker malclosures: 1. High vibration trip 2. Loss of excitation
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3. Various AC undervoltage drops Out-of-phase breaker closure will result in abnormal generator noise and vibration at the time of closure. If there is reason to suspect such breaker malclosure, the equipment should be immediately inspected to determine the cause of the malclosure and for any damage to the generator and/or reduction gear. Refer to the “Control and Protection” section of this volume for additional information on the synchronizing system. D. Normal Load Operation 1. Manual Loading Manual loading is accomplished by clicking on the SPEED SP RAISE/SPEED SP LOWER targets on the CRT Main Display. Manual loading can also be accomplished by means of the governor control switch (70R4/CS) on the generator control panel. Holding the switch to the right will increase the load; holding it to the left will decrease the load. Manual loading beyond the selected temperature control point BASE or PEAK is not possible. The manual loading rate is shown in the Control Specification-Settings Drawing. NOTE When manually loading with the governor control switch (70R4/CS) for load changes greater than 25% of full load, the operator should not change more than 25% of full load in one minute. 2. Automatic Loading On startup if no load point is selected, the unit will load to the SPINNING RESERVE load point. The SPINNING RESERVE load point is slightly greater than no load, typically 8% of base rating. An intermediate load point, PRE-SELECTED load, and temperature control load points BASE and PEAK can be selected anytime after a start signal has been given. The selection will be displayed on the CRT. The unit will load to the selected load point. PRESELECTED LOAD is a load point greater than SPINNING RESERVE and less than BASE, typically 50%. The auto loading rate is shown in Control Specification-Settings Drawing. E. Remote Operation To transfer turbine control from the control compartment to remotely located equipment, select REMOTE on the CRT Main Display. The turbine may then be started, automatically synchronized, and loaded by the remote equipment. If manual synchronization is to be performed at the remote location, the synchronizing selector switch (43S) mounted on the generator control panel must be placed in the OFF/REMOTE position.
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Unit Operation/Turbine (Gas)
F. Shutdown and Cooldown 1. Normal Shutdown Normal shutdown is initiated by selecting STOP on the CRT Main Display. The shutdown procedure will follow automatically through generator unloading, turbine speed reduction, fuel shutoff at part speed and initiation of the cooldown sequence as the unit comes to rest. 2. Emergency Shutdown Emergency shutdown is initiated by depressing the EMERGENCY STOP pushbutton. An emergency shutdown can also be mechanically initiated by pushing the manual emergency trip valve on the gauge cabinet assembly, or the manual trip button on the overspeed trip mechanism mounted on the side of the accessory gear. Cooldown operation after emergency shutdown is also automatic provided the permissives for this operation are met. 3. Cooldown Immediately following a shutdown, after the turbine has been in the fired mode, the rotor is turned to provide uniform cooling. Uniform cooling of the turbine rotor prevents rotor bowing, resultant rubbing and imbalance, and related damage that might otherwise occur when subsequent starts are attempted without cooldown. The turbine can be started and loaded at any time during the cooldown cycle. The cooldown cycle may be accelerated using the starting device; in which case it will be operated at cranking speed. On units having an electric motor as the starting device, the operator must heed instructions regarding the length of time the motor can be operated without overheating. Refer to the control specifications. The device furnished for cooldown rotation on MS 5001P, MS 6001B, and MS 7001EA units is the hydraulic ratchet which is mounted as part of the torque converter. The ratchet cycles once every 3.0 minutes to turn the rotor 47°. A description of rotor turning operation and servicing can be found in the Starting System tab. The MS 9001E is a continuous turning gear system at 6.0 rpm. The minimum time required for turbine cooldown depends mainly on the turbine ambient temperature. Other factors, such as wind direction and velocity in outdoor installations and air drafts in indoor installations, can have an affect on the time required for cooldown. The cooldown times recommended in the following paragraphs are the result of GE Company operating experience in both factory and field testing of GE gas turbines. The purchaser may find that these times can be modified as experience is gained in operation of the gas turbine under his particular site conditions. Cooldown times should not be accelerated by opening up the turbine compartment doors or the lagging panels since uneven cooling of the outer casings may result in excessive stress. The unit must be on rotor turning operation immediately following a shutdown for at least 24 hours to ensure minimum protection against rubs and unbalance on a subsequent starting attempt. The GE Company, however, recommends that the rotor turning operation continue for 48 hours after shutdown to ensure uniform rotor cooling.
UOGTNODLN–18
Unit Operation/Turbine (Gas)
UOGTNODLN
To terminate the cooldown sequence, prior to timer timeout select the Auxiliary Control Display on the CRT. Select “RATCHET OFF”. This will cause the cooldown auxiliaries to be turned off. Similarly, by selecting the “RATCHET ON” target, the cooldown auxiliaries can be reinstated. G. Special Operations 1. Black Start Operation (Optional with Gas Turbines equipped with a diesel engine starting device) a. General Gas turbine operation under “black start” conditions is defined as a requirement to start and run the turbine when an external AC power source is not available. Diesel engines are normally utilized as starting equipment with other compatible steam or gas starting means optional. The prime DC controlling power for the turbine control system is derived from the unit battery. Ignition and internal AC control power is obtained through DC conversion circuitry within the SPEEDTRONIC power supply system. b. Operation When the turbine is started, the DC emergency lube pump will supply adequate lubrication until the accessory gear-driven main lube oil pump pressure is established. The emergency pump continues to run until the accelerating speed signal (14HA) indicates that the unit has accelerated to 50% speed. The emergency pump then shuts down if lube oil pressure switch (63QL) indicates adequate pressure. Black start operation also requires the addition of the 88HR DC hydraulic ratchet pump assembly. This unit furnishes the required hydraulic control oil pressure for operation of the starting clutch and ratchet assembly. For liquid fuel machines, fuel pressure delivered to the input of the turbine gear driven fuel pump is provided by a dc/ac powered fuel forwarding pump. The DC motor drives the pump until AC power is available to drive the AC motor. The turbine high pressure fuel oil requirements are satisfied by the normal accessory gear driven fuel pump. Gas turbine AC powered cooling system fan drive motors are operated from partial to full power by driven load generator output, as the gas turbine is brought up to operational speed level. During turbine shutdown and cooldown periods, the operational lube supply is again furnished by the emergency DC lube pump and the 88HR DC hydraulic ratchet supply pump assembly mentioned previously operates to turn the rotor. Refer to the Lube Oil and Hydraulic Oil Supply Schematic Piping Diagrams; and the SPEEDTRONIC Control instructions of this service manual for further related information.
UOGTNODLN–19
UOGTNODLN
Unit Operation/Turbine (Gas)
2. Fuel Transfer (Gas-Distillate Option) Fuel transfer is initiated using the Fuel Mixture Display on the CRT. When transferring from one fuel to the other, there is a thirty second delay before the transfer begins. For the gas-to-distillate transfer, the delay allows for filling the liquid fuel lines. For the distillate-to-gas transfer, the delay allows time for the speed ratio valve (and gas control valve) to modulate the inter volume gas pressure before the transfer begins. Once started, fuel transfer takes approximately thirty seconds. The transfer can be stopped at any fuel mixture proportion within limits as specified in the Control Specification-Settings Drawing by setting the FUEL MIX SETPOINT and then selecting MIX. Fuel transfer should be initiated prior to ignition or after the unit reaches operating speed. 3. Automatic Fuel Transfer On Low Gas Pressure (Gas-Distillate Option) In the event of low fuel gas pressure the turbine will transfer to liquid fuel. The transfer will occur with no delay for line filling. To return to gas fuel operation after an automatic transfer, manually reselect gas fuel. 4. Diesel Testing (Optional on MS 5001 and MS 6001 Units) The starting diesel may be tested either with the turbine operating or while shutdown. To test the diesel, first select the Auxiliary Control Display on the CRT. Select the “DIESEL TEST ON” target. The diesel can now be tested by operating the diesel test pushbutton located on the accessory base. The diesel will run at idle speed as long as the pushbutton is held in. (Do not exceed two (2) minutes.) 5. Jogging Turbine Rotor (MS 5001 and MS 6001 Units) A pushbutton (43HR) located on the accessory base is provided for manual jogging of the turbine shaft by means of the hydraulic ratchet. 6. Testing the Emergency DC Lube Pump The DC emergency pump may be tested using the test pushbutton on the motor starter. 7. Overspeed Trip Checks Overspeed trip system testing should be performed on an annual basis on peaking and intermittently used gas turbines. On continuously operated units, the test should be performed at each scheduled shutdown and after each major overhaul. All units should be tested after an extended shutdown period of two or more months unless otherwise specified in the Control Specifications-Adjustments Drawing. NOTE The turbine should be operated for at least 30 minutes at rated speed before checking the overspeed settings. This will allow determination of the actual trip speed, which might be higher or lower than the “cold” trip speed depending upon several contributing factors, such as oil temperature and vibration.
UOGTNODLN–20
Unit Operation/Turbine (Gas)
UOGTNODLN
8. Electrical Overspeed Turbine speed is controlled by the turbine speed reference signal TNR. The maximum speed called for by TNR is limited by the high speed stop control constant. This value is nominally set at 107% of rated speed. It will be necessary to enter a new constant value for the high speed stop constant that will allow the speed to increase above the electrical overspeed trip setting. New constants can be entered with the Control Constant Adjust display activated and via the keypad. Reference the control specification and the SPEEDTRONIC Mark V Maintenance Manual (GEH 5980) for details. For security, an identification code must be entered via the keypad in order to make any changes to the control system constants. With the high speed stop constant adjusted to be higher than the electrical overspeed trip speed, raise unit speed gradually by using the SPEED SP RAISE target on the Main Display and observe speed at which the unit trips against the value tabulated in the Control Specifications — Setting drawing. CAUTION 1. Do not exceed the maximum search speed as defined in the Control Specifications. 2. Return all constants to their normal value after coastdown of unit. 9. Mechanical Overspeed (if applicable) In order to test the mechanical overspeed bolt it is necessary to change the electrical overspeed trip setting constant to be greater than the mechanical overspeed bolt overspeed setting. After changing the required constants raise unit speed gradually by using the SPEED SP RAISE target on the Main Display and observe speed at which the unit trips against the value tabulated in the Control Specifications — Settings drawing. CAUTION 1. Do not exceed the maximum search speed as defined in the Control Specifications. 2. Return all constants to their normal values following tests. 3. Reset mechanical overspeed trip mechanism on unit accessory gear.
Record all trip speeds. Mechanical testing should also include the emergency trip button on the turbine control panel and the manual overspeed mechanical trip located on the right side of the accessory gear. Successful completion of the above tests will assure that all shutdown devices are operating correctly. To reduce the possibility of overspeed bolt trip system degradation where the trip speed becomes excessively high, especially after long periods of inactivity, it is recommended that the mechanical bolt be tested periodically by carefully overspeeding the turbine and noting the speed at which the trip occurs. If the trip does not occur within the limits, as defined in the Control Specifications, the bolt should be sparingly oiled in place with a lightweight machine oil, stroked by manually depressing the plunger several times through its stroke limits, and retested. The overspeed bolt should then be tripped three successive times within 1% of nominal trip speed and within 1% repeatability unless defined otherwise in the Control Specifications.
UOGTNODLN–21
UOGTNODLN
Unit Operation/Turbine (Gas) CAUTION 1. Do not exceed the maximum search speed as defined in the Control Specifications. 2. The turbine should not be operated unless the overspeed bolt, the overspeed trip mechanisms, the fuel stop valves and other shutdown devices are in reliable condition.
If a trip does not occur within reliable limits, refer to the adjustment instructions in the Service Manual, Protection System, Overspeed Bolt Assembly. If three successive trips do not occur within acceptable repeatability limits, see instructions for Maintenance and Replacement or contact your Field Service Representative for assistance. 10. Steam Injection Operation (Optional) Before operating the steam injection system for the first time following an overhaul or periods of extended shutdown, it is important that the following checks be made: a. Steam supply is within design parameters b. Instrument air supply is at required pressure c. Steam line orifice size is correct a. Pre-Operation Checks Prior to operation, check for the following conditions: a. CRT controls are in non-select positions (Steam Injection OFF) b. Manual stop valve is open c. All hand valves in line of flow are open d. All valves to temperature or pressure gauges are open e. Steam supply pressure and temperature are in operating range b. Startup The automatic control system, in conjunction with logic circuits of the microcomputer of the SPEEDTRONIC control system, operates the steam injection system control valving and assures that the proper amount of steam injection is provided to the turbine combustion system during operation. To initiate steam injection the operator must first select the Steam Injection Overview Display on the CRT. Selecting the STM INJ ON target initiates the steam injection control. At this point the automatic steam control circuits will take over, initiate the drain and stop valve sequences and control the system. When steam conditions are correct, the steam control valve releases steam into the combustion system at the proper steam-to-fuel flow ratio. The startup and operating sequence of the steam injection system is described and explained in the Steam Injection control system text of the Control and Protection Tab.
UOGTNODLN–22
Unit Operation/Turbine (Gas)
UOGTNODLN
c. Trouble Shooting The purpose of the system is to provide steam to the turbine combustion system at the desired pressure, temperature and flow. If this does not happen, the following problems may be the cause: (1) Steam supply exhausted (2) Insufficient supply pressure (3) Control valve closed (4) Stop valve closed The following should be checked: (1) Adequate steam supply (2) Check steam supply system (3) Check control valve actuator and drain valve operation (4) Check that instrument air supply pressure is sufficient and/or check solenoid control valve operation. Alarm and shutdown conditions of the steam injection system are detected by a protection program built into Control Sequence Program. Alarm and trip indications are displayed on the CRT. An alarm condition is initiated by high or low pressure levels and by high or low temperatures. See Control Specifications for alarm and trip point values. The computer program is designed to trip the steam stop valve and prevent steam flow if steam temperature becomes too high or too low. It can trip the system on temperature or pressure to protect against loss of superheat and carry over of condensate. Steam at too high a pressure can cause damage to valve stem packing and system seals. A steam injection trip only shuts down the steam injection system. It does not trip the turbine. 11. Water Washing System Operation (Optional) a. General Water washing should be scheduled during a normal shutdown, if possible. This will allow enough time for the internal machine temperature to drop to the required levels for the washing. The time required to cool the machine can be shortened by maintaining the unit at crank speed. During this cooling of the turbine, the wash water is to be heated to the proper level. b. Mandatory Precautions Before water washing of the compressor begins, the turbine blading temperature must be low enough so that the water does not cause thermal shock.
UOGTNODLN–23
UOGTNODLN
Unit Operation/Turbine (Gas) CAUTION The differential temperature between the wash water and the interstage wheelspace temperature must not be greater than 120°F (48.9°C) to prevent thermal shock to the hot gas parts. For wash water of 180°F (82.2°C), the maximum wheelspace temperature must be no greater than 300°F (148.9°C) as measured by the digital thermocouple readout system on the turbine control panel.
To reduce this difference, the wash water may be heated and the turbine kept on crank until the wheelspace temperatures drop to an acceptable level. The wheelspace temperatures are read in the control room on the CRT. CAUTION If, during operation, there has been an increase in exhaust temperature spread above the normal 15°F to 30°F (8.3°C to 16.6°C), the thermocouples in the exhaust plenum should be examined. If they are coated with ash, the ash should be removed. Radiation shields should also be checked. If they are not radially oriented relative to the turbine, they should be repositioned per the appropriate drawing. If the thermocouples are coated with ash, or if the radiation shields are not properly oriented, a correct temperature reading will not be obtained.
If neither of the above conditions exists and there is no other explanation for the temperature spread, consult the GE Installation and Service Engineering representative.
* * * WARNING * * * The water wash operation involves water under high pressure. Caution must be exercised to ensure the proper positioning of all valves during this operation. Since the water may also be hot, necessary precautions should be taken in handling valves, pipes, and potentially hot surfaces. NOTE Before water washing the compressor, inspect the inlet plenum and gas turbine bellmouth for large accumulations of atmospheric contaminants which could be washed into the compressor. These deposits can be removed by washing with a garden hose. c. Water Wash Procedures Refer to cleaning publication included in this section for details on procedures. 12. Standby Gas Turbines on Extended Shutdown The GE Company recommends the following procedures for gas turbines subject to extended shutdowns.
UOGTNODLN–24
Unit Operation/Turbine (Gas)
UOGTNODLN
a. The turbine rotor should be operated on turning gear or ratchet for one hour each day to prevent the buildup of corrosive deposits in the turbine wheel dovetails, OR b. The gas turbine should be operated at full speed, no load for one hour per week to dry the turbine out and thereby preventing moisture condensation in the turbine wheel dovetail crevices. IV. DESCRIPTION OF PANELS AND TERMS A. Turbine Control Panel (TCP) The turbine control panel contains the hardware and software required to operate the turbine. EMERGENCY STOP (5E) — This red pushbutton is located on the front of the TCP. Operation of this pushbutton immediately shuts off turbine fuel. BACKUP OPERATOR INTERFACE (BOI) — This interactive display is mounted on the front of the TCP. All operator commands can be issued from this module. In addition, alarm management can be performed and turbine parameters can be monitored from the . B. CRT The CRT is a personal computer that directly interfaces to the turbine control panel. This is the primary operator station. All operator commands can be issued from the CRT. Alarm management can be performed and turbine parameters can be monitored. With the proper password, editing can also be accomplished. 1. Main Display Operator selector targets and master control selector targets can be actuated from the main display by using the cursor positioning device (CPD). Operator selector targets include: OFF — Inhibits a start signal. CRANK — With crank selected, a start signal will bring the machine to cranking speed (14HM). FIRE — With FIRE selected, a START signal will bring the machine to minimum speed and establish flame in the combustors. Selecting FIRE while the machine is on CRANK will initiate the firing sequence and establish flame in the combustors. AUTO — With AUTO selected, a START signal will bring the machine to operating speed. Changing selections from FIRE to AUTO will allow the machine to accelerate to operating speed. REMOTE — With REMOTE selected, control for the unit is transferred to the remote control equipment. Master control selector targets include: START — A START selection will cause the unit to start. With AUTO selected, the unit will load to the SPINNING RESERVE load point.
UOGTNODLN–25
UOGTNODLN
Unit Operation/Turbine (Gas) FAST START - A FAST START selection will cause the unit to start. With AUTO selected, the unit will load to the PRESELECTED load point. The machine will load at the manual loading rate. STOP - A STOP selection will cause the unit to initiate a normal shutdown. All operator selector switches and master control selector targets are green and are located on the right side of the display. All green targets are the AUTO/EXECUTE type, which means that the target must be selected with the CPD and then, within three seconds, the EXECUTE target at the bottom of the display must also be selected in order to actuate that command.
2. Load Control Display Load selector targets can be actuated from the load control display by using the cursor positioning device (CPD). Load selector targets include: PRESEL - Select the preselected load point. BASE - Select base temperature control load point. *PEAK - Select peak temperature control load point. 3. *Fuel Mixture Display Fuel selector targets are used to select the desired fuel by using the cursor positioning device (CPD). Fuel selector targets include: GAS SELECT - 100% gas fuel operation. DIST SELECT - 100% distillate fuel operation. MIX SELECT - Selecting MIX while on 100% single fuel will cause the machine to transfer to mixed fuel operation at a preset mixture. 4. *Isochronous Setpoint Display Governor selector targets are used to select the desired type of speed control by using the cursor positioning device (CPD). Governor selector targets include: DROOP SELECT - Used to select droop speed control. ISOCH SELECT - Used to select isochronous speed control. 5. *Inlet Guide Vane Control Display The inlet guide vane (IGV) temperature control targets are IGV TEMP CNTL ON and IGV TEMP CNTL OFF. The IGV AUTO target selects normal operation of the IGVs. The IGV MANUAL target allows the maximum IGV angle to be manually set by the operator (not normally used while on-line).
*Optional equipment
UOGTNODLN–26
Unit Operation/Turbine (Gas)
UOGTNODLN
6. Alarm Display This screen displays the current un-reset alarms, the time when each alarm occurred, the alarm drop number and a word description of the alarm. An “*” indicates that the alarm has not been acknowledged. The “*” disappears after the alarm has been acknowledged. For more information, see the Mark V Users’ Manual (GEH 5979). 7. Auxiliary Display COOLDOWN ON and COOLDOWN OFF can be selected from this display. The DIESEL TEST ON and DIESEL TEST OFF targets (if diesel starting means is used) can also be selected from this display. Selecting the DIESEL TEST ON target enables the permissive which allows the Diesel Test Pushbutton to be manually operated. 8. *Mechanical Overspeed Test Display After selecting the ENABLE SOFTSW’s target, the OVERSPEED TEST HP target can be selected. This will adjust the electrical overspeed setpoint to allow testing of the mechanical overspeed equipment. 9. Manual Reset Target Selecting the manual reset target resets the Master Reset Lockout function. This target must be selected so that the unit can be restarted following a trip. C. Definition of Terms SPINNING RESERVE - The minimum load control point based on generator output. The spinning reserve magnitude in MWs can be found in the control specifications (5–10% of rating is a typical value). PRESELECTED LOAD - A load control point based on generator output. The preselected load point is adjustable within a range designated in the Control Specification. The preselected load point is normally set below the base load point (50–60% of rating is a typical value). BASE LOAD - This is the normal maximum loading for continuous turbine operation as determined by turbine exhaust temperature levels. PEAK LOAD (Optional) - This is the maximum allowable output permitted for relatively long-duration, emergency power requirement situations consistent with acceptable turbine parts life. Peak loading duration is based on turbine exhaust temperature levels. D. Generator Control Panel (Typical) SYNCHRONIZING LAMPS — Rough indication of the speed and phase relationship between the generator and the bus. FREQUENCY METER — Indicates generator frequency. INCOMING VOLTMETER — Indicates generator voltage.
UOGTNODLN–27
UOGTNODLN
Unit Operation/Turbine (Gas)
RUN VOLTMETER — Indicates bus voltage. SYNCHROSCOPE — Indicates the phase relationship between the generator and bus voltage. GENERATOR AMMETER — Indicates generator phase current. The phase current to be read is selected on the three position ammeter selector switch. GENERATOR WATTMETER — Indicates the generator output in megawatts. GENERATOR VARMETER — Indicates the generator reactive output in megavars. GENERATOR TEMPERATURE METER — (Traditionally included on the Generator Control Panel, but actually displayed in Mark V SPEEDTRONIC systems on the CRT.) Reads the generator Resistance Temperature Detector (RTD) selected by the temperature meter selector switch. EXCITER VOLTMETER — Indicates generator field voltage (if used). GENERATOR FIELD AMMETER — Indicates generator field amperes (if used). AMMETER SELECTOR SWITCH — See Generator Ammeter (above). SYNCHRONIZING SELECTOR SWITCH (43S/CS) — Three position switch used to select the synchronizing mode. Manual — Selects manual synchronizing mode. In this position the generator frequency and voltage, bus voltage, and phase relationship will be displayed to facilitate manual synchronizing. Off/Remote — Used when the unit is being controlled from the remote control equipment. Auto — Used for local automatic synchronizing. VOLTMETER SWITCH (VS) — Used to select the phase of the bus voltage to be displayed on the run voltmeter. TEMPERATURE METER SELECTOR SWITCH — Traditionally included on the Generator Control Panel, but actually displayed in Mark V SPEEDTRONIC systems on the CRT. VOLTAGE/VAR CONTROL SWITCH (90R4/CS) — Controls generator voltage when the unit is off the line, and controls voltage/vars when the machine is on the line. (Increase — Right; Decrease — Left; spring return to normal.) GENERATOR BREAKER CONTROL SWITCH (52G/CS) — Used to open or close the generator breaker. The indicator lights above the switch indicate Open (Green) and Closed (Red). NOTE Using this switch, the generator breaker should be closed only when proper synchronizing techniques are used or when the system onto which the generator is being brought is not energized. GENERATOR DIFFERENTIAL LOCK-OUT SWITCH (86G) — Manual reset lockout switch which operates in the event of a generator fault.
UOGTNODLN–28
Unit Operation/Turbine (Gas)
UOGTNODLN
GOVERNOR RAISE/LOWER CONTROL SWITCH (70R4/CS) — Used to control turbine speed when the generator is off the line (i.e. for manual synchronizing); generator load when the generator is on the line; and frequency when the generator is running isolated and on DROOP speed control. TRANSFORMER DIFFERENTIAL LOCK-OUT SWITCH (86T) — Manual reset lockout switch which operates in the event of a transformer fault. WATTHOUR METER — Measures the watthour output of the generator. E. Motor Control Center The turbine is provided with a motor control center for the control of the electrical auxiliaries. The motor control center includes AC and DC distribution systems. Motor controllers are used for auxiliaries such as motors and heaters. Each motor controller normally consists of a breaker, control power transformer, control circuit, power contactor, selector switch and indicator lights. The selector switch is normally left in AUTO. Each motor control center is also provided with AC and DC distribution panel boards with circuit breakers. F. Supervisory Remote Equipment Supervisory equipment is normally functionally the same as the equipment described in the cable connected master panel. However, it may differ somewhat in metering and indications. Refer to the supervisory manufacturer’s instruction manual for details. G. Annunciator System The attached alarm list is a maxcase of alarms that may be available. All alarms may not be used on this project. Alarms are displayed on the CRT when the ALARM Display mode is selected. Before clearing an alarm, action should be taken to determine the cause and perform the necessary corrective action. The following is a list of annunciator messages along with suggested operator action. NOTE The alarm messages can be categorized as either “trip” or “alarm”. The “trip” messages contain the word TRIP in the message. The “alarm” messages do not indicate TRIP. For those alarms associated with permissive to start and trip logics latched up through the MASTER RESET function, it will be necessary to call up the CRT Display with the Master Reset target in order to unlatch and clear these alarms.
UOGTNODLN–29
DT-1C
E
G
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O
SIZE
A3
DWG. NO.
SH.
132B8218
HMI CRM3 Server
BN Modbus TCP/IP+S1
Ethernet GSM
21" RS2 32
(1)
(1) (6)
(1)
PDH
UDH
(3)
E
UDH
UPS110VAC
21"
UDH
PDH
(3)
(1)
Laser Color Printer PRT1
HMI CRM2 Multi-Unit Server UPS110VAC
21"
UPS110VAC
UPS110VAC
(1) (1)
HMI CRM1 Multi-Unit Server
(moved from control room)
Network Time Server
Global Time Source (1)
REV.
Control Room
9G3
DCS
1
Laser Color Printer PRT2
UPS110VAC
PDH
HMI CRM4 Multi-Unit Server
UPS110VAC
UPS110VAC
21"
UDH
PDH
(3) (4)
(3) (4)
UDH
ADH
TRUNK
SW18
SW17
A PDH
P49A
UPS110VAC
UPS110VAC
PDH
UDH
ADH
TRUNK
P49A
B (1)
9G2 SW5
UPS110VAC
UPS110VAC
SW13
G60A
T60B
Mark VI
AVR EX2100
GPP G60B
UDH
R
EPM
S
RIM
T
TRUNK
G60B
G60A
EPM
T60B
RIM
M1
P49A
GCP
BN
C (from 9G4) (5) D (from 9G5) E (from 9G6)
V max
M2
UDH
M2
UDH
V max
PDH
Mark VI
AVR EX2100
GPP
M1
T
S
P50A
R ADH
ADH PDH
P48A
UPS110VAC
UPS110VAC
SW14
PDH
UDH
F (from 9G4) (5) G (from 9G5) H (from 9G6)
TRUNK
UPS110VAC
RS2 32
UDH
PDH
P50A UPS110VAC
20"
UPS110VAC
Hardware Link / Cable Remote to Scada Fiber Optic: (1) Single mode max 15 km length - SC type connectors UDH: Unit Data Highway. Unshielded Twisted Pair (UTP) cable, 4 pair, Category 5, RJ-45 connectors. Trunk: cross-over UTP cable is used to connect a switch to a switch. Fiber Optic: (2) Multimode max 2 km length - SC type connectors Time Synchronization: (1) Modulated IRIG-B time code signal, RG-58 Coaxial cable, BNC connector
K (from 9G4)
Alarm Printer
(2)
PDH: Plant Data Highway. (UTP) cable, 4 pair, Category 5, RJ-45 connectors.
L (from 9G4)
TRUNK
TRUNK
P48A
Alarm Printer
HMI 9G2 Single-Unit Server
ADH
ADH
UPS110VAC
20"
P49A
PDH
PDH
UDH
UDH
UDH
RS2 32
I (from 9G4)
same as 9G2
UPS110VAC
SW4
PDH
HMI 9G3 Single-Unit Server
J (from 9G4)
TRUNK
TRUNK
SW6
UPS110VAC
SW3
PDH
GCP
BN
M
9G1
(1) Customer Supply (2) Fiber optic between units is provided by GE (3) 21" LCD Color monitors provided by customer (4) One monitor displayed alarms (5) Only used during 9G3 and 9G4 commissionning. To be removed when other units available (6) Hardware signal exchange with DCS from each ECB
gGE Energy Products - Europe
SIZE
A3
4108 JAMNAGAR PROJECT
DRAWN by H Ginestous DATE DT-1C
21 December 2006
132B8218
DWG NO
SCALE
CONT ON
SHEET
1
SIZE
A3
DWG. NO.
SH.
132B8218
Laser Color Printer PRT3
BN Modbus TCP/IP+S1
Historian
UPS11 0VAC
(1) (1)
UPS110VAC
(1)
(1) (6)
110VAC UPS
UPS110VAC
UDH
HMI CRM6 Multi-Unit Server
HMI CRM5 Multi-Unit Server
UPS110VAC
21" (1) (1)
ROUTER1 (optional)
Laser Color Printer PRT4
Network Time Server 2
Global Time Source (1)
Ethernet GSM
E
Control Room
9G4
DCS
REV.
2
UPS110VAC
21"
PDH
UDH
(3)
UPS110VAC
21"
PDH
(3)
PERFORMANCE MONITOR
UDH
UPS110VAC
21"
OSM (optional) UPS110VAC
21"
UDH
PDH
PDH
(3)
(3)
PDH
(3)
A
PDH
UDH
TRUNK
P49A
UPS110VAC
(1)
ADH
SW20
SW19
B
UPS11 0VAC
PDH
UDH
ADH
TRUNK
P49A
(1) (6)
M
9G5 UPS110VAC
SW7
SW15
9G6
UPS110VAC
SW9
G60A
G60B
UDH
P49A
R
Mark VI
AVR EX2100
GPP T60B
S
EPM
T
RIM
M1
TRUNK
G60A
T60B
G60B
EPM
M2
GCP
BN
V max
M2
M1
T
S
P50A
R ADH
ADH
I (from 9G1) J (from 9G2) C (from 9G3) (5)
UDH
V max
UDH
RIM
Mark VI
AVR EX2100
GPP
PDH
PDH
GCP
BN
UPS110VAC
PDH
TRUNK
TRUNK
P48A
D (from 9G3) UPS110VAC
SW8
UPS110VAC
SW16
SW10
UDH
PDH
K (from 9G1) L (from 9G2) F (from 9G3) (5)
PDH
UPS110VAC
UDH
PDH
P50A UPS110VAC
20"
TRUNK
TRUNK
P48A
Alarm Printer
RS2 32
Alarm Printer
Hardware Link / Cable Remote to Scada Fiber Optic: (1) Single mode max 15 km length - SC type connectors UDH: Unit Data Highway. Unshielded Twisted Pair (UTP) cable, 4 pair, Category 5, RJ-45 connectors. Trunk: cross-over UTP cable is used to connect a switch to a switch.
G (from 9G3)
UPS110VAC
(2)
PDH: Plant Data Highway. (UTP) cable, 4 pair, Category 5, RJ-45 connectors.
ADH
HMI 9G5 Single-Unit Server
ADH
UPS110VAC
TRUNK
P49A 20"
UPS110VAC
UDH
UDH
UDH
RS2 32
E (from 9G3)
PDH
PDH
HMI 9G4 Single-Unit Server
same as 9G5
(1) Customer Supply (2) Fiber optic between units is provided by GE (3) 21" LCD Color monitors provided by customer (4) One monitor displayed alarms (5) Only used during 9G3 and 9G4 commissionning. To be removed when other units available (6) Hardware signal exchange with DCS from each ECB
gGE Energy Products - Europe
Fiber Optic: (2) Multimode max 2 km length - SC type connectors
DRAWN by H Ginestous
Time Synchronization: (1) Modulated IRIG-B time code signal, RG-58 Coaxial cable, BNC connector
DATE
21 December 2006
H (from 9G3)
SIZE
A3
132B8218
DWG NO
4108 JAMNAGAR PROJECT
SCALE
CONT ON
SHEET
2
SIZE
Switch : SW1 Location : ECB 9G1 Type : 323A4747NZP50A Port_1 GT1_SVR\PDHA Cat 5 Port_2 9G1\G60A Cat 5 Port_3 9G1\EPM Cat 5 Port_6 9G1\BN Cat 5 Port_7 9G1\BN\RIM Cat 5 Port_9 GT1_SVR\UDHA Cat 5 Port_10 9G1\R Cat 5 Port_13 9G1\M1 Cat 5 Port_20 SW2\Port_20 Crossover FOPort_1 9G3\SW13\FOPort_1 Fiber FOPort_2 9G4\SW15\FOPort_3 Fiber Switch : SW2 Location : ECB 9G1 Type : 323A4747NZP50A Port_1 GT1_SVR\PDHB Cat 5 Port_2 9G1\G60B Cat 5 Port_3 9G1\T60B Cat 5 Port_6 9G1\BN Cat 5 Port_9 GT1_SVR\UDHB Cat 5 Port_11 9G1\S Cat 5 Port_12 9G1\T Cat 5 Port_13 9G1\M2 Cat 5 Port_14 9G1\Vmax Cat 5 Port_20 SW1\Port_20 Crossover FOPort_1 9G3\SW14\FOPort_2 Fiber FOPort_2 9G4\SW16\FOPort_3 Fiber
A3
DWG. NO.
SH.
132B8218
PDH PDH PDH PDH PDH UDH UDH UDH Trunk FO FO
Switch : SW3 Location : ECB 9G2 Type : 323A4747NZP50A Port_1 GT2_SVR\PDHA Cat 5 Port_2 9G2\G60A Cat 5 Port_3 9G2\EPM Cat 5 Port_6 9G2\BN Cat 5 Port_7 9G2\BN\RIM Cat 5 Port_9 GT2_SVR\UDHA Cat 5 Port_10 9G2\R Cat 5 Port_13 9G2\M1 Cat 5 Port_20 SW4\Port_20 Crossover FOPort_1 9G3\SW13\FOPort_2 Fiber FOPort_2 9G4\SW15\FOPort_4 Fiber
PDH PDH PDH PDH PDH UDH UDH UDH Trunk FO FO
PDH PDH PDH PDH UDH UDH UDH UDH UDH Trunk FO FO
Switch : SW4 Location : ECB 9G2 Type : 323A4747NZP50A Port_1 GT2_SVR\PDHB Cat 5 Port_2 9G2\G60B Cat 5 Port_3 9G2\T60B Cat 5 Port_6 9G2\BN Cat 5 Port_9 GT2_SVR\UDHB Cat 5 Port_11 9G2\S Cat 5 Port_12 9G2\T Cat 5 Port_13 9G2\M2 Cat 5 Port_14 9G2\Vmax Cat 5 Port_20 SW3\Port_20 Crossover FOPort_1 9G3\SW14\FOPort_1 Fiber FOPort_2 9G4\SW16\FOPort_4 Fiber
PDH PDH PDH PDH UDH UDH UDH UDH UDH Trunk FO FO
Hardware Link / Cable Remote to Scada Fiber Optic: (1) Single mode max 15 km length - SC type connectors
Trunk: cross-over UTP cable is used to connect a switch to a switch.
DRAWN by H Ginestous
Time Synchronization: (1) Modulated IRIG-B time code signal, RG-58 Coaxial cable, BNC connector
DATE
21 December 2006
E
PDH PDH PDH PDH PDH PDH PDH PDH UDH UDH UDH UDH UDH Trunk FO
Switch : SW6 Location : ECB 9G3 Type : 323A4747NZP49A Port_1 GT3_SVR\PDHB Cat 5 Port_2 9G3\G60B Cat 5 Port_3 9G3\T60B Cat 5 Port_4 CRM3_SVR\PDHB Cat 5 Port_5 9G3_DCS\GSM-B_GT3_SVR Cat 5 Port_6 9G3\BN Cat 5 Port_7 9G3_DCS\BN-A Cat 5 Port_8 9G3_DCS\BN-RIM Cat 5 Port_9 GT3_SVR\UDHB Cat 5 Port_11 9G3\S Cat 5 Port_12 9G3\T Cat 5 Port_13 9G3\M2 Cat 5 Port_14 9G3\Vmax Cat 5 Port_15 CRM3_SVR\UDHB Cat 5 Port_20 SW14\Port_8 Crossover FOPort_1 CRM\SW18\FOPort_1 Fiber
PDH PDH PDH PDH PDH PDH PDH PDH UDH UDH UDH UDH UDH UDH Trunk FO
Switch : SW13 Location : Type : 323A4747NZP48A Port_8 SW5\Port_20 FOPort_1 9G1\SW1\FOPort_1 FOPort_2 9G2\SW3\FOPort_1 FOPort_3 9G4\SW15\FOPort_5 FOPort_4 9G5\SW9\FOPort_1 FOPort_5 9G6\SW11\FOPort_1
ECB 9G3 Trunk FO FO FO FO FO
Switch : SW14 Location : Type : 323A4747NZP48A Port_8 SW6\Port_20 FOPort_1 9G2\SW4\FOPort_1 FOPort_2 9G1\SW2\FOPort_1 FOPort_3 9G4\SW16\FOPort_5 FOPort_4 9G5\SW10\FOPort_1 FOPort_5 9G6\SW12\FOPort_1
ECB 9G3
gGE Energy Products - Europe
Fiber Optic: (2) Multimode max 2 km length - SC type connectors
REV.
Switch : SW5 Location : ECB 9G3 Type : 323A4747NZP49A Port_1 GT3_SVR\PDHA Cat 5 Port_2 9G3\G60A Cat 5 Port_3 9G3\EPM Cat 5 Port_4 CRM3_SVR\PDHA Cat 5 Port_5 9G3_DCS\GSM-A_GT3_SVR Cat 5 Port_6 9G3\BN Cat 5 Port_7 9G3\BN\RIM Cat 5 Port_8 Network Time Server 1\PDH Cat 5 Port_9 GT3_SVR\UDHA Cat 5 Port_10 9G3\R Cat 5 Port_13 9G3\M1 Cat 5 Port_15 CRM3_SVR\UDHA Cat 5 Port_16 Network Time Server 1\UDH Cat 5 Port_20 SW13\Port_8 Crossover FOPort_1 CRM\SW17\FOPort_1 Fiber
UDH: Unit Data Highway. Unshielded Twisted Pair (UTP) cable, 4 pair, Category 5, RJ-45 connectors. PDH: Plant Data Highway. (UTP) cable, 4 pair, Category 5, RJ-45 connectors.
3
SIZE
A3
Crossover Fiber Fiber Fiber Fiber Fiber
Crossover Fiber Fiber Fiber Fiber Fiber
Trunk FO FO FO FO FO
132B8218
DWG NO
4108 JAMNAGAR PROJECT
SCALE
CONT ON
SHEET
3
SIZE
Switch : SW7 Location : ECB 9G4 Type : 323A4747NZP49A Port_1 GT4_SVR\PDHA Cat 5 Port_2 9G4\G60A Cat 5 Port_3 9G4\EPM Cat 5 Port_5 9G4_DCS\GSM-A_GT4_SVR Cat 5 Port_6 9G4\BN Cat 5 Port_7 9G4\BN\RIM Cat 5 Port_8 Network Time Server 2\PDH Cat 5 Port_9 GT4_SVR\UDHA Cat 5 Port_10 9G4\R Cat 5 Port_13 9G4\M1 Cat 5 Port_16 Network Time Server 2\UDH Cat 5 Port_20 SW15\Port_8 Crossover FOPort_1 CRM\SW19\FOPort_1 Fiber
PDH PDH PDH PDH PDH PDH PDH UDH UDH UDH UDH Trunk FO
Switch : SW8 Location : ECB 9G4 Type : 323A4747NZP49A Port_1 GT4_SVR\PDHB Cat 5 Port_2 9G4\G60B Cat 5 Port_3 9G4\T60B Cat 5 Port_5 9G4_DCS\GSM-B_GT4_SVR Cat 5 Port_6 9G4\BN Cat 5 Port_7 9G4_DCS\BN-A Cat 5 Port_8 9G4_DCS\BN-RIM Cat 5 Port_9 GT4_SVR\UDHB Cat 5 Port_11 9G4\S Cat 5 Port_12 9G4\T Cat 5 Port_13 9G4\M2 Cat 5 Port_14 9G4\Vmax Cat 5 Port_20 SW16\Port_8 Crossover FOPort_1 CRM\SW20\FOPort_1 Fiber
PDH PDH PDH PDH PDH PDH PDH UDH UDH UDH UDH UDH Trunk FO
Switch : SW15 Location : Type : 323A4747NZP48A Port_8 SW7\Port_20 FOPort_1 9G6\SW11\FOPort_2 FOPort_2 9G5\SW9\FOPort_2 FOPort_3 9G1\SW1\FOPort_2 FOPort_4 9G2\SW3\FOPort_2 FOPort_5 9G3\SW13\FOPort_3
ECB 9G4 Trunk FO FO FO FO FO
Switch : SW16 Location : Type : 323A4747NZP48A Port_8 SW8\Port_20 FOPort_1 9G5\SW10\FOPort_2 FOPort_2 9G6\SW12\FOPort_2 FOPort_3 9G1\SW2\FOPort_2 FOPort_4 9G2\SW4\FOPort_2 FOPort_5 9G3\SW14\FOPort_3
ECB 9G4
Crossover Fiber Fiber Fiber Fiber Fiber
Crossover Fiber Fiber Fiber Fiber Fiber
A3
DWG. NO.
Switch : SW9 Location : ECB 9G5 Type : 323A4747NZP50A Port_1 GT5_SVR\PDHA Cat 5 Port_2 9G5\G60A Cat 5 Port_3 9G5\EPM Cat 5 Port_6 9G5\BN Cat 5 Port_7 9G5\BN\RIM Cat 5 Port_9 GT5_SVR\UDHA Cat 5 Port_10 9G5\R Cat 5 Port_13 9G5\M1 Cat 5 Port_20 SW10\Port_20 Crossover FOPort_1 9G3\SW13\FOPort_4 Fiber FOPort_2 9G4\SW15\FOPort_2 Fiber Switch : SW10 Location : Type : 323A4747NZP50A Port_1 GT5_SVR\PDHB Port_2 9G5\G60B Port_3 9G5\T60B Port_6 9G5\BN Port_9 GT5_SVR\UDHB Port_11 9G5\S Port_12 9G5\T Port_13 9G5\M2 Port_14 9G5\Vmax Port_20 SW9\Port_20 FOPort_1 9G3\SW14\FOPort_4 FOPort_2 9G4\SW16\FOPort_1
4
REV.
E
ECB 9G6
PDH PDH PDH PDH PDH UDH UDH UDH Trunk FO FO
Switch : SW11 Location : Type : 323A4747NZP50A Port_1 GT6_SVR\PDHA Port_2 9G6\G60A Port_3 9G6\EPM Port_6 9G6\BN Port_7 9G6\BN\RIM Port_9 GT6_SVR\UDHA Port_10 9G6\R Port_13 9G6\M1 Port_20 SW12\Port_20 FOPort_1 9G3\SW13\FOPort_5 FOPort_2 9G4\SW15\FOPort_1
ECB 9G6
PDH PDH PDH PDH UDH UDH UDH UDH UDH Trunk FO FO
Switch : SW12 Location : Type : 323A4747NZP50A Port_1 GT6_SVR\PDHB Port_2 9G6\G60B Port_3 9G6\T60B Port_6 9G6\BN Port_9 GT6_SVR\UDHB Port_11 9G6\S Port_12 9G6\T Port_13 9G6\M2 Port_14 9G6\Vmax Port_20 SW11\Port_20 FOPort_1 9G3\SW14\FOPort_5 FOPort_2 9G4\SW16\FOPort_2
ECB 9G5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Crossover Fiber Fiber
SH.
132B8218
Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Crossover Fiber Fiber
Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Crossover Fiber Fiber
PDH PDH PDH PDH PDH UDH UDH UDH Trunk FO FO
PDH PDH PDH PDH UDH UDH UDH UDH UDH Trunk FO FO
Trunk FO FO FO FO FO
Hardware Link / Cable Remote to Scada Fiber Optic: (1) Single mode max 15 km length - SC type connectors UDH: Unit Data Highway. Unshielded Twisted Pair (UTP) cable, 4 pair, Category 5, RJ-45 connectors. PDH: Plant Data Highway. (UTP) cable, 4 pair, Category 5, RJ-45 connectors. Trunk: cross-over UTP cable is used to connect a switch to a switch.
gGE Energy Products - Europe
Fiber Optic: (2) Multimode max 2 km length - SC type connectors
DRAWN by H Ginestous
Time Synchronization: (1) Modulated IRIG-B time code signal, RG-58 Coaxial cable, BNC connector
DATE
21 December 2006
SIZE
A3
132B8218
DWG NO
4108 JAMNAGAR PROJECT
SCALE
CONT ON
SHEET
4
SIZE
Switch : SW17 Location : Type : 323A4747NZP49A Port_1 CRM1_SVR\PDHA Port_2 CRM2_SVR\PDHA Port_4 CRM4_SVR\PDHA Port_7 Laser Printer PRT1 Port_9 CRM1_SVR\UDHA Port_10 CRM2_SVR\UDHA Port_12 CRM4_SVR\UDHA Port_20 SW18\Port_20 Port_21 SW19\Port_21 FOPort_1 9G3\SW5\FOPort_1
Control Room
Switch : SW18 Location : Type : 323A4747NZP49A Port_1 CRM1_SVR\PDHB Port_2 CRM2_SVR\PDHB Port_4 CRM4_SVR\PDHB Port_7 Laser Printer PRT2 Port_9 CRM1_SVR\UDHB Port_10 CRM2_SVR\UDHB Port_12 CRM4_SVR\UDHB Port_20 SW17\Port_20 Port_21 SW20\Port_21 FOPort_1 9G3\SW6\FOPort_1
Control Room
Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Crossover Crossover Fiber
Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Crossover Crossover Fiber
PDH PDH PDH PDH UDH UDH UDH Trunk Trunk FO
PDH PDH PDH PDH UDH UDH UDH Trunk Trunk FO
A3
DWG. NO.
SH.
132B8218
5
REV.
E
Switch : SW19 Location : Type : 323A4747NZP49A Port_1 HIST1_SVR\PDHA Port_2 PERF_MONITOR Port_3 OSM\PDHA Port_5 CRM5_SVR\PDHA Port_6 CRM6_SVR\PDHA Port_7 Laser Printer PRT3 Port_9 HIST1_SVR\UDHA Port_10 CRM5_SVR\UDHA Port_11 CRM6_SVR\UDHA Port_12 OSM\UDHA Port_20 SW20\Port_20 Port_21 SW17\Port_21 FOPort_1 9G4\SW7\FOPort_1
Control Room
Switch : SW20 Location : Type : 323A4747NZP49A Port_1 HIST1_SVR\PDHB Port_2 PERF_MONITOR Port_3 OSM\PDHA Port_5 CRM5_SVR\PDHB Port_6 CRM6_SVR\PDHB Port_7 Laser Printer PRT4 Port_9 HIST1_SVR\UDHB Port_11 OSM\UDHB Port_13 CRM5_SVR\UDHB Port_14 CRM6_SVR\UDHB Port_20 SW19\Port_20 Port_21 SW18\Port_21 FOPort_1 9G4\SW8\FOPort_1
Control Room
Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Crossover Crossover Fiber
Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Cat 5 Crossover Crossover Fiber
PDH PDH PDH PDH PDH PDH UDH UDH UDH UDH Trunk Trunk FO
PDH PDH PDH PDH PDH PDH UDH UDH UDH UDH Trunk Trunk FO
Hardware Link / Cable Remote to Scada Fiber Optic: (1) Single mode max 15 km length - SC type connectors UDH: Unit Data Highway. Unshielded Twisted Pair (UTP) cable, 4 pair, Category 5, RJ-45 connectors. PDH: Plant Data Highway. (UTP) cable, 4 pair, Category 5, RJ-45 connectors. Trunk: cross-over UTP cable is used to connect a switch to a switch.
gGE Energy Products - Europe
Fiber Optic: (2) Multimode max 2 km length - SC type connectors
DRAWN by H Ginestous
Time Synchronization: (1) Modulated IRIG-B time code signal, RG-58 Coaxial cable, BNC connector
DATE
21 December 2006
SIZE
A3
132B8218
DWG NO
4108 JAMNAGAR PROJECT
SCALE
CONT ON
SHEET
5
g SPEEDTRONIC™ Mark VI Turbine Control System Walter Barker Michael Cronin GE Power Systems Schenectady, NY
GER-4193A
GE Power Systems
SPEEDTRONIC™ Mark VI Turbine Control System Contents Introduction . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 Architecture. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 1 Triple Redundancy . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 2 I/O Interface. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 General Purpose I/O . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 3 Application Specific I/O. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 4 Operator Interface . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 7 Software Maintenance Tools . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Communications . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 8 Communication Link Options. . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 Time Synchronization . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 Diagnostics . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 10 Power . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 11 Codes and Standards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Safety Standards . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Printed Wire Board Assemblies . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 CE – Electromagnetic Compatibility (EMC) . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 CE – Low Voltage Directive . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Environment . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Temperature . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Humidity . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 12 Elevation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Gas Contaminants . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Dust Contaminants . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Seismic Universal Building Code (UBC). . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Documentation . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Manuals . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 Drawings . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 13 List of Figures . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14 List of Tables . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . 14
GE Power Systems GER-4193A (10/00) ■
■
i
SPEEDTRONIC™ Mark VI Turbine Control System
GE Power Systems GER-4193A (10/00) ■
■
ii
SPEEDTRONIC™ Mark VI Turbine Control System Introduction
Architecture
The SPEEDTRONIC™ Mark VI turbine control is the current state-of-the-art control for GE turbines that have a heritage of more than 30 years of successful operation. It is designed as a complete integrated control, protection, and monitoring system for generator and mechanical drive applications of gas and steam turbines. It is also an ideal platform for integrating all power island and balance-of-plant controls. Hardware and software are designed with close coordination between GE’s turbine design engineering and controls engineering to insure that your control system provides the optimum turbine performance and you receive a true “system” solution. With Mark VI, you receive the benefits of GE’s unmatched experience with an advanced turbine control platform. (See Figure 1.)
The heart of the control system is the Control Module, which is available in either a 13- or 21slot standard VME card rack. Inputs are received by the Control Module through termination boards with either barrier or box-type terminal blocks and passive signal conditioning. Each I/O card contains a TMS320C32 DSP processor to digitally filter the data before conversion to 32 bit IEEE-854 floating point format. The data is then placed in dual port memory that is accessible by the on-board C32 DSP on one side and the VME bus on the other. In addition to the I/O cards, the Control Module contains an “internal” communication card, a main processor card, and sometimes a flash disk card. Each card takes one slot except for the main processor that takes two slots. Cards are manufactured with surface-mounted technology and conformal coated per IPC-CC830. I/O data is transmitted on the VME backplane between the I/O cards and the VCMI card located in slot 1. The VCMI is used for “internal” communications between: ■ I/O cards that are contained within its card rack ■ I/O cards that may be contained in expansion I/O racks called Interface Modules
• Over 30 years experience • Complete control, protection, and monitoring • Can be used in variety of applications • Designed by GE turbine and controls engineering
Figure 1. Benefits of Speedtronic™ Mark VI GE Power Systems GER-4193A (10/00) ■
■
■ I/O in backup Protection Modules ■ I/O in other Control Modules used in triple redundant control configurations ■ The main processor card The main processor card executes the bulk of the application software at 10, 20, or 40 ms depending on the requirements of the application. Since most applications require that spe1
SPEEDTRONIC™ Mark VI Turbine Control System cific parts of the control run at faster rates (i.e. servo loops, pyrometers, etc.), the distributed processor system between the main processor and the dedicated I/O processors is very important for optimum system performance. A QNX operating system is used for real-time applications with multi-tasking, priority-driven preemptive scheduling, and fast-context switching. Communication of data between the Control Module and other modules within the Mark VI control system is performed on IONet. The VCMI card in the Control Module is the IONet bus master communicating on an Ethernet 10Base2 network to slave stations. A unique poling type protocol (Asynchronous Drives Language) is used to make the IONet more deterministic than traditional Ethernet LANs. An optional Genius Bus™ interface can be provided on the main processor card in Mark VI Simplex controls for communication with the GE Fanuc family of remote I/O blocks. These blocks can be selected with the same software configuration tools that select Mark VI I/O cards, and the data is resident in the same database. The Control Module is used for control, protection, and monitoring functions, but some applications require backup protection. For example, backup emergency overspeed protection is always provided for turbines that do not have a mechanical overspeed bolt, and backup synch check protection is commonly provided for generator drives. In these applications, the IONet is extended to a Backup Protection Module that is available in Simplex and triple redundant forms. The triple redundant version contains three independent sections (power supply, processor, I/O) that can be replaced while the turbine is running. IONet is used to access diagnostic data or for cross-tripping between the Control Module and the
GE Power Systems GER-4193A (10/00) ■
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Protection Module, but it is not required for tripping.
Triple Redundancy Mark VI control systems are available in Simplex and Triple Redundant forms for small applications and large integrated systems with control ranging from a single module to many distributed modules. The name Triple Module Redundant (TMR) is derived from the basic architecture with three completely separate and independent Control Modules, power supplies, and IONets. Mark VI is the third generation of triple redundant control systems that were pioneered by GE in 1983. System throughput enables operation of up to nine, 21-slot VME racks of I/O cards at 40 ms including voting the data. Inputs are voted in software in a scheme called Software Implemented Fault Tolerance (SIFT). The VCMI card in each Control Module receives inputs from the Control Module back-plane and other modules via “its own” IONet. Data from the VCMI cards in each of the three Control Modules is then exchanged and voted prior to transmitting the data to the main processor cards for execution of the application software. Output voting is extended to the turbine with three coil servos for control valves and 2 out of 3 relays for critical outputs such as hydraulic trip solenoids. Other forms of output voting are available, including a median select of 4-20ma outputs for process control and 0200ma outputs for positioners. Sensor interface for TMR controls can be either single, dual, triple redundant, or combinations of redundancy levels. The TMR architecture supports riding through a single point failure in the electronics and repair of the defective card or module while the process is running. Adding sensor redundancy increases the fault tolerance
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SPEEDTRONIC™ Mark VI Turbine Control System of the overall “system.” Another TMR feature is the ability to distinguish between field sensor faults and internal electronics faults. Diagnostics continuously monitor the 3 sets of input electronics and alarms any discrepancies between them as an internal fault versus a sensor fault. In addition, all three main processors continue to execute the correct “voted” input data. (See Figure 2.) Other GE ToTo Other GE Control Systems Control Systems
Operator Maintenance Operator /Maintenance Interface Interface Communications to DCS
Unit Data Highway Unit Data Highway Ethernet Ethernet
CIMPLICITY RDisplay System CIMPLICITY® Display System WindowsNT TM OperatingSystem Windows NT™ Operating System
CommunicationsToDCS 1.RS232 RS232 Modbus Modbus Slave/Master Slave/Master 1. Ethernet TCP-IP Slave 2.Ethernet TCP-IPModbus Modbus Slave 3. GSM 3.Ethernet Ethernet TCP-IP TCP-IPGSM
BackupProtection 1.Emergency Emergency Overspeed 1. Overspeed 2. Synch Synch Check Check Protection 2. Protection
Protection Module Protection Module
Control Module Control Module
P S
X
P.S. P.S. CPU CPU I/O I/O
Y
P.S. P.S. CPU CPU I/O I/O
Z
P.S. P.S. CPU CPU I/O I/O
Redundant Unit
RedundantUnit Data Highway Data Highway (Required) (ifrequired)
Ethernet Ethernet- IONet - IONet
Software SoftwareVoting Voting
Control Module Control Module
P S
Ethernet Ethernet --IONet IONet
Control Module Control Module
P S
Ethernet - IONet Ethernet - IONet
Figure 2. Mark VI TMR control configuration
I/O Interface There are two types of termination boards. One type has two 24-point, barrier-type terminal blocks that can be unplugged for field maintenance. These are available for Simplex and TMR controls. They can accept two 3.0 mm2 (#12AWG) wires with 300 volt insulation. Another type of termination board used on Simplex controls is mounted on a DIN rail and
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I/O devices on the equipment can be mounted up to 300 meters (984 feet) from the termination boards, and the termination boards must be within 15 m (49.2’) from their corresponding I/O cards. Normally, the termination boards are mounted in vertical columns in termination cabinets with pre-assigned cable lengths and routing to minimize exposure to emi-rfi for noise sensitive signals such as speed inputs and servo loops.
Backup Protection
Primary Controllers Primary Controllers 1. Control 1. Control 2.2.Protection Protection 3. 3.Monitoring Monitoring
Ethernet Ethernet
has one, fixed, box-type terminal block. It can accept one 3.0 mm2 (#12AWG) wire or two 2.0 mm2 (#14AWG) wires with 300 volt insulation.
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General Purpose I/O Discrete I/O. A VCRC card provides 48 digital inputs and 24 digital outputs. The I/O is divided between 2 Termination Boards for the contact inputs and another 2 for the relay outputs. (See Table 1.) Analog I/O. A VAIC card provides 20 analog inputs and 4 analog outputs. The I/O is divided between 2 Termination Boards. A VAOC is dedicated to 16 analog outputs and interfaces with 1 barrier-type Termination Board or 2 box-type Termination Boards. (See Table 2.) Temperature Monitoring. A VTCC card provides interface to 24 thermocouples, and a VRTD card provides interface for 16 RTDs. The input cards interface with 1 barrier-type TB
Type
I/O
TBCI
Barrier
24 CI
DTCI
Box
24 CI
TICI
Barrier
24 CI
TRLY
Barrier
12 CO
DRLY
Box
12 CO
Characteristics 70-145Vdc, optical isolation, 1ms SOE 2.5ma/point except last 3 input are 10ma / point 18-32Vdc, optical isolation, 1ms SOE 2.5ma/point except last 3 input are 10ma/point 70-145Vdc, 200-250Vdc, 90-132Vrms, 190-264Vrms (47-63Hz), optical isolation 1ms SOE, 3ma / point Plug-in, magnetic relays, dry, form “C” contacts 6 circuits with fused 3.2A, suppressed solenoid outputs Form H1B: diagnostics for coil current Form H1C: diagnostics for contact voltage Voltage Resistive Inductive 24Vdc 3.0A 3.0 amps L/R = 7 ms, no suppr. 3.0 amps L/R = 100 ms, with suppr 125Vdc 0.6A 0.2 amps L/R = 7 ms, no suppr. 0.6 amps L/R = 100 ms, with suppr 120/240Vac 6/3A 2.0 amps pf = 0.4 Same as TRLY, but no solenoid circuits
Table 1. Discrete I/O 3
SPEEDTRONIC™ Mark VI Turbine Control System
Analog I/O TB TBAI
Type Barrier
I/O 10 AI 2 AO
TBAO
Barrier
16 AO
DTAI
Box
10 AI 2 AO
DTAO
Box
8 AO
Characteristics (8) 4-20ma (250 ohms) or +/-5,10Vdc inputs (2) 4-20ma (250 ohms) or +/-1ma (500 ohms) inputs Current limited +24Vdc provided per input (2) +24V, 0.2A current limited power sources (1) 4-20ma output (500 ohms) (1) 4-20ma (500 ohms) or 0-200ma (50 ohms) output (16) 4-20ma outputs (500 ohms) (8) 4-20ma (250 ohms) or +/-5,10Vdc inputs (2) 4-20ma (250 ohms) or +/-1ma (500 ohms) inputs Current limited +24Vdc available per input (1) 4-20ma output (500 ohms) (1) 4-20ma (500 ohms) or 0-200ma (50 ohms) output (8) 4-20ma outputs (500 ohms)
Table 2. Analog I/O Termination Board or 2 box-type Termination Boards. Capacity for monitoring 9 additional thermocouples is provided in the Backup Protection Module. (See Table 3.) Temperature Monitoring TB TBTC
Type Barrier
I/O 24 TC
DTTC TRTD
Box Barrier
12 TC 16 RTD
DTAI
Box
8 RTD
Characteristics Types: E, J, K, T, grounded or ungrounded H1A fanned (paralleled) inputs, H1B dedicated inputs Types: E, J, K, T, grounded or ungrounded 3 points/RTD, grounded or ungrounded 10 ohm copper, 100/200 ohm platinum, 120 ohm nick H1A fanned (paralleled) inputs, H1B dedicated inputs RTDs, 3 points/RTD, grounded or ungrounded 10 ohm copper, 100/200 ohm platinum, 120 ohm nick
Table 3. Temperature Monitoring
Application Specific I/O In addition to general purpose I/O, the Mark VI has a large variety of cards that are designed for direct interface to unique sensors and actuators. This reduces or eliminates a substantial amount of interposing instrumentation in many applications. As a result, many potential single-point failures are eliminated in the most critical area for improved running reliability and reduced long-term maintenance. Direct interface to the sensors and actuators also enables the diagnostics to directly interrogate the devices on the equipment for maximum effectiveness. This data is used to analyze device and system performance. A subtle benefit of this design is that spare-parts inventories are
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reduced by eliminating peripheral instrumentation. The VTUR card is designed to integrate several of the unique sensor interfaces used in turbine control systems on a single card. In some applications, it works in conjunction with the I/O interface in the Backup Protection Module described below. Speed (Pulse Rate) Inputs. Four-speed inputs from passive magnetic sensors are monitored by the VTUR card. Another two-speed (pulse rate) inputs can be monitored by the servo card VSVO which can interface with either passive or active speed sensors. Pulse rate inputs on the VSVO are commonly used for flow-divider feedback in servo loops. The frequency range is 214k Hz with sufficient sensitivity at 2 Hz to detect zero speed from a 60-toothed wheel. Two additional passive speed sensors can be monitored by “each” of the three sections of the Backup Protection Module used for emergency overspeed protection on turbines that do not have a mechanical overspeed bolt. IONet is used to communicate diagnostic and process data between the Backup Protection Module and the Control Module(s) including cross-tripping capability; however, both modules will initiate system trips independent of the IONet. (See Table 4 and Table 5.) Synchronizing. The synchronizing system consists of automatic synchronizing, manual synchronizing, and backup synch check protection. Two single-phase PT inputs are provided VTUR I/O Terminations from Control Module TB TTUR
Type Barrier
TRPG* TRPS* TRPL* DTUR DRLY DTRT
Barrier
Box Box
I/O 4 Pulse rate 2 PTs Synch relays 2 SVM 3 Trip solenoids 8 Flame inputs
Characteristics Passive magnetic speed sensors (2-14k Hz) Single phase PTs for synchronizing Auto/Manual synchronizing interface Shaft voltage / current monitor (-) side of interface to hydraulic trip solenoids UV flame scanner inputs (Honeywell)
4 Pulse Rate 12 Relays
Passive magnetic speed sensors (2-14k Hz) Form “C” contacts – previously described Transition board between VTUR & DRLY
Table 4. VTUR I/O terminations from Control Module
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SPEEDTRONIC™ Mark VI Turbine Control System
VPRO I/O Terminations from Backup Protection Module TB TPRO
Type Barrier
TREG* TRES* TREL*
Barrier
I/O 9 Pulse rate 2 PTs 3 Analog inputs 9 TC inputs 3 Trip solenoids 8 Trip contact in
Characteristics Passive magnetic speed sensors (2-14k Hz) Single phase PTs for backup synch check (1) 4-20ma (250 ohm) or +/-5,10Vdc inputs (2) 4-20ma (250 ohm) Thermocouples, grounded or ungrounded (+) side of interface to hydraulic trip solenoids 1 E-stop (24Vdc) & 7 Manual trips (125Vdc)
Table 5. VPRO I/O terminations from Backup Protection Module on the TTUR Termination Board to monitor the generator and line busses via the VTUR card. Turbine speed is matched to the line frequency, and the generator and line voltages are matched prior to giving a command to close the breaker via the TTUR. An external synch check relay is connected in series with the internal K25P synch permissive relay and the K25 auto synch relay via the TTUR. Feedback of the actual breaker closing time is provided by a 52G/a contact from the generator breaker (not an auxiliary relay) to update the database. An internal K25A synch check relay is provided on the TTUR; however, the backup phase / slip calculation for this relay is performed in the Backup Protection Module or via an external backup synch check relay. Manual synchronizing is available from an operator station on the network or from a synchroscope. Shaft Voltage and Current Monitor. Voltage can build up across the oil film of bearings until a discharge occurs. Repeated discharge and arcing can cause a pitted and roughened bearing surface that will eventually fail through accelerated mechanical wear. The VTUR / TTUR can continuously monitor the shaft-to- ground voltage and current, and alarm at excessive levels. Test circuits are provided to check the alarm functions and the continuity of wiring to the brush assembly that is mounted between the turbine and the generator.
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Flame Detection. The existence of flame either can be calculated from turbine parameters that are already being monitored or from a direct interface to Reuter Stokes or Honeywell-type flame detectors. These detectors monitor the flame in the combustion chamber by detecting UV radiation emitted by the flame. The Reuter Stokes detectors produce a 4-20ma input. For Honeywell flame scanners, the Mark VI supplies the 335Vdc excitation and the VTUR / TRPG monitors the pulses of current being generated. This determines if carbon buildup or other contaminates on the scanner window are causing reduced light detection. Trip System. On turbines that do not have a mechanical overspeed bolt, the control can issue a trip command either from the main processor card to the VTUR card in the Control Module(s) or from the Backup Protection Module. Hydraulic trip solenoids are wired with the negative side of the 24Vdc/125Vdc circuit connected to the TRPG, which is driven from the VTUR in the Control Module(s) and the positive side connected to the TREG which is driven from the VPRO in each section of the Backup Protection Module. A typical system trip initiated in the Control Module(s) will cause the analog control to drive the servo valve actuators closed, which stops fuel or steam flow and de-energizes (or energizes) the hydraulic trip solenoids from the VTUR and TRPG. If crosstripping is used or an overspeed condition is detected, then the VTUR/TRPG will trip one side of the solenoids and the VPTRO/TREG will trip the other side of the solenoid(s). Servo Valve Interface. A VSVO card provides 4 servo channels with selectable current drivers, feedback from LVDTs, LVDRs, or ratio metric LVDTs, and pulse-rate inputs from flow divider feedback used on some liquid fuel systems. In TMR applications, 3 coil servos are commonly
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SPEEDTRONIC™ Mark VI Turbine Control System used to extend the voting of analog outs to the servo coils. Two coil servos can also be used. One, two, or three LVDT/Rs feedback sensors can be used per servo channel with a high select, low select, or median select made in software. At least 2 LVDT/Rs are recommended for TMR applications because each sensor requires an AC excitation source. (See Table 6 and Table 7.) TB TSVO
Type Barrier
I/O 2 chnls.
DSVO
Box
2 chnls.
Characteristics (2) Servo current sources (6) LVDT/LVDR feedback 0 to 7.0 Vrms (4) Excitation sources 7 Vrms, 3.2k Hz (2) Pulse rate inputs (2-14k Hz) *only 2 per VSVO (2) Servo current sources (6) LVDT/LVDR feedback 0 to 7.0 Vrms (2) Excitation sources 7 Vrms, 3.2k Hz (2) Pulse rate inputs (2-14k Hz) *only 2 per VSVO
Table 6. VSVO I/O terminations from Control Module
mination board can be provided with active isolation amplifiers to buffer the sensor signals from BNC connectors. These connectors can be used to access real-time data by remote vibration analysis equipment. In addition, a direct plug connection is available from the termination board to a Bently Nevada 3500 monitor. The 16 vibration inputs, 8 DC position inputs, and 2 Keyphasor inputs on the VVIB are divided between 2 TVIB termination boards for 3,000 rpm and 3,600 rpm applications. Faster shaft speeds may require faster sampling rates on the VVIB processor, resulting in reduced vibration inputs from 16-to-8. (See Table 8.) VVIB I/O Terminations from Control Module TB TVIB
Type Barrier
I/O 8 Vibr.
4 Pos. 1 KP
Characteristics Seismic, Proximitor, Velomitor, accelerometer charge amplifier DC inputs Keyphasor Current limited –24Vdc provided per probe
Nominal Servo Valve Ratings Coil Type #1 #2 #3 #4 #5 #6 #7
Nominal Current +/- 10 ma +/- 20 ma +/- 40 ma +/- 40 ma +/- 80 ma +/- 120 ma +/- 120 ma
Coil Resistance 1,000 ohms 125 ohms 62 ohms 89 ohms 22 ohms 40 ohms 75 ohms
Mark VI Control Simplex & TMR Simplex Simplex TMR TMR Simplex TMR
Table 7. Nominal servo valve ratings Vibration / Proximitor® Inputs. The VVIB card provides a direct interface to seismic (velocity), Proximitor®, Velomitor®, and accelerometer (via charge amplifier) probes. In addition, DC position inputs are available for axial measurements and Keyphasor® inputs are provided. Displays show the 1X and unfiltered vibration levels and the 1X vibration phase angle. -24vdc is supplied from the control to each Proximitor with current limiting per point. An optional ter-
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Table 8. VVIB I/O terminations from Control Module Three phase PT and CT monitoring. The VGEN card serves a dual role as an interface for 3 phase PTs and 1 phase CTs as well as a specialized control for Power-Load Unbalance and Early-Valve Actuation on large reheat steam turbines. The I/O interface is split between the TGEN Termination Board for the PT and CT inputs and the TRLY Termination Board for relay outputs to the fast acting solenoids. 420ma inputs are also provided on the TGEN for monitoring pressure transducers. If an EX2000 Generator Excitation System is controlling the generator, then 3 phase PT and CT data is communicated to the Mark VI on the network rather than using the VGEN card. (See Table 9.) Optical Pyrometer Inputs. The VPYR card moni-
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SPEEDTRONIC™ Mark VI Turbine Control System
TB TGEN
Type Barrier
I/O 2 PTs 3 CTs 4 AI
TRLY
Barrier
12 CO
Characteristics 3 Phase PTs, 115Vrms 5-66 Hz, 3 wire, open delta 1 Phase CTs, 0-5A (10A over range) 5-66 Hz 4-20ma (250 ohms) or +/-5,10Vdc inputs Current limited +24Vdc/input Plug-in magnetic relays previously described
■ A backup operator interface to the plant DCS operator interface ■ A gateway for communication links to other control systems ■ A permanent or temporary maintenance station ■ An engineer’s workstation
Table 9. VGEN I/O terminations from Control Module tors two LAND infrared pyrometers to create a temperature profile of rotating turbine blades. Separate, current limited +24Vdc and –24Vdc sources are provided for each Pyrometer that returns four 4-20ma inputs. Two Keyphasors are used for the shaft reference. The VPYR and matching TPYR support 5,100 rpm shaft speeds and can be configured to monitor up to 92 buckets with 30 samples per bucket. (See Table 10.) TB TPYR
Type Barrier
I/O 2 Pyrometers
Characteristics (8) 4-20ma (100 ohms) (2) Current limited +24Vdc sources (2) Current limited -24Vdc sources (2) Keyphasor inputs
Table 10. VPYR I/O terminations from Control Module
Operator Interface The operator interface is commonly referred to as the Human Machine Interface (HMI). It is a PC with a Microsoft® Windows NT® operating system supporting client/server capability, a CIMPLICITY® graphics display system, a Control System Toolbox for maintenance, and a software interface for the Mark VI and other control systems on the network. (See Figure 3.) It can be applied as: ■ The primary operator interface for one or multiple units GE Power Systems GER-4193A (10/00) ■
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Figure 3. Operator interface graphics: 7FA Mark VI All control and protection is resident in the Mark VI control, which allows the HMI to be a non-essential component of the control system. It can be reinitialized or replaced with the process running with no impact on the control system. The HMI communicates with the main processor card in the Control Module via the Ethernet based Unit Data Highway (UDH). All analog and digital data in the Mark VI is accessible for HMI screens including the high resolution time tags for alarms and events. System (process) alarms and diagnostics alarms for fault conditions are time tagged at frame rate (10/20/40 ms) in the Mark VI control and transmitted to the HMI alarm management system. System events are time tagged at frame rate, and Sequence of Events (SOE) for contact inputs are time tagged at 1ms on the contact input card in the Control Module. Alarms can 7
SPEEDTRONIC™ Mark VI Turbine Control System be sorted according to ID, Resource, Device, Time, and Priority. Operators can add comments to alarm messages or link specific alarm messages to supporting graphics. Data is displayed in either English or Metric engineering units with a one-second refresh rate and a maximum of one second to repaint a typical display graphic. Operator commands can be issued by either incrementing / decrementing a setpoint or entering a numerical value for the new setpoint. Responses to these commands can be observed on the screen one second from the time the command was issued. Security for HMI users is important to restrict access to certain maintenance functions such as editors and tuning capability, and to limit certain operations. A system called “User Accounts” is provided to limit access or use of particular HMI features. This is done through the Windows NT User Manager administration program that supports five user account levels.
Software Maintenance Tools The Mark VI is a fully programmable control system. Application software is created from inhouse software automation tools which select proven GE control and protection algorithms and integrate them with the I/O, sequencing, and displays for each application. A library of software is provided with general-purpose blocks, math blocks, macros, and application specific blocks. It uses 32-bit floating point data (IEEE-854) in a QNX operating system with real-time applications, multitasking, prioritydriven preemptive scheduling, and fast context switching. Software frame rates of 10, 20, and 40 ms are supported. This is the elapsed time that it takes to read inputs, condition the inputs, execute the application software, and send outputs. Changes to the application software can be
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made with password protection (5 levels) and downloaded to the Control Module while the process is running. All application software is stored in the Control Module in non-volatile flash memory. Application software is executed sequentially and represented in its dynamic state in a ladder diagram format. Maintenance personnel can add, delete, or change analog loops, sequencing logic, tuning constants, etc. Data points can be selected and “dragged” on the screen from one block to another to simplify editing. Other features include logic forcing, analog forcing, and trending at frame rate. Application software documentation is created directly from the source code and printed at the site. This includes the primary elementary diagram, I/O assignments, the settings of tuning constants, etc. The software maintenance tools (Control System Toolbox) are available in the HMI and as a separate software package for virtually any Windows 95 or NT based PC. The same tools are used for EX2000 Generator Excitation Systems, and Static Starters. (See Figure 4 and Figure 5.)
Communications Communications are provided for internal data transfer within a single Mark VI control; communications between Mark VI controls and peer GE control systems; and external communications to remote systems such as a plant distributed control system (DCS). The Unit Data Highway (UDH) is an Ethernetbased LAN with peer-to-peer communication between Mark VI controls, EX2000 Generator Excitation Controls, Static Starters, the GE Fanuc family of PLC based controls, HMIs, and Historians. The network uses Ethernet Global Data (EGD) which is a message-based protocol with support for sharing information with mul-
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SPEEDTRONIC™ Mark VI Turbine Control System control. All trips between units are hardwired even if the UDH is redundant.
Figure 4. Software maintenance tools – card configuration
Relay Ladder Diagram Editor for Boolean Functions
Figure 5. Software maintenance tools – editors tiple nodes based on the UDP/IP standard (RFC 768). Data can be transmitted Unicast, Multicast or Broadcast to peer control systems. Data (4K) can be shared with up to 10 nodes at 25Hz (40ms). A variety of other proprietary protocols are used with EGD to optimize communication performance on the UDH. 40 ms is fast enough to close control loops on the UDH; however, control loops are normally closed within each unit control. Variations of this exist, such as transmitting setpoints between turbine controls and generator controls for voltage matching and var/power-factor
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The UDH communication driver is located on the Main Processor Card in the Mark VI. This is the same card that executes the turbine application software; therefore, there are no potential communication failure points between the main turbine processor and other controls or monitoring systems on the UDH. In TMR systems, there are three separate processor cards executing identical application software from identical databases. Two of the UDH drivers are normally connected to one switch, and the other UDH driver is connected to the other switch in a star configuration. Network topologies conform to Ethernet IEEE 802.3 standards. The GE networks are a Class “C” Private Internet according to RFC 1918: Address Allocation for Private Internets – February 1996. Internet Assigned Numbers Authority (IANA) has reserved the following IP address space 192.168.1.1: 192.168.255.255 (192.168/ 16 prefix). Communication links from the Mark VI to remote computers can be implemented from either an optional RS232 Modbus port on the main processor card in Simplex systems, or from a variety of communication drivers from the HMI. When the HMI is used for the communication interface, an Ethernet card in the HMI provides an interface to the UDH, and a second Ethernet card provides an interface to the remote computer. All operator commands that can be issued from an HMI can be issued from a remote computer through the HMI(s) to the Mark VI(s), and the remote computer can monitor any application software data in the Mark VI(s). Approximately 500 data points per control are of interest to a plant control system; however, about 1,200
9
SPEEDTRONIC™ Mark VI Turbine Control System points are commonly accessed through the communication links to support programming screen attributes such as changing the color of a valve when it opens.
Communication Link Options Communication link options include: ■ An RS-232 port with Modbus Slave RTU or ASCII communications from the Main Processor Card. (Simplex: full capability. TMR: monitor data only – no commands) ■ An RS-232 port with Modbus Master / Slave RTU protocol is available from the HMI. ■ An RS-232/485 converter (halfduplex) can be supplied to convert the RS-232 link for a multi-drop network. ■ Modbus protocol can be supplied on an Ethernet physical layer with TCP-IP for faster communication rates from the HMI. ■ Ethernet TCP-IP can be supplied with a GSM application layer to support the transmission of the local highresolution time tags in the control to a DCS from the HMI. This link offers spontaneous transmission of alarms and events, and common request messages that can be sent to the HMI including control commands and alarm queue commands. Typical commands include momentary logical commands and analog “setpoint target” commands. Alarm queue commands consist of silence (plant alarm horn) and reset commands as well as alarm dump requests that cause the entire alarm queue to be transmitted from the Mark VI to the DCS. GE Power Systems GER-4193A (10/00) ■
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■ Additional “master” communication drivers are available from the HMI.
Time Synchronization Time synchronization is available to synchronize all controls and HMIs on the UDH to a Global Time Source (GTS). Typical GTSs are Global Positioning Satellite (GPS) receivers such as the StarTime GPS Clock or other timeprocessing hardware. The preferred time sources are Universal Time Coordinated (UTC) or GPS; however, the time synchronization option also supports a GTS using local time as its base time reference. The GTS supplies a time-link network to one or more HMIs with a time/frequency processor board. When the HMI receives the time signal, it is sent to the Mark VI(s) using Network Time Protocol (NTP) which synchronizes the units to within +/-1ms time coherence. Time sources that are supported include IRIG-A, IRIG-B, 2137, NASA36, and local signals.
Diagnostics Each circuit card in the Control Module contains system (software) limit checking, high/low (hardware) limit checking, and comprehensive diagnostics for abnormal hardware conditions. System limit checking consists of 2 limits for every analog input signal, which can be set in engineering units for high/high, high/low, or low/low with the I/O Configurator. In addition, each input limit can be set for latching/nonlatching and enable/disable. Logic outputs from system limit checking are generated per frame and are available in the database (signal space) for use in control sequencing and alarm messages. High/low (hardware) limit checking is provided on each analog input with typically 2 occurrences required before initiating an alarm. These limits are not configurable, and they are 10
SPEEDTRONIC™ Mark VI Turbine Control System selected to be outside the normal control requirements range but inside the linear hardware operational range (before the hardware reaches saturation). Diagnostic messages for hardware limit checks and all other hardware diagnostics for the card can be accessed with the software maintenance tools (Control System Toolbox). A composite logic output is provided in the data base for each card, and another logic output is provided to indicate a high/low (hardware) limit fault of any analog input or the associated communications for that signal. The alarm management system collects and time stamps the diagnostic alarm messages at frame rate in the Control Module and displays the alarms on the HMI. Communication links to a plant DCS can contain both the software (system) diagnostics and composite hardware diagnostics with varying degrees of capability depending on the protocol’s ability to transmit the local time tags. Separate manual reset commands are required for hardware and system (software) diagnostic alarms assuming that the alarms were originally designated as latching alarms, and no alarms will reset if the original cause of the alarm is still present. Hardware diagnostic alarms are displayed on the yellow “status” LED on the card front. Each card front includes 3 LEDs and a reset at the top of the card along with serial and parallel ports. The LEDs include: RUN: Green; FAIL: Red; STATUS: Yellow. Each circuit card and termination board in the system contains a serial number, board type, and hardware revision that can be displayed; 37 pin “D” type connector cables are used to interface between the Termination Boards and the J3 and J4 connectors on the bottom of the Control Module. Each connector comes with latching fasteners and a unique label identify-
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ing the correct termination point. One wire in each connector is dedicated to transmitting an identification message with a bar-code serial number, board type, hardware revision, and a connection location to the corresponding I/O card in the Control Module.
Power In many applications, the control cabinet is powered from a 125Vdc battery system and short circuit protected external to the control. Both sides of the floating 125Vdc bus are continuously monitored with respect to ground, and a diagnostic alarm is initiated if a ground is detected on either side of the 125Vdc source. When a 120/240vac source is used, a power converter isolates the source with an isolation transformer and rectifies it to 125Vdc. A diode high select circuit chooses the highest of the 125Vdc busses to distribute to the Power Distribution Module. A second 120/240vac source can be provided for redundancy. Diagnostics produce an under-voltage alarm if either of the AC sources drop below the undervoltage setting. For gas turbine applications, a separate 120/240vac source is required for the ignition transformers with short circuit protection of 20A or less. The resultant “internal” 125Vdc is fuse-isolated in the Mark VI power distribution module and fed to the internal power supplies for the Control Modules, any expansion modules, and the termination boards for its field contact inputs and field solenoids. Additional 3.2A fuse protection is provided on the termination board TRLY for each solenoid. Separate 120Vac feeds are provided from the motor control center for any AC solenoids and ignition transformers on gas turbines. (See Table 11.)
11
SPEEDTRONIC™ Mark VI Turbine Control System
Steady State Voltage 125Vdc (100 to 144Vdc) 120vac (108 to 132vac) 240vac (200 to 264vac)
Freq.
Load
Comments
10.0 A dc
Ripple DEMAND /FILE:{FILENAME}.DM2
where {filename}.DM2 is a Demand Display filename such as OPERATOR.DM2.
Commands and Arguments To configure Demand Display more specifically from the command line, type DEMAND then any of the following arguments at the command prompt, as needed: • The /UNIT: argument starts the Demand Display program for the unit specified. For example: F:\RUNTIME>DEMAND /UNIT:T1
The unit name must be a valid unit. Selecting an invalid unit or no unit displays the Unit Selection dialog box. Single unit sites ignore this argument and default to the single unit. • The /FILE: argument executes the Demand Display program and loads a requested Demand Display file. For example: F:\RUNTIME>DEMAND /FILE:OPERATOR.DM2
or F:\RUNTIME>DEMAND /FILE:F:\RUNTIME\OPERATOR.DM2
Incorrect entries cause error messages.
This argument requires permission to read the file and/or directory. Entering an invalid path or filename displays an error message and a blank, untitled Demand Display file. When entering no filename, the program attempts to open the default file F:\RUNTIME\DEMAND01.DM2. If it cannot open the file, the program displays an error message and a blank file.
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• The /DISPLAY: argument displays the screen in a particular file. For example: F:\RUNTIME>DEMAND /FILE:OPERATOR.DM2 /DISPLAY:”LUBE OIL”
If the screen name is invalid, the program displays the menu for the file requested. If the file is invalid, a blank, untitled file displays. • The /TYPE: argument displays the data screen with points specified at the command line. For example: F:\RUNTIME>DEMAND /TYPE:(L1,F4)
The program displays a blank Demand Display file if the point types are invalid. If a filename is entered, it ignores the point types.
Using Multiple Arguments You can enter multiple arguments to configure Demand Display more specifically. The following combination rules apply: • File and Display ignores the Type argument • File ignores an invalid Display argument • Type can only be used with the Unit argument or alone • Unit can be used with any other argument, unless it is a single unit system (then the Unit is ignored • Unit ignores any following invalid argument • Display requires a File argument preceding it Examples of valid combinations: F:\RUNTIME>DEMAND /UNIT:T2 /FILE:OPERATOR.DM2/DISPLAY:”LUBE OIL”
or F:\RUNTIME> DEMAND/UNIT:T2 /TYPE:(F4)
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Alarm Logger Control This program is used with Mark IV, V, V LM, and VI controllers.
Several classes of turbine control actions can be automatically logged to a printer. The HMI’s Alarm Logger allows you to select alarms and events to output to the printer using the Alarm Logger Control dialog box (see Figure 4-8). The Alarm Logger Control does not access any files when making its changes. Instead, it writes its output to a special section of global memory that is then read by the Alarm Logger program, which writes the alarms and events to the alarm printer. Note Alarm Logger Control does not configure individual points.
Exits dialog box without saving changes.
Process identification data
Saves selections and exits. Cancels changes and exits.
Click on drop-down box arrow to select unit (displayed in alphanumeric order).
Applies current unit’s settings to all units. Immediately deletes all pending alarm print jobs for all units from the Alarm Printer (does not require OK to be selected).
There are four functions (categories of information that can be printed. Click on box to select. (Blank is unselected; a check is selected.) You can select each function on a unit basis by selecting the Unit and Function, then OK button. Figure 4-8. Alarm Logger Control Dialog Box
Starting the Alarm Logger Control You can start the Alarm Logger Control program any of four ways:
You can use the command line arguments to customize the Alarm Logger Control startup.
•
Double-click the program icon (if it is available on the desktop).
•
On the Windows desktop, select Start, Turbine Control Maintenance Group, Unit T#, then Alarm Logger Control.
•
Enter logger.exe in the Run dialog box in the Start menu.
•
Enter logger.exe at the DOS command line, then press Enter.
To quickly display the desired configuration, start the Alarm Logger Control from the DOS command line with following argument: G:\EXEC\LOGGER.EXE /UNIT:T1
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specifies the unit name as T1
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Hold List (Steam Applications) This program is used with Mark V and Mark VI controllers.
The Hold List is required for the HMI to support Mark V controllers on systems that have Automatic Turbine Startup (ATS). The ATS code resides in ROM in the processor only. ATS is active only when the Automatic mode is selected. It is used to set speed control targets and valve positions based on various inputs (such as steam temperatures and pressures, calculated valve stresses, turbine rotor stresses, and turbine shell stresses, metal temperatures, speed and operating mode.) Turbine operating conditions may cause a hold, which prevents ATS from setting the speed or load target to a higher value. In the HMI, the Hold List display enables you to view the current points on the Hold List and to override any or all hold points, if desired. Overriding a hold allows the ATS to advance its targets as operating conditions permit.
Hold List Points The points for the Hold list are listed in the HMI unit configuration directory F:\UNITN\TOTT_B.SRC file. The list can hold 64 points, maximum. The points are either Alarms or Events, which display on the Alarm and Event Logger. This file must be compiled by the table compiler G:\EXEC\TABLE_C.EXE. For Mark V, the point list is then downloaded to and processors with the EEPROM downloader G:\EXEC\EEPROM.EXE. Select TOTT for the section to download. Reboot the processors activate any list changes.
Hold List Programs For Mark V, the Hold List is maintained in the and processors by programs in PROM. The Hold List receiver in the HMI is automatically started by the TCI system service. Refer to Chapter 2 and Appendix B for more information on alarm displays.
The CIMPLICITY Alarm Viewer displays the Hold List on the HMI. You should configure a separate CIMPLICITY Alarm Viewer for the Hold List to allow only the holds from a given unit on the display and to exclude holds from the regular alarm list. You can change this at any time.
Hold List Rules The Hold List is maintained according to the following rules: • A point that is picked up is entered in the Hold List as (0 - > 1). • Unacknowledged entries have an N character in the ACK field. • Acknowledged entries have a Y character in the ACK field. • A hold point whose state is a picked up (logic 1) displays the ALARM state. • A hold point whose state is a dropped out (logic 0) displays the NORMAL state. • A point has been acknowledged is removed from the Hold List display.
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• A picked up hold point may be overridden by an operator using the Lock command button. • An overridden point displays Locked as the first part of their long name text. • An overridden point loses its override when it drops out (1 -> 0). • The Hold List displays the time of the last pickup or override, unit, acknowledge state, current state, override status, and the short and long name of each hold point in the list. • The text Hold displays in the drop number field and the CSDB offset displays in the reference field. The reference field is typically not displayed. • The Hold List program in , not , outputs a logic signal indicating that there are one or more active holds that have not been overridden. This point is named L68DW_ATS_HL. ATS and the turbine control use this signal to set speed, load, and valve position targets.
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Notes
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Chapter 5 CIMPLICITY Displays
Introduction The CIMPLICITY HMI product must be installed before these applications can be used.
The CIMPLICITY HMI collects data from plant sensors and devices, then transforms the data into dynamic text, alarm, and graphic displays. Operators can access real-time information when monitoring and making control decisions. The turbine control HMI supports many CIMPLICITY applications for operation.
GFK-1180 provides a detailed description of the CIMPLICITY display features.
CIMPLICITY is used primarily to display turbine status screens, which enable an operator to monitor the unit(s). Refresh rate is typically 1 second. CIMPLICITY cannot configure the turbine control. CIMPLICITY supports OLE and ActiveX applications for automation displays. CIMB (CIMPLICITY Bridge) enables CIMPLICITY to collect data and alarms from a turbine unit with Mark V. (Mark VI used EGD) TCIMB provides the following software functions: • MARKV_RP collects data from a turbine using TCI and forwards the information to the CIMPLICITY Point Manager. • EXTMGR collects alarms and forwards them to the CIMPLICITY Alarm Manager. (See Chapter 6.) • LOCKOUT sends a lockout command to a unit using TCI. (See Extended Alarm Commands below.) • SILENCE sends a silence command to a unit using TCI. (See Extended Alarm Commands below.) This chapter identifies these functions, as follows: Section
Page
CIMPLICITY ActiveX Objects................................................................................5-2 Manual Synchronizing Display .........................................................................5-2 Triggered Plot (Valve Travel) ...........................................................................5-6 Alarm Filtering in HMI Servers ...............................................................................5-8 Configuring Users .............................................................................................5-8 Configuring Resources ....................................................................................5-12 Configuring Alarm Filters ...............................................................................5-14 Examples of Screens for Filtered Alarms........................................................5-23 Currently Implemented Filters ........................................................................5-25 Extended Alarm Commands...................................................................................5-26 Reactive Capability Display ...................................................................................5-28
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CIMPLICITY ActiveX Objects Microsoft Corporation developed ActiveX controls originally to support the creation of Internet-enabled applications.
ActiveX controls allow different types of software objects to communicate if the software supports ActiveX. The controls are interactive within an application. They can be gauges, charts, displays, graphs, or any other object that allows a user to access the particular functionality of the object.
Mark V, V LM.
Manual Synchronizing Display
For operator control, the HMI includes two CIMPLICITY add-ons supplied by Industrial Systems (Salem, VA) and identified as ActiveX objects: Manual Synchronizing Display and Triggered Plot. These are described below.
To bring a generator online with a power grid, the speed (frequency) and phase angle of the generator’s ac waveform must match that of the power grid. The preferred method is to use the turbine controller’s auto-synchronizing function. OLE is “Object Linking and Embedding” (see the Glossary for a more detailed definition).
For Mark V and V LM, a Manual Sync Object (an OLE object) is provided in CIMPLICITY HMI to allow the user to see a display representing this synchronization process (see Figure 5-1). The object contains all the fields that need to be updated at a fast rate. For Mark V and V LM, all data in the object is updated at 16 Hz. For Mark VI, this operation is at 10 Hz. The Manual Synchronizing Display must be run from a CIMPLICITY server for the desired controller. This is because the object uses the messaging services of TCI. The object consists of five parts, which you can set using tabs on the CIMPLICITY HMI Properties dialog box for that object. These tabs are described below. Synchroscope -Configure using Scope tab
Resets green dots at end of pointer (see Figure 5-2)
Breaker close times -Configure using Breaker tab Breaker Trip and Breaker Close buttons -Configure using Buttons tab (see Note below) Values that need updating quickly -- Configure using Values tab
Permissives needed to close the breaker -- Configure using Permissives tab.
Figure 5-1. Manual Sync Object (Used in CIMPLICITY HMI)
Note When you push the Breaker Close or Breaker Trip button, a dialog box displays with two buttons for command confirmation: • Command sends the breaker close or trip command when selected and released • Done exits the dialog box and cancels the breaker close or trip command
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Configuring the Synchroscope To configure the Synchroscope part of the object, enter parameters into the Scope tab. Name of ActiveX control
Signal that drives synchroscope pointer. Pointer is positioned at this angle as long as slip frequency is less than the Maximum slip frequency.
Select unit from drop-down list. Signal used to determine current slip frequency. If greater than maximum slip frequency, pointer is positioned at bottom of scope. Maximum slip frequency. Locations marks on scope. Entered in degrees separated by spaces. (Optional.) Signal used to change pointer color. If signal is not defined, pointer is white. If true, pointer is green. If false, pointer is red.
(Optional.) Signal indicating state of Sync relay. Each time signal is true and pointer is updated, a green dot is drawn at end of pointer. Scope’s R button (located top right; see Figure 5-1) is used to reset dots.
Configuring Breaker Close Times To configure the object’s breaker close times, enter values into the Breaker tab. BMS Socket (usually 15) used to obtain TCEA diagnostic message. (Message is how object gets breaker close times.) I/O Processor (usually 2F hex) used to obtain TCEA diagnostic message. Diagnostic Message type (usually 5).
Offset (usually 40) into the Diagnostic Message to the Nominal Close Time value.
Offset (usually 42) into the diagnostic message to the Learned Close Time value.
Offset (usually 48) into the diagnostic message to the Actual Close Time value.
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Configuring Permissives To configure the Permissives part of the object, add or edit the list entries in the Permissives tab.
Logic signal used.
String displayed next to box. Permissives display in object in the same order as in list box.
Determines color of box displayed by variable. If variable value equals Sense value, box is green. If not equal, box is red with a dash next to it.
Move currently selected entry up one row in the list.
Add entries to list.
Move currently selected entry down one row in list.
Delete currently selected entry. Edit currently selected entry.
Configuring Breaker Close and Trip Buttons To configure the object’s Breaker Close and Breaker Trip buttons, enter parameters into the Buttons tab.
(Optional.) Signal to send Breaker Close pushbutton command to. If not filled in, button is not displayed. Set length of pushbutton command in duration box. (Optional.) Signal to send the Breaker Trip pushbutton command to. If not filled in, button is not displayed. Set length of pushbutton command in duration box.
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Configuring Values To configure the object’s Values, enter data into the Value tab. Values in display in the object in the same order as in the list box Sets number of digits for displaying the value. Uses number of decimal places and units string specified in the scale code. Signal used for the value. String that displays to the left of the value.
Add entries to end of list. Apply to the currently selected entry. Up moves currently selected entry up one row; Down moves it down one row.
Configuring Object Colors The change colors in the object, edit the Colors tab.
Box shows current color of selection (Background or Foreground)
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Click down arrow to select area to change – Background or Foreground (text) color Click to change color of selection.
Chapter 5 CIMPLICITY Displays • 5-5
Mark V, V LM
Triggered Plot (Valve Travel) The Triggered Plot function is an ActiveX object that provides a graph of high-speed turbine data. The graph can be triggered by the change in state of a logic signal in the unit. Turbine commands can be sent from here, making it useful for initiating turbine tests (such as valve travel tests). Like the Manual Synchronizing Display, Triggered Plot is run from a CIMPLICITY server for the desired controller (see Figure 5-2). You configure the object by setting configuration information on the Triggered Plot Control Properties tabs, which is a CIMPLICITY HMI Properties dialog box (see Figure 5-3).
Plotted data displays within graph box, up to two data points versus time. Data (status points) collected at a sample rate of 8 times per second for an elapsed time of 1 to 120 seconds, as selected by user. Updates once per second. Plot is triggered by user-specified logic signal and its desired state to trigger.
Figure 5-2. Inactive Triggered Plot Screen
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Configuring Object Properties There are six tabs for configuring Triggered Plot Control Properties (see Figure 5-3).
Specify up to 2 pushbuttons for sending commands to unit
Set status points (up to 8) and position on the display.
Select object colors.
Elapsed time for data collection (1 to 120 sec.)
Select unit from drop-down list Name of variable that determines beginning of test State of trigger to begin the plot Plot points for left and right axis Range for low and high plot (in raw counts) Select color for each plot line Selected plot points are plotted from the time the trigger first reaches the specified state until the end of the entered elapsed time. Figure 5-3. Inactive Triggered Plot Screen Showing Version Window
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Alarm Filtering in HMI Servers GFK-1180 provides a detailed description of the CIMPLICITY display features.
Normally, all alarms for the roles assigned to your CIMPLICITY User ID are displayed in the separate Alarm Viewer window (an OCX control). You can also filter alarms to display subsets using the Alarm Setups dialog box. The Alarm Filter feature allows specific displays for alarms. These can be based on: • Various Resources or Types. An example of a resource would be each single Gas or Steam Turbine, the Exciter, BOP, or the system itself. • Alarm type or function (for example, Diagnostic, Process, Low, Medium, High). To configure alarms for filtering in HMI servers, you need to do the following: 1. Configure users 2. Configure resources 3. Configure the alarm filters All procedures must be followed and completed in the order presented. It is good practice to check off each procedure when you complete it. For this purpose, this chapter includes checkboxes next to each procedure heading Note The procedures in this section require that you have a working knowledge of CIMPLICITY, including its Workbench application, User Configuration, Resource Configuration, and various aspects of Alarms. Document GFK-1180 provides this information.
Configuring Users A user is an individual person working with a CIMPLICITY HMI project. Each CIMPLICITY HMI user has the following attributes, which must be configured: Security – A user may be assigned a Password. If a Password is configured and enabled, then a user cannot access CIMPLICITY HMI project functions without entering both the User ID and Password. Roles and Privileges – A user is assigned a role. Each role in the CIMPLICITY HMI project has certain privileges assigned to it. The privileges define the functions the user can access. If a user lacks the privilege to access a secure function, an error message is displayed and access is denied. View of Resources – A user’s view determines the accessible resource data. Alarms for resources outside a user’s view do not display on the user’s Alarm Viewer window. ¨ All procedures in this section were completed successfully.
Ø To configure Users for the CIMPLICITY HMI project 1. Open the project in the CIMPLICITY Workbench (refer to Chapter 6 for an overview). 2. In the Workbench left pane under the Security folder, select below.
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Users, as shown
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Left pane displays CIMPLICITY application folders
Select
Right pane displays files or records of selected object.
3. Open the New User dialog box and add a new user called OPERATOR. Type in the new name (User ID) then click OK.
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4. Open the User Properties dialog box for the user OPERATOR and enter Operator as the User name.
Select tab.
Type in the new User Name then click OK.
The Resources properties let you define the resources for which the user can view alarms.
5. Select the Resources tab and add all resources T1 through T8. Select tab.
Displays resources currently assigned to user.
To add resources, select from Available box then click Add .
Note Resources can be added or removed based on the User’s rights. For example if you want to have a User name as User1 who is supposed to operate only Gas Turbine T1 (GT1), then add only T1 as the Resource for the User1.
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6. Define the Role Properties for the user OPERATOR, as shown below.
Select options
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Click boxes to select
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Configuring Resources ¨ All procedures in this section were completed successfully.
Ø To configure Resources for the CIMPLICITY HMI project 1. In the Workbench left pane under the Security folder, select shown in the figure below.
Resources, as
Select
2. Add a New Resource T1 and click OK, as shown in the figure below. Type in the new name (Resource ID) then click OK.
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3. Add the Resource Definition for T1, as shown in the figure below. Type in Description.
Displays Users currently assigned to Resource. To add Users for this Resource, select from Available Users box, then click Add.
Displays Users available for this Resource.
4. Using the procedures in steps 2 and 3, add resources from T1 to T8 for GT1 to GT8, as shown in the figure below.
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Configuring Alarm Filters ¨ All procedures in this section were completed successfully.
Ø To configure Alarm Filters for the CIMPLICITY HMI project 1.
In the Workbench left pane under the Advanced folder, select
Alarm
Classes, as shown below.
Select
2. Add an Alarm Class named DIAG, as show below.
Type in
Select The Order value is the priority for the Alarms that fall under that particular class. The lower the Order number, the higher the priority. Select options
Click to apply inputs Click to exit
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3. Using the procedures in step 2, add the classes and descriptions shown in the figure below.
Enter values as shown here into Alarm Class dialog box (as shown in step 2).
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Colors selected in Alarm Class dialog box are displayed as a numerical equivalent here.
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4.
In the Workbench left pane as shown below, select Screens. Alarm.cim (standard template from Cimproj) then displays in the right panel. Select Alarm.cim.
1. Select
2. Select
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5. Right click in CimEdit, then select Edit to open the following Alarms screen. Open Frame Container from the menu, as shown below.
Select
Note CIMPLICITY HMI uses frame animation (frame containers) to navigate between individual screens. This enables you to access all control and monitoring features needed. The frame displayed can be changed by clicking buttons or other frames.
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6. Right click in CimEdit, then select CIMPLICITY AMV Control Object and Properties from the menu, as shown below. This displays the CIMPLICITY AMV Control Properties dialog box.
1. Select 2. Select
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7. Add the project, by clicking Add Project, as shown below.
Select (the Select Project dialog box displays).
Projects are listed here after being added.
For servers, select. (Connect to the remote project only when the alarm is not available locally
Select the project from the dropdown list. Click OK. The project displays in the Projects tab.
8. In Projects tab, double-click the newly added project ALARM_FILTER. This displays the Project Settings dialog box, as shown below. Add the Alarm setup as shown below.
Type in
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Click to select Alarm setup and exit back to the previous Projects dialog box.
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Project and Setup listed. Select to apply changes, thus adding new project.
9. Open the Alarm.cim file in CimVview and click Setup, as shown below. The Alarm Setup dialog box displays.
Click
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Bet sure to include the “$” symbol at the beginning of the Setup name. This makes it accessible to all users. Without the symbol, it can be accessed only by the user account that created it.
10. Add a Setup called $DIAG_GT1, as shown below.
Type in Setup name Click The Modify Setup box then displays (see below).
11. Select the Classes tab, then select DIAG from the list box.
Click Click (Do not click OK)
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12. Select the Resources tab. Then select T1 from the list box and OK to return to the Alarm Setups dialog box, as shown below. Click
Click
Click
13. Click Save to save this setup.
14. Follow the same procedure (steps 10 to 13) to create other setup.
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Examples of Screens for Filtered Alarms After configuring filtered alarms, triggered alarms display according to the filter setup for that particular screen. Figures 5-4 through 5-6 show examples.
Figure 5-4. Screen for Gas Turbine T1, Displaying Alarm Only for T1
Note Typically the top alarm window is for process alarms and the bottom one for diagnostic alarms.
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Figure 5-5. Screen for Gas Turbine T2, Displaying Alarm Only for T2
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Figure 5-6. Screen for All, Displaying Alarms for All
Currently Implemented Filters Available setups: • $DIAG_GT1 (TO GT8) • $PROC_GT1 (TO GT8) • $EX200_GT1 (TO GT8) or $EX2K_GT1 (TO GT8) • $ALL • $SYSTEM • $BOP
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Extended Alarm Commands To display alarms, a standalone Alarm Viewer is embedded into a CIMPLICITY screen.
Custom TCI commands are used to enhance the CIMPLICITY Alarm Viewer for turbine applications. These include the Silence and Lockout (Lock and Unlock), which are configured as buttons in the CIMPLICITY Alarm Viewer. Silence, Lock, and Unlock buttons are usually configured so that you must highlight and select an alarm before pressing the buttons.
Ø To edit custom alarm features for the Silence, Lock, and Unlock buttons 1. Right-click on the white background of the Alarm window. A menu displays, as shown below. 2. Select CIMPLICITY AMV Control Object, then Properties. The properties window displays. Make the Buttons tab selections, as shown in the figure below.
Select tab to display Button properties options. Select to move highlighted button up or down.
Button list. Highlight button name to select for modifying.
Select to modify highlighted button’s properties.
Select to display the Lock, Unlock, and Silence button list. (A different list displays for each selection.)
3. In the Button Caption window, modify the button properties as shown in the figure below.
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Enter button name
Enter button function Enter configuration properties command
Use the following command strings to configure the buttons: Required data and data format can be viewed from the DOS command line by typing SILENCE and LOCKOUT.
• LOCKOUT uses the syntax: LOCKOUT: [(nodename)] LOCK lockout 1 %res %id %refid [(nodename)] UNLOCK: lockout 0 %res %id %refid [(nodename)]
• SILENCE uses the syntax: SILENCE %res [(node)].
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Reactive Capability Display Mark IV, V, V LM, VI
The Reactive Capability Display is a real-time graphic that shows the turbine generator's current MW and MVAR operating point (see Figure 5-7). You can use this display to check how close the generator is operating to its thermal limits.
Three static curves represent the generator’s thermal limits at three discrete operating points. The curves are plotted at constant generator hydrogen pressure or constant ambient temperature, depending on the application.
Red dot represents the current turbine operating point. It moves as the point changes.
Figure 5-7. Example of Generator Capability Curves Screen
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Chapter 6 CIMPLICITY Project Configuration
Introduction The CIMPLICITY HMI product must be installed before these applications can be used.
This chapter provides information about configuring CIMPLICITY projects for use with the turbine control HMI product. To understand and implement the information in this chapter, you should have a working knowledge of CIMPLICITY projects. Document GFK-1180 provides this information. CIMPLICITY HMI should be configured with the following project properties: Project Name – Appropriate name (for example, SVR1) Sub Directory – Must be Cimproj Path – F:\Cimproj General options – Basic control, external alarm manager Protocols – MarkV+ Communication (this is TCIMB) Others determined by the type of controller The project properties can be examined using the CIMPLICITY Workbench (see Figure 6-2). This chapter is organized as follows: Section
Page
Using Workbench.....................................................................................................6-2 Opening a Project .....................................................................................................6-3 Signal Manager.........................................................................................................6-4 Setup..................................................................................................................6-4 Signals ...............................................................................................................6-5 Alarms ...............................................................................................................6-6 Importing Signals ..............................................................................................6-8 External Alarm Manager ........................................................................................6-10 SDB Exchange .......................................................................................................6-10 SDB Utilities ..........................................................................................................6-10 ® Modbus Data Interface .........................................................................................6-11 OLE for Process Controls (OPC) ...........................................................................6-12
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Using Workbench Document GFK-1180 provides detail about using Workbench.
The CIMPLICITY HMI Workbench is an application used to view, configure, organize, and manage projects. It is similar to the Microsoft Windows Explorer in its display of the file structure and menu options across the top of the window. Refer to Alarm Filtering in HMI Servers (Chapter 5) for examples of the Workbench window. Ø To open Workbench 1. Click Start on the Windows task bar. 2. Select Programs, then CIMPLICITY, HMI, and Workbench. -Orw Select the .gef file in the f:\Cimproj directory. Figure 6-1 shows the File menu for starting a New Project. Figure 6-2 shows the Project menu selection for examining project Properties.
Figure 6-1. Workbench Menu Showing Selections for Starting a New Project
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Figure 6-2. Workbench Menu Showing Selections for Examining Project Properties
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Opening a Project Using the CIMPLICITY HMI, there are three ways to open a project, as described below. Ø To open a CIMPLICITY project through the Windows Start menu 1. Click Start on the Windows task bar. 2. Select Programs, then CIMPLICITY, HMI, and Workbench. A blank CIMPLICITY Workbench now opens. 3. From the Workbench window, select Open from the File menu. 4. Select the project you want to open. Ø To open a CIMPLICITY project from the Windows File Explorer 1. Open File Explorer. 2. Open the f:\cimproj directory. 3. Double-click the .gef file. Ø To open a CIMPLICITY project from the Start Menu 1. Click Start on the Windows task bar. 2. Select Documents. 3. Click the .gef file.
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Chapter 6 CIMPLICITY Project Configuration • 6-3
Signal Manager The program can be found on the HMI in G:\EXEC\CSDBUtil.EXE.
In Mark IV, V, and V LM, the Signal Manager is a program for configuring CIMPLICITY points and alarms for the turbine controllers. The TCI service must be running before using this utility, since it accesses data from each unit’s Data Dictionary, which is built and maintained by the TCI service. For Mark IV, Mark V, and Mark V LM controllers, the Signal Manager is used to configure both points and alarms. Point information is retrieved from the Control Signal Database (CSDB) and used to populate the CIMPLICITY Point Manager Database. Alarm information is configured for run-time retrieval of the alarm text from the TCI. For a Mark VI, signal management is through an HMI device.
Setup Ø To enable alarms for CIMPLICITY 1. Create a new project. 2. Select options in the New Project dialog box , shown below.
Click when completed
Select directory Select Select applicable
After creating a new CIMPLICITY project, you must configure a CIMPLICITY Port for the communications protocol. This enables signals to be imported into the project. Refer to the CIMPLICITY Base System User’s Manual GFK-1180 for more information on creating projects and configuring ports.
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When the Signal Manager imports controller signals into CIMPLICITY, it configures any needed CIMPLICITY devices and resources, if they are not already present. For example, when importing signals for unit T1, the utility configures a CIMPLICITY device and a CIMPLICITY resource, both called T1. MARKV_RP is TCIMB function that collects data from a turbine using TCI and forwards the information to the CIMPLICITY Point Manager.
For each device that Signal Manager configures, it a also configures three virtual points needed by the MARKV_RP program. For example, for a device called T1, the utility produces the following virtual points: • T1_TIME, which contains the unit’s current time • T1_DATE, which contains the unit’s current date • T1_VALID, a Boolean value that indicates if the HMI is currently communicating with the unit
Signals CSDB is Control System Database.
Signal Manager displays data from the Data Dictionary, which describes the unit’s CSDB. Each row of the display shows information about a signal, divided into columns that display the following signal attributes: Signal attribute
Description
Name
Signal’s name
Access
Read /write
Cim Type
CIMPLICITY point type that corresponds to this signal
Description
Description of the signal
Eng. Units
Engineering Units
Flags
Signal attributes (for example, alarm, command, permanent)
High Limit
High limit for the signal’s value
Low Limit
Low limit for the signals value
Offset
Offset into the CSDB where this signal is located
Precision
Numeric precision for display of the signal’s value
Scale Code
Scale code for engineering unit conversion
Synonym
Optionally specified synonym for this signal
Type
Datatype for this signal
Value
Signal’s current value
You can configure the items listed. The display is a standard Windows List Control, which supports the expected user interface commands for selecting items, sorting rows, and sizing columns.
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Chapter 6 CIMPLICITY Project Configuration • 6-5
Alarms The Signal Manager can also be used to configure alarms for EX2000 and EX2100 exciters.
CIMPLICITY alarms are only placeholders that are given the appropriate parameters at run-time when they occur. The Signal Manager can be used to configure the alarms for Mark V, Mark V LM, and Mark VI turbine controllers, as well and other events. It uses the following configuration IDs: Alarm use
Alarm ID for configuration
Process alarms for turbine
P*
Diagnostic alarms for turbine
D* (Mark V only)
Hold list points**
HOLD (Steam only)
Sequence of events**
SOE
Digital events**
EVENT
* n is the drop number reported by the controller. ** These CIMPLICITY alarms are generated multiple times at run-time with different parameters for each instance.
When the Signal Manager configures alarms, it also configures alarm classes, as follows: • If a needed alarm class is not configured, it is added to the CIMPLICITY configuration • If the alarm class is already configured, the existing alarm class definition is used • The following alarm classes apply: Class
Definition
PRC
Process alarms
DIAG
Diagnostic alarms
HOLD
Hold list entries
SOE
Sequence of events
EVENT
Digital events
EX2K
Exciter alarms (see below)
Configuring Exciter Alarms Exciter alarms are configured from information contained in the file F:\EX2000.DAT. This information is specific to the EX2000 exciter and represents interpretations of the fault codes generated by the EX2000 exciter. The exciter alarms are not placeholders and are configured with all parameters fully defined. Ø To configure alarms for controllers w Select Alarms from the Action menu. Signal Manager then configures process and diagnostic alarms, as well as alarms for Hold List, SOEs, and digital events.
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HMI for SPEEDTRONIC Turbine Control GEH-6126A Vol. I
Ø To configure alarms for EX2000 exciters 1. Select EX2000 Alarms from the Action menu. Signal Manager then configures exciter alarms as defined in F:\EX2000.DAT and displays the Exciter Fault Code dialog box. 2. Make the signal selections as shown in the figure below. Signal Manager then runs command line utilities and displays their output in a scrolling text box. In CIMPLICITY, these utilities configure events and actions that generate alarms when the value of the fault code CIMPLICITY point changes value.
Type in signal name (Point ID) Select exciter core that generates the fault
Click when selections for the signal are completed in this box. The box remains open Click when no more signal selections are to be made. This closes the dialog box.
3. After these events and actions are configured, specify additional exciter fault code points using the Exciter Fault Code box as in step 2. 4. When completed, select Done.
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Chapter 6 CIMPLICITY Project Configuration • 6-7
Importing Signals When the Signal Manager is started, an empty list displays. Ø To add signals to the Signal Manager list 1. Select New from the File menu. 2. A dialog box displays, allowing you to specify which signals to get from the Data Dictionary.
Type in name with wildcards to filter signals retrieved from the Data Dictionary. Supported are: •
Asterisk (*), which matches zero or more occurrences of any character
•
Question mark (?), which matches zero or one occurrence of any character
Select box(es) to filter the signals by type. (A check mark in a box allow signals of the corresponding type to pass through the filter). Select Unit from list of available units. Click when completed, adding signals to Signal Manager.
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HMI for SPEEDTRONIC Turbine Control GEH-6126A Vol. I
Ø To individually import signals individually into CIMPLICITY w
In Signal Manager, select the desired signals from the displayed list.
Ø To import all signals at once into CIMPLICITY 1. In Signal Manager, select Select All from the Edit menu. 2. Select Import from the Action menu. This displays a dialog box that allows you to select the .gef file for the desired CIMPLICITY project (see Figure 6-6).
Figure 6-6. Example of CIMPLICITY Project Selection Dialog Box
You may sometimes want to populate the CIMPLICITY point database with points from a set of screens. Ø To populate the Signal Manager’s displayed list of signals with the signals referenced in a set of screens 1. Select Match from the Action menu. Signal Manager then scans all the screens and displays any points not found in the Data Dictionary. 2. Select the signals as desired and import them into the CIMPLICITY point database using the procedures described previously.
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Chapter 6 CIMPLICITY Project Configuration • 6-9
External Alarm Manager The External Alarm Manager is a software component of the CIMPLICITY Bridge (CIMB). It functions as an interface that collects turbine controller alarms and forwards them to the CIMPLICITY Alarm Manager, where they are displayed. For Mark IV and VI controllers, only process alarms can be displayed. For Mark V controllers, both process and diagnostic alarms can be displayed. Mark VI controllers use the toolbox to display diagnostic alarms (refer to GEH-6403).
SDB Exchange The System Database (SDB) Exchange is available for Mark VI controllers. It provides a way to populate the CIMPLICITY point and alarm databases with the data extracted from the Mark VI SDB. Refer to GEI-100279 for more information about the SDB Exchange.
SDB Utilities The SDB Utilities must run on the PC that is the CIMPLICITY Server.
The SDB Utilities are available for Mark VI controllers. They provide a way to populate the CIMPLICITY point and alarm databases with the data extracted from the Mark VI SDB. The SDB Utilities support four sources for importing signal and alarm data into the CIMPLICITY HMI Project: • Signals from the SDB, which contains data used by one or more system devices. • Signals from a comma separated variable file (*.csv), which is a common text format for spreadsheet and database output. • Signals from a shared name file (*.snf), associated with the Series 90™-70 programmable logic controller (PLC). • Alarms imported from the SDB into the CIMPLICITY HMI Project alarm definitions. Refer to GEI-100500 for more information about the SDB Utilities. .
6-10 • Chapter 6 CIMPLICITY Project Configuration
HMI for SPEEDTRONIC Turbine Control GEH-6126A Vol. I
Modbus® Data Interface This utility is used with Mark IV and VI controllers. Modbus is an industry standard communication link used by the HMI to provide the current value of variables from the HMI to any system that requests it via the Modbus link.
The HMI acts as a Modbus slave (see Figure 6-7). This means that it waits for requests from another computer (a Modbus master) and answers them by returning the current value of the variables requested. When the HMI receives turbine control commands, it forwards them to the turbine controller. Both RS-232C and Ethernet links are supported. CimMod is a program supplied by Industrial Systems (Salem, VA) as part of the CIMPLICITY project. Its function is to communicate between the CIMPLICITY point database and the TCI Modbus slave. This allows transfer of data to the Modbus master. HMI Server Mark VI
Mark IV
TCI
CIMPLICITY
CIMMOD
TCI Modbus Slave
DCS
Mark V & Mark V LM
Figure 6-7. Data Flow from Controllers in Modbus Slave Mode
CimMod_L is a command line utility (CIMMOD_L.EXE) that reads the necessary configuration files in the TCI to create a Modbus list for CIMPLICITY (CIMMOD.LST). The list defines the format and scaling of each mapped coil and register. It also indicates which signals are controller commands. Refer to document GEI-100517 for more information about using CimMod and CimMod_L.
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Chapter 6 CIMPLICITY Project Configuration • 6-11
OLE for Process Controls (OPC) OPC was developed by the OPC Foundation and endorsed by Microsoft.
OPC is a standard communications mechanism for moving data between HMIs and I/O Servers. It is based on Microsoft OLE technology. CIMPLICITY OPC Client software provides CIMPLICITY users with access to process data from OPC servers. The OPC Client supports all CIMPLICITY data types and the following CIMPLICITY features: • Collection of unsolicited data from an OPC Server • Poll after setpoint • Triggered reads • Analog deadband through CIMPLICITY filtering Refer to GE Fanuc document GFK-1181 for OPC Client information. OPC Servers provide real time data by firing events whenever the value of an item added by the OPC client changes. The CIMPLICITY HMI OPC Server provides a standards-based way to access run-time information from a CIMPLICITY HMI project. Refer to GE Fanuc document GFK-1675 for OPC Server information.
6-12 • Chapter 6 CIMPLICITY Project Configuration
HMI for SPEEDTRONIC Turbine Control GEH-6126A Vol. I
Appendix A HMI Function Reference
Section
Page
HMI Functions for GE Turbine Controllers ............................................................A-1 CIMPLICITY HMI Supported Functions ...............................................................A-4
HMI Functions for GE Turbine Controllers GE’s Turbine Control HMI functions are provided by the TCI, TCIMB, and GE Turbine Control Systems Solutions CD. The following table lists these functions and identifies their applicability in the SPEEDTRONIC turbine controllers. Functions are provided through CIMPLICITY, unless otherwise noted. Mark IV
Mark V
Mark V LM
Mark VI
ü
ü
ü
ü
Toolbox graphics for Mark VI
Logic Forcing
ü
ü
ü
Toolbox function for Mark VI
Dynamic Rung Display
ü
ü
ü
Toolbox function for Mark VI
Pre-vote Data Display
ü
ü
ü
TSM for Mark VI
Diagnostic Counters Display
ü
ü
ü
TSM for Mark VI
Control Constants Display
ü
ü
ü
Toolbox function for Mark VI
Control Constants Adjust Display
ü
ü
ü
Toolbox function for Mark VI
Autocalibrate Display
ü
ü
Toolbox function for Mark VI
Trip History
ü
ü
ü
Capture blocks for Mark VI
HMI Function
Application Notes
Data and Control Displays Demand Display
CIMPLICITY Add-ons CIMPLICITY Bridge
ü
ü
ü
ü
Signal Manager
ü
ü
ü
ü
External Alarm Manager
ü
ü
ü
ü
Reactive Capability Display
ü
ü
ü
ü
Manual Synchronizing Display
ü
ü
ü
Emissions Analysis
ü
ü
Triggered Plot
ü
ü
GEH-6126A Volume I Operator’s Guide
SDB Exchange for Mark VI
Implemented with CIMPLICITY for Mark VI
Appendix A HMI Function Reference • A-1
HMI Function
Mark IV
Mark V
Mark V LM
ü
ü
Mark VI
Application Notes
Unit Communications Stagelink CSF
ü
Not available in some Mark IVs
MAMSP
ü
Not available in some Mark IVs
TCI Modbus™ Master
ü
ü
Not available in some Mark IVs
ü
EGD Unit Communications (continued) Process Alarms
ü
Diagnostic Alarms
ü
ü
ü
ü
ü
ü
Events
ü
ü
ü
ü
SOEs
ü
ü
ü
ü
ü
Hold List
ü
Toolbox function for Mark VI
Controllers with Steam ATS only
ü
SDB Utilities / Exchange Unit Configuration Tools Sequence Editor
ü
ü
ü
Toolbox function for Mark VI
Sequence Compiler
ü
ü
ü
Toolbox function for Mark VI
Sequence Documentor
ü
ü
ü
Toolbox function for Mark VI
CSP Printer
ü
ü
ü
Toolbox function for Mark VI
Table Compiler
ü
ü
Application Code Downloads
ü
ü
ü
Toolbox function for Mark VI
ü
ü
Toolbox for Mark VI
TSM for Mark VI
Firmware Downloader Mark V Make
ü
ü
Card Identification
ü
ü
ü
ü
ü
ü
Alarm List
ü
FMV ID
ü
LDB Configuration Tools
ü
I/O Configuration Tool
ü
ü
ü
Toolbox function for Mark VI
Time Synchronizing Timesync Function
ü
ü
ü
ü
NTP for Mark VI
High Resolution (IRIG)
ü
ü
ü
ü
Option
GPS
ü
ü
ü
ü
Option
NTP
ü
ü
ü
ü
Option
A-2 • Appendix A HMI Function Reference
HMI for SPEEDTRONIC Turbine Control GEH-6126A, Volume I
Mark IV
Mark V
Mark V LM
Mark VI
Alarm Printing
ü
ü
ü
ü
Alarm History
ü
ü
ü
ü
ü
ü
ü
Capture Blocks + Data Historian for Mark VI
ü
ü
ü
Toolbox function for Mark VI
High-speed Data Collection
ü
ü
ü
Toolbox Trend Recorder for Mark VI
Control Constants Compare
ü
ü
ü
ü
ü
ü
ü
ü
ü
HMI Function
Application Notes
Other Functions
Trip History Automatic Collection Normal Data Collection
ü
Optional Functions TCI Modbus Slave
ü
TCI Modbus Master GSM
ü
ü
ü
ü
Power Block Control
ü
ü
ü
ü
ü
ü
ü
ü
ü
ü
ü
ü
ü
ü
ü
Performance Monitor
For external device interface
Simple cycle only
Web Diagnostic Functions Demand Display
ü
Logic Forcing Display Alarm Display
ü
Control Constants Display HMI Log Files
ü
ü
ü
ARCWHO Utility
ü
ü
ü
ü
ü
ü
ü ü
Diagnostic Programs Product Code File Verification
GEH-6126A Volume I Operator’s Guide
ü
Appendix A HMI Function Reference • A-3
CIMPLICITY HMI Supported Functions The turbine control HMI supports many functions of the CIMPLICITY HMI. The following table lists and identifies these functions. Do not load unsupported CIMPLICITY functions on the HMI for SPEEDTRONIC Turbine controllers. Although the CIMPLICITY HMI function listed below will run on the HMI for SPEEDTRONIC Turbine controllers, they are not necessarily supported by GE Power Systems for use on the HMI. Please check with a GE Power Systems representative for availability. Options not listed as supported in the following table have not been qualified.
Earliest Supported Version
CIMPLICITY Function
Supported
Application Notes Calendar-based Control
Action Calendar Alarm Blocking Alarm Horn 3.2 SP7
Alarm Viewer
ü
Interactive ActiveX alarm viewing object
3.2 SP7
Basic Control Engine
ü
Visual Basic for applications scripting language Data logging via ODBC
Data Logger DDE Server (CWSERV)
Dynamically switch between English and metric units
Dynamic Measurement Systems Genius Communication from HMI
3.2 SP7
Historical Data Analyzer
Comprehensive data summarization
Historical Trends
Interactive ActiveX object for viewing trend
HMI for CNC
Integration with GE Fanuc CNC controllers
HMI Modbus Master
ü Display alarms and messages to marquee devices
Marquee 3.2 SP7
Modbus Plus Communications
ü
Modbus TCP/IP Communications 4.01 SP2
OPC Client
Consult Salem, VA factory, Turbine Control Application Engineering (540) 387-7388
4.01 SP2
OPC Server
Consult Salem, VA factory, Turbine Control Application Engineering (540) 387-7388
4.01 SP8
OpenProcess
3.2 SP7
Pager PocketViewer
A-4 • Appendix A HMI Function Reference
Pending
ü
Send alarm information to alpha-numeric pagers WinCE CimView
HMI for SPEEDTRONIC Turbine Control GEH-6126A, Volume I
Earliest Supported Version 3.2 SP7 4.01 SP2 3.2 SP7
3.2 SP7
CIMPLICITY Function
Supported
PointBridge
ü
Allows CIMPLICITY server to act as device to another server
Quick Trends
ü
Pop-up trends for any points on a screen
Real-time Trends
ü
Interactive ActiveX object for viewing trend
Recipes
Device-independent recipe management
Report Manager
Report generation and management from process
Series 90™ PLC Fault Tables
ü
3.2 SP7
SmartObjects™
ü
Reusable drag and drop graphic and scripted objects
SPC
New features for SPC
System Sentry
Constantly watches HMI and system parameters
Tracker Option
Track items through a production facility
Web Gateway
ü
XY Plots
GEH-6126A Volume I Operator’s Guide
Send CIMPLICITY HMI data to web pages Send screens over web to standard web browsers
Web Viewer 3.2 SP7
View PLC faults Complete mission critical redundancy support
Server Redundancy 4.01 SP2
Application Notes
ü
ActiveX object for plotting multiple x-y data
Appendix A HMI Function Reference • A-5
Notes
A-6 • Appendix A HMI Function Reference
HMI for SPEEDTRONIC Turbine Control GEH-6126A, Volume I
Appendix B Alarm Overview
Introduction The turbine controllers generate three types of alarms, which are viewed on the HMI or toolbox: Process, Hold List, and Diagnostic (see Figure B-1).
HMI
Alarm Display
HMI
Toolbox
Diagnostic Display
UDH
Process & Hold List Controller Alarms
Controller
Controller
Diagnostic Alarms
I/O
I/O
Diagnostic Alarm Bits
I/O
Figure B-1. Three Types of Alarms Generated by the Mark VI Controller
This appendix provides a general overview of turbine controller alarms viewed and addressed using the HMI. It is intended to assist the operator in understanding how to use the HMI for monitoring, using the features described in this document. Note The information in this appendix applies specifically to the Mark VI controller. However, it should also apply to Mark IV, Mark V, and Mark V LM controllers, except in discussion of Control System Toolbox features. This information is provided as follows: Section
Page
Hold List Alarms ..................................................................................................... B-2 Process Alarms ........................................................................................................ B-2 Process (and Hold) Alarm Data Flow............................................................... B-2 Diagnostic Alarms ................................................................................................... B-3
GEH-6126A, Volume I Operator’s Guide
Appendix B Alarm Overview • B-1
Hold List Alarms (Steam Turbine Only) Refer to the Hold List section in Chapter 4.
Hold List alarms are similar to process alarms with the additional feature that the scanner drives a specified signal True whenever any Hold List signal is in the alarm state (hold present). This signal is used to disable automatic turbine startup logic at various stages in the sequencing. Operators may override a hold list signal so that the sequencing can proceed even if the hold condition has not cleared.
Process Alarms Process Alarms are caused by machinery and process problems, and alert the operator by means of messages on the HMI screen. The alarms are created in the controller using alarm bits generated in the I/O boards or in sequencing. The user configures the desired analog alarm settings in sequencing using the toolbox. Process Alarms are generated by the transition of Boolean signals configured by the toolbox (for Mark VI) with the alarm attribute. The signals may be driven by sequencing or they may be tied to input points to map values directly from I/O boards. Process alarm signals are scanned each frame after the sequencing is run. In TMR systems, process signals are voted and the resulting composite diagnostic is present in each controller. A useful application for process alarms is the annunciation of system limit checking. Limit checking takes place in the I/O boards at the frame rate, and the resulting Boolean status information is transferred to the controller and mapped to Process Alarm signals. Two system limits are available for each process input, including thermocouple, RTD, current, voltage, and pulse rate inputs. System limit 1 can be the high or low alarm setting, and system limit 2 can be a second high or low alarm setting. These limits are configured from the toolbox in engineering units. There are several choices when configuring system limits. Limits can be configured as enabled or disabled, latched or unlatched, and greater than or less than the preset value. System out of limits can be reset with the RESET_SYS signal.
Process (and Hold) Alarm Data Flow The operator or the controller can take action based on process alarms.
Process and Hold alarms are time stamped and stored in a local queue in the controller. Changes representing alarms are time stamped and sent to the alarm queue. Reports containing alarm information are assembled and sent over the UDH to the CIMPLICITY HMIs. Here the alarms are again queued and prepared for operator display by the Alarm Viewer. Operator commands from the HMI, such as alarm Acknowledge, Reset, Lock, and Unlock, are sent back over the UDH to the alarm queue. There they change the status of the appropriate alarms. An alarm entry is removed from the controller queue when its state has returned to normal and it has been acknowledged and reset (refer to Figure B-2). Hold alarms are managed in the same fashion but are stored on a separate queue. Additionally, hold alarms cannot be locked but may be overridden.
B-2 • Appendix B Alarm Overview
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
Mark VI Controller
Input
Signal 1
. . .
. . .
Input
Signal n
UDH
Alarm Report
Alarm Scanner
Alarm Command
Alarm Queue Including Time
Alarm Logic Variable Alarm ID
Mark VI HMI
Alarm Receiver
Alarm Viewer
Alarm Queue Operator Commands - Ack - Reset - Lock - Unlock - Override for Hold Lists
Figure B-2. Generating Process Alarms
Diagnostic Alarms Diagnostic Alarms are caused by equipment problems, and use settings factory programmed in the boards. Diagnostic Alarms identify the failed module to help the service engineer quickly repair the system. For details of the failure, the operator can request a display on the toolbox screen (Mark VI) or review the details in the HMI Alarm Display screen. The controller and I/O boards all generate diagnostic alarms, including the VCMI, which generates diagnostics for the power subsystem. The controller has extensive self-diagnostics, most that are available directly at the toolbox (for Mark VI). Diagnostic alarms can be viewed from the toolbox by selecting the desired board, clicking the right mouse button to display the drop down menu, and selecting display diagnostics. A list of the diagnostic alarms for any I/O board can be displayed, and may be reset from the toolbox.
GEH-6126A, Volume I Operator’s Guide
Appendix B Alarm Overview • B-3
Notes
B-4 • Appendix B Alarm Overview
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
Glossary
ActiveX ActiveX, developed by Microsoft, is a set of rules for how applications should share information. With ActiveX, users can ask or answer questions, use pushbuttons, and interact in other ways with the web page or compatible program. It is not a programming language, but rather a model for writing programs so that other programs and the operating system can call them. ActiveX technology is used with Microsoft Internet Explorer® to make interactive web pages that look and behave like computer programs, rather than static pages.
ActiveX control A control (object) using ActiveX technologies to enable animation. An ActiveX control can be automatically downloaded and executed by a web browser. Programmers can develop ActiveX controls in a variety of languages, including C, C++, Visual Basic, and Java. ActiveX controls have full access to the Windows operating system.
alarm A message notifying an operator or administrator of equipment, network, or process problems.
Alarm Viewer A standalone window within CIMPLICITY (an OCX control) for monitoring and responding to alarms.
AMV Alarm Viewer.
application A complete, self-contained program that performs a specific function directly for the user. Application programs are different than system programs, which control the computer and run application programs and utilities.
ARCNET Attached Resource Computer Network, a LAN communications protocol developed by Datapoint Corporation. ARCNET defines the physical (coax and chip) and datalink (token ring and board interface) layer of a 2.5 MHz communication network.
GEH-6126A Volume I Operator’s Guide
Glossary • 1
Balance of Plant (BOP) Plant equipment other than the turbine that needs to be controlled.
board Printed wiring board, or circuit board, used for electronic circuits.
Boolean Digital statement that expresses a condition that is either True or False, also called a discrete, or logical signal.
breaker (circuit breaker) A switching device, capable of making, carrying, and breaking currents under normal circuit conditions and also making, carrying for a specified time, and breaking currents under specified abnormal conditions, such as those of short circuit.
The turbine controller’s Communicator core (processor).
CimEdit An object-oriented graphics editor tool of CIMPLICITY HMI that functions with its runtime viewer CimView. It can create graphical screens with animation, scripting, colors, and a variety of graphical elements that represent power plant operation.
CIMPLICITY HMI Pc-based operator interface software from GE Fanuc Automation, configurable to work with a wide variety of control and data acquisition equipment.
cimproj The required subdirectory name for a CIMPLICITY HMI project (F:\Cimproj). The project configuration Workbench (.gef) is located in this subdirectory.
CimView An interactive graphical user interface of CIMPLICITY HMI used to monitor and control power plant equipment, displaying data as text or a variety of graphic objects. Its screens were created with CimEdit. They include a variety of interactive control functions for setting point values, displaying other graphic screens, and initiating custom software routines and other Windows applications.
client-server Software architecture where one software product makes requests on another software product. For example, an arrangement of PCs with software making one a data acquisition device and the other a data using device.
command line The line on a computer display where the user types commands to be carried out by a program. This is a feature of a text-based interface such as MS-DOS, as opposed to a graphical user interface (GUI) such as Windows.
configure Select specific options, either by editing disk files, or by setting the location of hardware jumpers, or by loading software parameters into memory. 2 • Glossary
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
control system Equipment that automatically adjusts the output voltage, frequency, MW, or reactive power, as the case may be, of an asset in response to certain aspects of common quality such as voltage, frequency, MW, or reactive power. Such equipment includes, but is not limited to, speed governors and exciters.
Control System Solutions Product software provided on a CD for a GE control system. For example, this may include the Control System Toolbox or SDB Exchange programs.
Control System Toolbox See toolbox.
CRC Cyclic Redundancy Check which is used to detect errors in data such as transmissions or files on a disk.
cross plot Display of two variables, plotted one against the other over time, in an X-Y type plot to detect signal correlations and to analyze performance.
CSDB Control Signal Database, used in the turbine controller to store real time process data used in the control calculations.
CSF Control System Freeway, a token passing communication network, typically using TWINAX cabling, running at 2.3 MHz.
The turbine controller’s backup Communicator core (processor). (Also see .)
data dictionary A system file that contains the information needed to operate a database in a database management system. This file includes basic operating information about the records and fields of a certain database, the limits on acceptable data values, and access-authorization information. For the HMI, the data dictionary files contain information about unit-specific control signal database pointnames, alarm text messages (for both process and diagnostic alarms), and display information for signal pointnames (type/units, messages, and such). The primary unit Data Dictionary file, UNITDATA.DAT, can be created on an HMI in the unit-specific directory.
DCS Distributed Control System, used for process control applications including control of boilers and other power plant equipment.
deadband Range of values inside of which the incoming signal can be altered without changing the output response. The Historian uses a sophisticated deadband algorithm to decide whether to save or discard incoming data, as part of its data compression function.
GEH-6126A Volume I Operator’s Guide
Glossary • 3
Demand Display An HMI function that allows you to monitor several turbine data points at a time and issue simple commands. It supports multiple units.
device A configurable component of a process control system.
Devcom Application program that serves as a communications bridge between the CIMPLICITY HMI Point Manager and a device being monitored.
dynamic An attribute emphasizing motion, change, and process as opposed to static.
EGD Ethernet Global Data, a network protocol used by some controllers. Devices share data through periodic EGD exchanges (pages of data).
Ethernet LAN with a 10 or 100 megabaud data rate, used to link one or more computers and/or controllers together. It features a collision avoidance/collision detection system. It uses TCP/IP and I/O services layers that conform to the IEEE 802.3 standard, developed by Xerox, Digital Equipment Corporation (DEC), and Intel.
event Discrete signal generated by a change in a status of a logic signal in a controller.
EX2000 GE generator exciter control. It regulates the generator field current to control the generator output voltage.
fault code A message from the controller to the HMI indicating a controller warning or failure.
firmware Set of executable software, stored in memory chips that hold their content without electrical power, such as EPROM or Flash memory.
filter A program that separates data or signals in accordance with specified criteria.
forcing Setting a signal to a particular value, regardless of the value the blockware or I/O is writing to that signal.
frame rate Basic scheduling rate of the controller. It encompasses one complete input-computeoutput cycle for the controller.
4 • Glossary
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
GSM GE Industrial Systems Standard Messages. Application-level messages processed in gateway to the DCS. The gateway serves as a protocol translator and can communicate directly with several process controllers. No data is emitted from the gateway unless previously requested by the DCS equipment.
Global Time Source (GTS) Worldwide system supplying UTC (Coordinated Universal Time) using a network of satellites.
graphical user interface (GUI) An operating system interface between the user and the computer, based on graphics. GUIs typically use a mouse or other tracking device and icons. First developed by Xerox as an easier to learn interface than text-based ones, it was adopted by Apple for the Macintosh, Microsoft for Windows, and even forUNIX systems as XWindows.
header Textual information, such as a title, date, name, or other applicable identifying information, positioned at the top of a screen, column, or page, and usually repeated at every occurrence.
Historian A client/server-based data archival system for data collection, storage, and display of power island and auxiliary process data.. It combines high-resolution digital event data from the turbine controller with process analog data to create a sophisticated tool for investigating cause-effect relationships.
HMI Human-Machine Interface. The GE HMI is a Windows NT-based operator interface to the turbine controllers and auxiliary power plant equipment. The HMI uses CIMPLICITY as the operator interface, and supports the Historian Client Toolset for viewing Historian data.
HRSG Heat Recovery Steam Generator. This uses exhaust heat from a gas turbine to generate steam.
icon A small picture intended to represent something (a file, directory, or action) in a graphical user interface. When an icon is clicked on, some action is performed, such as opening a directory or aborting a file transfer
ICS Integrated Control System. The GE ICS combines various power plant controls into a single distributed control system.
initialize Set values (addresses, counters, registers, and such) to a beginning value prior to the rest of processing.
GEH-6126A Volume I Operator’s Guide
Glossary • 5
IONet The Mark VI I/O Ethernet communication network.
LAN Local area network (communications). A typical LAN consists of peripheral devices and controllers contained in the same building, and often on the same floor.
logical Statement of a true/false sense, such as a Boolean.
Mark IV SPEEDTRONIC gas turbine controller, introduced in 1983. The first GE triple modular redundant (TMR) control for fault-tolerant operation.
Mark V All-digital SPEEDTRONIC gas and steam turbine controller, introduced in 1991, available in Simplex and TMR control versions. At first equipped with a DOS-based pc operator interface, later upgraded to use the NT-based CIMPLICITY HMI.
Mark V LM SPEEDTRONIC gas turbine controller, introduced in 1995, designed specifically to support the aeroderivative Dry Low Emissions (DLE) technology developed by GE Aircraft Engines. Equipped to use the NT-based CIMPLICITY HMI.
Mark VI VME-based SPEEDTRONIC gas and steam turbine controller, available in Simplex and TMR control versions. Equipped to use the NT-based CIMPLICITY HMI and Control System Toolbox.
menu (Software.) A list from which the user may select an operation to be performed.
Modbus Serial communication protocol, initially developed by Gould Modicon for use between PLCs and other computers.
network A data communication system that links two or more computers and peripheral devices.
object (Software.) Generally, any item that can be individually selected and manipulated. This can include shapes and pictures that appear on a display screen, as well as less tangible software entities. In object-oriented programming, for example, an object is a self-contained entity that consists of both data and procedures to manipulate the data.
OCX OLE custom control. An independent program module that can be accessed by other programs in a Windows environment. ActiveX (Microsoft’s next generation of controls) is backward compatible OCX. 6 • Glossary
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
OLE (Pronounced as separate letters.) Object linking and embedding. A compound document standard developed by Microsoft Corporation. It enables you to create objects with one application and then link or embed them in a second application. Embedded objects retain their original format and links to the application that created them. Support for OLE is built into the Windows.
OPC OLE for Process Controls. The OPC Specification is a non-proprietary technical specification that defines a set of standard interfaces based upon Microsoft’s OLE/COM technology. The application of the OPC standard interface makes possible interoperability between automation/control applications, field systems/devices, and business/office applications.
panel The side or front of a piece of equipment on which terminations and termination assemblies are mounted.
pc Abbreviation for personal computer.
PDH See Plant Data Highway.
permissives Conditions that allow advancement from one state to another.
Plant Data Highway (PDH) Ethernet communication network linking the Historian, HMI Servers, HMI Viewers, workstation, and printers.
PLC Programmable logic controller. These are designed for discrete (logic) control of machinery, and they also compute math (analog) functions and perform regulatory control.
plot To draw an image by connecting a series of precisely placed points on a screen or paper, using a series of lines.
point Basic unit for variable information in the controller, also referred to as signal.
product code (runtime) Software stored in the controller’s Flash memory that converts application code (pcode) to executable code.
GEH-6126A Volume I Operator’s Guide
Glossary • 7
reactive capability The reactive power injection or absorption capability of generating sets and other reactive power resources such as Static Var Compensators, capacitors, and synchronous condensers. This includes reactive power capability of a generating set during the normal course of the generating set operations.
reboot Restart the controller or pc after a controlled shutdown.
relay ladder diagram (RLD) A ladder diagram represents a relay circuit. Power is considered to flow from the left rail through contacts to the coil connected at the right.
resources Also known as groups. Resources are systems (devices, machines, or work stations where work is performed) or areas where several tasks are carried out. Resource configuration plays an important role in the CIMPLICITY system by routing alarms to specific users and filtering the data users receive.
runtime See product code.
Sequence of Events (SOE) A high-speed record of contact closures taken during a plant upset to allow detailed analysis of the event. Most turbine controllers support a data resolution of 1 millisecond.
server A pc that gathers data over Ethernet from plant devices, and makes the data available to pc-based operator interfaces known as Viewers.
setpoint Value of a controlled variable, departure from which causes a controller to operate to reduce the error and restore the intended steady state.
signal Basic unit for variable information in the controller, also referred to as point.
Simplex Operation that requires only one set of control and I/O, and generally uses only one channel.
SOE See Sequence of Events.
SRTP Service Request Transfer Protocol. An Ethernet communications protocol for communications between the turbine controller and the HMI.
8 • Glossary
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
Stagelink ARCNET-based communication link used by many controllers.
synchroscope Instrument for detecting whether two moving parts are synchronized
tag Identifying name given to a process measurement point.
TCEA DS200TCEA Emergency Overspeed Board (TCEA), located in the controller’s Protective Core , is used for the high-speed protection circuitry. It is often referred to as the Protective Processor. The three TCEA boards used in the core are referred to as the , , and processors. These boards scale and condition input for high and low shaft speed, flame detection, and automatic synchronization. They then output the signals via the TCEA (location 1) board over the IONET to the core’s DS200STCA board. The TCEAs send emergency trip signals to the Turbine Trip Board (DS200TCTG). Each TCEA has its own power supply and power supply diagnostics.
TCI Turbine Control Interface. The GE-supplied software package on the HMI that interfaces to the turbine control.
TCP/IP Communications protocols developed to inter-network dissimilar systems. It is a de facto UNIX standard, but is supported on almost all systems. TCP controls data transfer and IP provides the routing for functions, such as file transfer and e-mail.
timetag Information added to data to indicate the time at which it was collected. Also called a time stamp.
TMR Triple Modular Redundancy. This is an architecture that uses three identical sets of control and I/O, and votes the results to obtain highly reliable output signals.
toolbox (Control System Toolbox) Windows-based software package used to configure the Mark VI controllers, exciters, and drives.
trend Time-based screen plot showing the history of process values, available in the Historian, HMI, and the Control System Toolbox.
trigger Transition in a discrete signal from 0 to 1, or from 1 to 0, initiating an action or sequence.
GEH-6126A Volume I Operator’s Guide
Glossary • 9
Unit Data Highway (UDH) Connects the Mark VI controllers, LCI, EX2000, PLCs, and other GE provided equipment to the HMI servers. Sometimes used to refer to Stagelink.
UTC Coordinated Universal Time, an international time-reference standard.
utility A small helper program that performs a specific task, usually related to managing system resources. Utilities differ from applications mostly in terms of size, complexity, and function.
web browser Pc software, such as Microsoft Internet Explorer or Netscape Navigator, allowing screens and data to be viewed over a network from a server.
Windows NT Advanced 32-bit operating system from Microsoft Corporation for 386-based PCs and above.
Workbench A CIMPLICITY HMI program used to view, configure, organize, and manage every component of a CIMPLICITY project through a single window.
10 • Glossary
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
Index A ActiveX objects, 1-9, 5-1, 5-2, 5-6, A-4, A-5 Manual Synchronizing Display, 5-2, 5-6, A-1 trends, 1-6, A-4, A-5 Triggered Plot, 5-2, 5-6, 5-7, A-1 alarm display, 2-3, 2-6, 4-16 Alarm Viewer, 1-6, 2-3, 2-6, 4-16, 5-8, 5-26, A-4, B-2 CimView, 1-5, 1-6, 2-2 Extended Alarm Commands, 2-3, 5-1, 5-26 Lock, 2-3, 4-17, 5-26, 5-27, B-2 Lockout, 5-1, 5-26, 5-27 Silence, 2-3, 5-1, 5-26, 5-27 Unlock, 2-3, 5-26, 5-27, B-2 alarm filters, 5-8 configuring, 5-14 Alarm Viewer, 1-6, 2-3, 2-6, 4-16, 5-8, 5-26, A-4, B-2, AMV, 5-18, 5-26 CimView, 1-5, 1-6, 2-2 Extended Alarm Commands, 2-3, 5-1, 5-26 Lock, 2-3, 4-17, 5-26, 5-27, B-2 Lockout, 5-1, 5-26, 5-27 Silence, 2-3, 5-1, 5-26, 5-27 Unlock, 2-3, 5-26, 5-27, B-2 alarms, 1-3, 1-4, 1-6, 2-3, 2-5, 3-9, 4-15, 4-16, 5-1, 5-8, 5-26, 6-4, 6-5, 6-6, 6-10, A-4, B-2 alarm display, 2-3, 2-6, A-3, B-3 Alarm Logger Control, 2-6, 4-15 Alarm Viewer, 1-6, 2-3, 2-6, 4-16, 5-8, 5-26, A-4, B-2 alarm.cim file, 5-16, 5-20 AMV, 5-18, 5-26 diagnostic, 6-6, 6-10, A-2, B-1, B-3 Extended Alarm Commands, 2-3, 5-1, 5-26 Lock, 2-3, 4-17, 5-26, 5-27, B-2 Lockout, 5-1, 5-26, 5-27 Silence, 2-3, 5-1, 5-26, 5-27 Unlock, 2-3, 5-26, 5-27, B-2 External Alarm Manager, 6-10, A-1 filtered, 1-9, 5-23 filtering, 5-8, 6-2 Hold List, 2-6, 4-16, 4-17, 6-6, A-2, B-1, B-2 process, 3-12, 6-10, A-2, B-1 – B-3 AMV, 5-18, 5-26 animation, 1-5, 3-3, 3-4, 5-17 graphic displays, 1-2, 1-3, 1-4, A-1
GEH-6126A Volume I Operator’s Guide
B Balance of Plant, 1-7, 5-8, 5-25 board (see printed wiring boards) Boolean, 6-5, B-2 BOP (see Balance of Plant) breaker (see circuit breaker)
C CimEdit, 1-5, 1-8, 5-17 animation, 1-5, 3-3, 3-4, 5-17 CIMPLICITY ActiveX objects, 1-9, 5-1, 5-2, 5-6, A-4, A-5 HMI, 1-3, 1-8, 2-3, 5-1, 5-2, 5-6, 5-8, 5-12, 5-14, 5-17, 6-1 – 6-3, 6-10, 6-12, A-1, A-4, A-5, B-2 Cimproj, 5-16, 6-1, 6-2 CimView, 1-5, 1-6, 2-2, A-4 circuit breaker, 5-2, 5-3 client-server, 1-1 command line, 3-6, 3-11, 3-15, 4-13 – 4-15, 5-27, 6-7, 6-11 communications, 1-3, 1-6, 1-8, 6-4, 6-12, A-2, A-4 Ethernet, 1-7, 3-13, 6-1, 6-11 Modbus, 1-7, 6-11, A-2 – A-4 configuration, 1-3, 1-9, 2-4, 4-7, 4-13, 4-14, 4-16, 5-1, 5-3 – 5-6, 5-8, 5-12, 5-14, 6-2, 6-4 – 6-7 alarm filters, 5-14 Demand Display, 4-13 resources, 5-12 users, 5-8 Control Signal Database (CSDB), 4-17, 6-4, 6-5 control system, 1-3, 1-6, 1-9, 4-1 Control System Freeway (CSF), A-2 Control System Solutions, 1-8 Control System Toolbox (toolbox), 1-2, 1-7, 1-8, 2-5, 3-2, 3-9, 3-13, 4-2, 6-10, B-1 – B-3 Trend Recorder, 1-2, 1-8, 3-13, A-3 controllers Mark IV, 1-1, 1-3, 4-2, 4-13, 4-15, 5-28, 6-4, 6-10, 6-11, A-1, A-2, B-1 Mark V, 1-1 – 1-3, 1-7, 1-8, 2-5, 2-6, 3-2, 3-9, 3-12 – 3-15, 4-2, 5-2, 5-6, 6-4, 6-6, 6-10, A-1 – A-3, B-1 – B-3 Mark V LM, 1-1, 1-8, 3-12, 3-14, 3-15, 6-4, 6-6, A-1, B-1 Mark VI, 1-1 – 1-3, 1-7, 1-8, 2-5, 3-2, 3-9, 3-13, 4-2, 4-16, 5-2, 6-4, 6-6, 6-10, A-1 – A-3, B-1 – B-3 controls ActiveX, 1-9, 5-1, 5-2, 5-6, A-4, A-5 CSDB (see Control Signal Database) CSF (see Control System Freeway)
Index • 1
D
G
Data Dictionary, 1-3, 4-3 – 4-6, 4-9, 6-4, 6-5, 6-9 data history, 3-9, 3-11, 3-12, 3-15 database Control Signal Database (CSDB), 4-17, 6-4, 6-5 SDB Exchange, 1-8, 6-10 SDB Utilities, 6-10, A-2 DCS (see Distributed Control System) Demand Display, 2-6, 3-2, 3-3, 3-5, 3-8, 4-2 – 4-11, 4-13, 4-14, A-1, A-3 configuring, 4-13 Find All Function, 3-7 starting, 4-2 timetag, 4-5 diagnostic alarms, 6-6, 6-10, A-2, B-1, B-3 displays CimView, 1-5, 1-6, 2-2 Demand Display, 2-6, 3-2, 3-3, 3-5, 3-8, 4-2 – 4-11, 4-13, 4-14, A-1, A-3 Manual Synchronizing, 5-2, 5-6, A-1 Reactive Capability, 5-28, A-1 Sequencing, 3-7 Distributed Control System (DCS), 1-7 documentation, 1-8, 1-10, 4-2 DOS commands (command line), 3-6, 3-11, 3-15, 4-13 – 4-15, 5-27, 6-7, 6-11 Dynamic Rung Display, 1-4, 3-2 – 3-8 starting, 3-6 timetag, 3-4, 3-5, 3-9
GE Standard Messages (GSM), 1-7, A-3 graphic displays, 1-2 – 1-6, 5-1, 5-28, A-1, A-5 CimEdit, 1-5, 1-8, 5-17 CimView, 1-5, 1-6, 2-2 GSM (see GE Standard Messages)
H Help, 4-11 How to Get, 1-10 Historian, 1-2, 1-7, 1-8, 3-13, A-3 HMI (see Human-Machine Interface) hold alarms data flow, B-1, B-2 Hold List, 2-6, 4-16, 4-17, 6-6, A-2, B-1, B-2 Human-Machine Interface (HMI) features, 1-2 optional features, 1-7 other tools, 2-5 program files, 4-3 setup, 1-8, 5-19 – 5-21, 6-4 specifications, 1-7 startup, 2-2
I ICS, 1-7
K E EGD (see Ethernet Global Data), 3-13, A-2 Ethernet, 1-7, 3-13, 6-11 Ethernet Global Data (EGD), 3-13, A-2 EX2000, 6-6, 6-7 fault code, 6-6, 6-7 exciter, 5-8, 6-6, 6-7 Extended Alarm Commands, 2-3, 5-1, 5-26 Lock, 2-3, 4-17, 5-26, 5-27, B-2, 4-17 Lockout, 5-1, 5-26, 5-27 Silence, 2-3, 5-1, 5-26, 5-27 Unlock, 2-3, 5-26, 5-27, B-2 External Alarm Manager, 6-10, A-1
F fault code, 6-6, 6-7 file structure, 3-2, 6-2 filter, 5-8 filtered alarms, 1-9, 5-23 Resource Definition, 5-13 Role Properties, 5-11 User Properties, 5-10
2 • Index
keypad menus, 1-9
M Manual Synchronizing Display, 5-2, 5-6, A-1 Mark IV, 1-1, 1-3, 4-2, 4-13, 4-15, 5-28, 6-4, 6-10, 6-11, A-1, A-2, B-1 Mark V, 1-1 – 1-3, 1-7, 1-8, 2-5, 2-6, 3-2, 3-9, 3-12 – 3-15, 4-2, 4-16, 5-2, 5-6, 6-4, 6-6, 6-10, A-1 – A-3, B-1 – B-3 Mark V LM, 1-1, 1-8, 3-12, 3-14, 3-15, 6-4, 6-6, A-1, B-1 Mark VI, 1-1 – 1-3, 1-7, 1-8, 2-5, 3-2, 3-9, 3-13, 4-2, 4-16, 5-2, 6-4, 6-6, 6-10, A-1 – A-3, B-1 – B-3 Modbus, 1-7, 6-11, A-2, A-3, A-4
N network, 1-4 Ethernet, 1-7, 3-13, 6-1, 6-11 Modbus, 1-7, 6-11, A-2, A-3, A-4
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
O objects ActiveX, 1-9, 5-1, 5-2, 5-6, A-4, A-5 OCX, 2-3, 5-8 OLE, 1-5, 2-3, 5-1, 5-2, 6-12 OPC, 1-8, 6-12, A-4 OCX, 2-3, 5-8 OLE, 1-5, 2-3, 5-1, 5-2, 6-12 OLE for Process Controls (OPC), 1-8, 6-12, A-4 OPC (see OLE for Process Controls)
P panel, 1-6, 5-16 PDH (see Plant Data Highway) permissives, 1-4, 5-4 Plant Data Highway (PDH), 1-3 PLC (see Programmable Logic Controller) points, 1-3, 1-6, 2-6, 3-3, 3-8, 3-9, 3-12, 4-3, 4-5, 4-6, 4-14 – 4-17, 6-4 – 6-7, 6-9, A-5, B-2 printed wiring boards, B-3 process alarms, 3-12, 6-10, A-2, B-1 – B-3 data flow, B-1, B-2 TMR systems, B-2 program files, 4-3 Programmable Logic Controller (PLC), 6-10, A-5 projects, 1-9, 2-4, 5-8, 5-12, 5-14, 5-19, 6-1 – 6-4, 6-9, 6-10, 6-12 configuration Cimproj, 5-16, 6-1, 6-2 Workbench, 2-4, 5-8, 5-12, 5-14, 5-16, 6-1 – 6-3 opening, 2-4, 6-3
R Reactive Capability Display, 5-28, A-1 requisition, 1-10 Resource Definition, 5-13 resources, configuring, 5-12 Role Properties, 5-11 rungs, 2-5, 3-2, 3-3, 3-6 – 3-8, A-1
S SDB Exchange, 1-8, 6-10 SDB Utilities, 6-10, A-2 security, 1-2, 5-8, 5-12 Sequence of Events (SOE), 6-6 Sequencing Display, 3-7 setpoint, 4-7, 6-12, 4-7 Signal Manager, 6-4 – 6-9, A-1 signals, importing, 6-8 SOE (see Sequence of Events) specifications, 1-7 SPEEDTRONIC controllers Mark IV, 1-1, 1-3, 4-2, 4-13, 4-15, 5-28, 6-4, 6-10, 6-11, A-1, A-2, B-1
GEH-6126A Volume I Operator’s Guide
Mark V, 1-1 – 1-3, 1-7, 1-8, 2-5, 2-6, 3-2, 3-9, 3-12 – 3-15, 4-2, 4-16, 5-2, 5-6, 6-4, 6-6, 6-10, A-1 – A-3, B-1 – B-3 Mark V LM, 1-1, 1-8, 3-12, 3-14, 3-15, 6-4, 6-6, A-1, B-1 Mark VI, 1-1 – 1-3, 1-7, 1-8, 2-5, 3-2, 3-9, 3-13, 4-2, 4-16, 5-2, 6-4, 6-6, 6-10, A-1 – A-3, B-1 – B-3 startup, 1-5, 1-6, 2-2
T TCI (see Turbine Control Interface) TCP/IP, 1-7, A-4 timetag, 3-4, 3-5, 3-9, 3-12, 4-5 TMR (see Triple Modular Redundancy) toolbox (see Control System Toolbox) trend, 1-6, A-4, A-5 Trend Recorder, 1-2, 1-8, 3-13, A-3 Trip History, 2-5, 3-9 – 3-15, A-1, A-3 trends ActiveX objects, 1-6, A-4, A-5 Triggered Plot, 5-2, 5-6, 5-7, A-1 valve travel, 5-6 Trip History, 2-5, 3-9 – 3-15, A-1, A-3 Data History Results Window, 3-9, 3-11, 3-12, 3-15 Dialog Box, 3-9, 3-11 Display, 2-5 Log, 2-5, 3-14, 3-15 Mark VI, 3-13 starting, 3-11 timetag, 3-9 Triple Modular Redundancy (TMR), B-2 Turbine Control Interface (TCI), 1-2, 1-3, 2-3, 2-5, 3-14, 4-16, 5-1, 5-2, 5-26, 6-4, 6-5, 6-11, A-1 – A-3
U UDH (see Unit Data Highway) Unit Data Highway (UDH), 1-3, B-2 User Properties, 5-10 users, configuring, 5-8
V valve travel, 5-6
W web, A-5 Diagnostic Functions, A-3 Gateway, 1-7, A-5 Workbench, 2-4, 5-8, 5-12, 5-14, 5-16, 6-1 – 6-3
Index • 3
Notes
4 • Index
HMI for SPEEDTRONIC Turbine Control GEH-6126A Volume I
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GEH-6421H, Volume I
SPEEDTRONIC
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Mark VI Control System Guide, Volume I
SPEEDTRONIC
TM
Mark VI Control System Guide, Volume I
These instructions do not purport to cover all details or variations in equipment, nor to provide for every possible contingency to be met during installation, operation, and maintenance. The information is supplied for informational purposes only, and GE makes no warranty as to the accuracy of the information included herein. Changes, modifications, and/or improvements to equipment and specifications are made periodically and these changes may or may not be reflected herein. It is understood that GE may make changes, modifications, or improvements to the equipment referenced herein or to the document itself at any time. This document is intended for trained personnel familiar with the GE products referenced herein. GE may have patents or pending patent applications covering subject matter in this document. The furnishing of this document does not provide any license whatsoever to any of these patents. All license inquiries should be directed to the address below. If further information is desired, or if particular problems arise that are not covered sufficiently for the purchaser’s purpose, the matter should be referred to: GE Energy Post Sales Service 1501 Roanoke Blvd. Salem, VA 24153-6492 USA Phone: 1 888 GE4 SERV (888 434 7378, United States) + 1 540 378 3280 (International) Fax: + 1 540 387 8606 (All) (“+” indicates the international access code required when calling from outside the USA) This document contains proprietary information of General Electric Company, USA and is furnished to its customer solely to assist that customer in the installation, testing, operation, and/or maintenance of the equipment described. This document shall not be reproduced in whole or in part nor shall its contents be disclosed to any third party without the written approval of GE Energy. GE PROVIDES THE FOLLOWING DOCUMENT AND THE INFORMATION INCLUDED THEREIN AS IS AND WITHOUT WARRANTY OF ANY KIND, EXPRESS OR IMPLIED, INCLUDING BUT NOT LIMITED TO ANY IMPLIED STATUTORY WARRANTY OF MERCHANTABILITY OR FITNESS FOR PARTICULAR PURPOSE. 2004 by General Electric Company, USA. All rights reserved
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Safety Symbol Legend
Indicates a procedure, condition, or statement that, if not strictly observed, could result in personal injury or death.
Indicates a procedure, condition, or statement that, if not strictly observed, could result in damage to or destruction of equipment.
Indicates a procedure, condition, or statement that should be strictly followed in order to optimize these applications.
Note Indicates an essential or important procedure, condition, or statement.
GEH-6421 Mark VI Control System Guide Volume I
Safety Symbol Legend x a
This equipment contains a potential hazard of electric shock or burn. Only personnel who are adequately trained and thoroughly familiar with the equipment and the instructions should install, operate, or maintain this equipment. Isolation of test equipment from the equipment under test presents potential electrical hazards. If the test equipment cannot be grounded to the equipment under test, the test equipment’s case must be shielded to prevent contact by personnel. To minimize hazard of electrical shock or burn, approved grounding practices and procedures must be strictly followed.
To prevent personal injury or equipment damage caused by equipment malfunction, only adequately trained personnel should modify any programmable machine.
b x Safety Symbol Legend
GEH-6421 Mark VI Control System Guide Volume I
Contents Chapter 1 Overview
1-1
Introduction ...............................................................................................................................................1-1 Related Documents ...................................................................................................................................1-2 How to Get Help .......................................................................................................................................1-3 Acronyms and Abbreviations ....................................................................................................................1-3
Chapter 2 System Architecture
2-1
Introduction ...............................................................................................................................................2-1 System Components ..................................................................................................................................2-1 Control Cabinet ..............................................................................................................................2-1 I/O Cabinet.....................................................................................................................................2-1 Unit Data Highway (UDH) ............................................................................................................2-2 Human-Machine Interface (HMI) ..................................................................................................2-3 Computer Operator Interface (COI)...............................................................................................2-3 Link to Distributed Control System (DCS)....................................................................................2-4 Plant Data Highway (PDH)............................................................................................................2-4 Operator Console ...........................................................................................................................2-4 Excitation Control System .............................................................................................................2-5 Generator Protection ......................................................................................................................2-5 Static Starter Control System .........................................................................................................2-5 Control Module ..............................................................................................................................2-6 Interface Module ............................................................................................................................2-8 Controller .......................................................................................................................................2-9 VCMI Communication Board......................................................................................................2-10 IONet............................................................................................................................................2-11 I/O Boards....................................................................................................................................2-12 Terminal Boards...........................................................................................................................2-14 Power Sources..............................................................................................................................2-17 Turbine Protection Module ..........................................................................................................2-18 Operating Systems .......................................................................................................................2-19 Levels of Redundancy .............................................................................................................................2-20 Control and Protection Features ..............................................................................................................2-21 Triple Modular Redundancy ........................................................................................................2-21 TMR Architecture ........................................................................................................................2-22 TMR Operation ............................................................................................................................2-24 Designated Controller ..................................................................................................................2-25 Output Processing ........................................................................................................................2-26 Input Processing...........................................................................................................................2-28 State Exchange.............................................................................................................................2-30 Median Value Analog Voting ......................................................................................................2-31 Two Out of Three Logic Voter ....................................................................................................2-31 Disagreement Detector.................................................................................................................2-32 Peer I/O ........................................................................................................................................2-32 Command Action .........................................................................................................................2-32 Rate of Response..........................................................................................................................2-32 Failure Handling ..........................................................................................................................2-33 Turbine Protection...................................................................................................................................2-34 Reliability and Availability .....................................................................................................................2-36 Online Repair for TMR Systems..................................................................................................2-36
GEH-6421H Mark VI Control System Guide Volume I
Contents x i
Reliability.....................................................................................................................................2-37 Third Party Connectivity .........................................................................................................................2-38
Chapter 3 Networks
3-1
Introduction ...............................................................................................................................................3-1 Network Overview ....................................................................................................................................3-1 Enterprise Layer .............................................................................................................................3-1 Supervisory Layer ..........................................................................................................................3-2 Control Layer .................................................................................................................................3-3 Data Highways ..........................................................................................................................................3-4 Plant Data Highway (PDH)............................................................................................................3-4 Unit Data Highway (UDH) ............................................................................................................3-5 Data Highway Ethernet Switches...................................................................................................3-6 Selecting IP Addresses for UDH and PDH ....................................................................................3-8 IONet.........................................................................................................................................................3-9 IONet - Communications Interface ..............................................................................................3-10 I/O Data Collection ......................................................................................................................3-11 Ethernet Global Data (EGD) ...................................................................................................................3-12 Modbus Communications........................................................................................................................3-14 Ethernet Modbus Slave............................................................................................................................3-15 Serial Modbus Slave................................................................................................................................3-17 Modbus Configuration .................................................................................................................3-18 Hardware Configuration...............................................................................................................3-19 Serial Port Parameters ..................................................................................................................3-21 Ethernet GSM..........................................................................................................................................3-22 PROFIBUS Communications..................................................................................................................3-24 Configuration ...............................................................................................................................3-25 I/O and Diagnostics......................................................................................................................3-26 Fiber-Optic Cables...................................................................................................................................3-27 Components..................................................................................................................................3-27 Component Sources......................................................................................................................3-31 Time Synchronization .............................................................................................................................3-32 Redundant Time Sources .............................................................................................................3-32 Selection of Time Sources............................................................................................................3-33
Chapter 4 Codes, Standards, and Environment
4-1
Introduction ...............................................................................................................................................4-1 Safety Standards ........................................................................................................................................4-1 Electrical....................................................................................................................................................4-2 Printed Circuit Board Assemblies ..................................................................................................4-2 Electromagnetic Compatibility (EMC) ..........................................................................................4-2 Low Voltage Directive ...................................................................................................................4-2 Supply Voltage...............................................................................................................................4-3 Environment ..............................................................................................................................................4-5 Storage ...........................................................................................................................................4-5 Operating........................................................................................................................................4-6 Elevation ........................................................................................................................................4-7 Contaminants..................................................................................................................................4-7 Vibration ........................................................................................................................................4-8 Packaging .......................................................................................................................................4-8 UL Class 1 Division 2 Listed Boards .............................................................................................4-8
ii x Contents
GEH-6421H Mark VI Control System Guide Volume I
Chapter 5 Installation and Configuration
5-1
Introduction ...............................................................................................................................................5-1 Installation Support ...................................................................................................................................5-1 Early Planning..............................................................................................................................5-2 GE Installation Documents ..........................................................................................................5-2 Technical Advisory Options ........................................................................................................5-3 Equipment Receiving and Handling........................................................................................................5-5 Weights and Dimensions.........................................................................................................................5-6 Cabinets........................................................................................................................................5-6 Control Console (Example)..........................................................................................................5-10 Power Requirements................................................................................................................................5-11 Installation Support Drawings.................................................................................................................5-12 Grounding ...............................................................................................................................................5-17 Equipment Grounding..................................................................................................................5-17 Building Grounding System.........................................................................................................5-18 Signal Reference Structure (SRS) ................................................................................................5-19 Cable Separation and Routing .................................................................................................................5-25 Signal/Power Level Definitions ...................................................................................................5-25 Cableway Spacing Guidelines......................................................................................................5-27 Cable Routing Guidelines ............................................................................................................5-30 Cable Specifications ................................................................................................................................5-31 Wire Sizes ....................................................................................................................................5-31 General Specifications .................................................................................................................5-32 Low Voltage Shielded Cable .......................................................................................................5-32 Connecting the System............................................................................................................................5-35 I/O Wiring....................................................................................................................................5-37 Terminal Block Features ..............................................................................................................5-38 Power System...............................................................................................................................5-38 Installing Ethernet ........................................................................................................................5-38 Startup Checks.........................................................................................................................................5-41 Board Inspections.........................................................................................................................5-41 Wiring and Circuit Checks...........................................................................................................5-44 Startup and Configuration .......................................................................................................................5-45 Topology and Application Code Download.................................................................................5-46 Online Download .........................................................................................................................5-47 Offline Download ........................................................................................................................5-48 Post-Download TMR Test ...........................................................................................................5-48 Controller Offline While System Online......................................................................................5-49 Offline Trip Analysis ...................................................................................................................5-49
Chapter 6 Tools and System Interface
6-1
Introduction ...............................................................................................................................................6-1 Toolbox .....................................................................................................................................................6-1 CIMPLICITY HMI ...................................................................................................................................6-4 Basic Description ...........................................................................................................................6-4 Product Features.............................................................................................................................6-6 Computer Operator Interface (COI) ..........................................................................................................6-7 Interface Features...........................................................................................................................6-7 Turbine Historian ......................................................................................................................................6-8 System Configuration.....................................................................................................................6-8 System Capability ..........................................................................................................................6-9 Data Flow.......................................................................................................................................6-9 Turbine Historian Tools ...............................................................................................................6-10
GEH-6421H Mark VI Control System Guide Volume I
Contents x iii
Chapter 7 Maintenance, Diagnostic, & Troubleshooting
7-1
Introduction ...............................................................................................................................................7-1 Maintenance ..............................................................................................................................................7-1 Modules and Boards.......................................................................................................................7-1 Component Replacement...........................................................................................................................7-2 Replacing a Controller ...................................................................................................................7-2 Replacing a VCMI .........................................................................................................................7-3 Replacing an I/O Board in an Interface Module.............................................................................7-3 Replacing a Terminal Board...........................................................................................................7-4 Cable Replacement.........................................................................................................................7-5 Alarms Overview.......................................................................................................................................7-6 Process Alarms ..........................................................................................................................................7-7 Process (and Hold) Alarm Data Flow ............................................................................................7-7 Diagnostic Alarms .....................................................................................................................................7-9 Voter Disagreement Diagnostics..................................................................................................7-10 Totalizers .................................................................................................................................................7-11 Troubleshooting.......................................................................................................................................7-12 I/O Board LEDs ...........................................................................................................................7-12 Controller Failures .......................................................................................................................7-14 Power Distribution Module Failure..............................................................................................7-14
Chapter 8 Applications
8-1
Introduction ...............................................................................................................................................8-1 Generator Synchronization ........................................................................................................................8-1 Hardware ........................................................................................................................................8-2 Application Code ...........................................................................................................................8-4 Algorithm Descriptions ..................................................................................................................8-5 Configuration .................................................................................................................................8-9 VTUR Diagnostics for the Auto Synch Function.........................................................................8-12 VPRO Diagnostics for the Auto Synch Function.........................................................................8-12 Hardware Verification Procedure.................................................................................................8-13 Synchronization Simulation .........................................................................................................8-13 Overspeed Protection Logic ....................................................................................................................8-15 Power Load Unbalance............................................................................................................................8-39 Early Valve Actuation .............................................................................................................................8-43 Fast Overspeed Trip in VTUR.................................................................................................................8-45 Compressor Stall Detection .....................................................................................................................8-48 Ground Fault Detection Sensitivity .........................................................................................................8-52
Glossary of Terms
G-1
Index
I-1
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GEH-6421H Mark VI Control System Guide Volume I
CHAPTER 1
Chapter 1 Overview Related Documents..................................................................... 1-2 How to Get Help......................................................................... 1-3 Acronyms and Abbreviations ..................................................... 1-3
Introduction This document describes the SPEEDTRONIC™ Mark VI turbine control system. Mark VI is used for the control and protection of steam and gas turbines in electrical generation and process plant applications. The main functions of the Mark VI turbine control system are as follows: x
Speed control during turbine startup
x
Automatic generator synchronization
x
Turbine load control during normal operation on the grid
x
Protection against turbine overspeed on loss of load
The Mark VI system is available as a simplex control or a triple modular redundant (TMR) control with single or multiple racks, and local or remote I/O. The I/O interface is designed for direct interface to the sensors and actuators on the turbine, to eliminate the need for interposing instrumentation, and to avoid the reliability and maintenance issues associated with that instrumentation. Note To obtain the highest reliability, Mark VI uses a TMR architecture with sophisticated signal voting techniques. The following figure shows a typical Mark VI control system for a steam turbine with the important inputs and control outputs.
GEH-6421H Mark VI Control System Guide Volume I
Chapter 1 Overview x 1-1
RS-232C
Laptop
Mark VI I/O Board Rack
PC Interface Comm Controller UCVX VCMI
VSVO
VTUR VAIC
Speed Extraction Pressure Exhaust Pressure Shaft Voltage & Current Monitor Automatic Synchronizing
Vibration, Thrust, Eccentricity Temperature (RTDs) Temperature (Thermocouples) Generator 3-Phase PTs & CT
(2) 3-Phase Gen/Line Voltage, (1) 3-Phase Gen. Current
Trip Generator
(24) Thermocouples
Inlet Pressure
(16) RTDs
Actuator
Proximitors: (16) Vibration, (8) Position, (2) KP
Actuator
VVIB VRTD VTCC VGEN
(24) Relays
(48) Contact Inputs. 1 ms SOE
Ethernet Data Highway
VCCC or VCRC
Typical Turbine Control System
Related Documents For additional information, refer to the following documents:
1-2 x Chapter 1 Overview
x
GEH-6403 Control System Toolbox for a Mark VI Controller (for details of configuring and downloading the control system)
x
GEH-6422 Turbine Historian System Guide (for details of configuring and using the Historian)
x
GEH-6408 Control System Toolbox for Configuring the Trend Recorder (for details of configuring the toolbox trend displays)
x
GEI-100534, Control Operator Interface (COI) for Mark VI and EX2100 Systems
x
GEI-100535, Modbus Communications
x
GEI-100536, Profibus Communications
x
GEI-100189, System Database (SDB) Server User's Guide
x
GEI-100271, System Database (SDB) Browser
GEH-6421H Mark VI Control System Guide Volume I
How to Get Help If technical assistance is required beyond the instructions provided in the documentation, contact GE as follows: GE Energy Post Sales Service 1501 Roanoke Blvd. Salem, VA 24153-6492 USA Phone: 1 888 GE4 SERV (888 434 7378, United States) + 1 540 378 3280 (International) Fax: + 1 540 387 8606 (All) Note "+" indicates the international access code required when calling from outside the USA.
Acronyms and Abbreviations ADL
Asynchronous Device Language
ASCII
America Standard Code for Information Interchange
BOP
Balance of Plant
BIOS
Basic Input/Output System
CCR
Central Control Room
CMOS
Complementary Metal-Oxide Semiconductor
COI
Computer Operator Interface
CPCI
CompactPCI
CPU
Central Processing Unit
CRC
Cyclic Redundancy Code/Check
CT
Current Transformer
DCE
Data Communication Equipment
DCS
Distributed Control System
DDE
Data Distribution Equipment
DHCP
Dynamic Host Configuration Protocol
DRAM
Dynamic Random Access Memory
DTD
Data Terminal Equipment Device
EGD
Ethernet Global Data
EMC
Electromagnetic Capability
EMI
Electro-Magnetic Interference
EVA
Early Valve Actuation
FE
Functional Earth
FFT
Fast Fourier Transform
FIT
Failures in Time
GPS
Global Position System
GSM
GE Standard Messaging
GTS
Global Time Source
HMI
Human-Machine Interface
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Chapter 1 Overview x 1-3
HRSG
1-4 x Chapter 1 Overview
Heat Recovery Steam Generator
ICS
Integrated Control System
IEEE
Institute of Electrical and Electronics Engineers
KP
KeyPhasor®
LAN
Local Area Network
MPU
Magnetic Pickup
MTBF
Mean Time Between Failures
MTBFO
Mean Time Between Forced Outage
MTTR
Mean Time To Repair
NEC
National Electrical Code
NEMA
National Electrical Manufacturer’s Association
NFPA
National Fire Protection Association
NTP
Network Time Protocol
PDH
Plant Data Highway
PE
Protective Earth
PLU
Power Load Unbalance
PDM
Power Distribution Module
PLC
Programmable Logic Controller
PPS
Pulse per Second
PT
Potential Transformer
RFI
Radio Frequency Interference
RLD
Relay Ladder Diagram
RPM
Revolutions Per Minute
RPSM
Redundant Power Supply Module
RTD
Resistance Temperature Device
RTU
Remote Terminal Unit
SDB
Systems Database
SIFT
Software Implemented Fault Tolerance
SOE
Sequence of Events
SOF
Start of Frame
SRS
Single Reference Structure
TMR
Triple Modular Redundant
UART
Universal Asynchronous Receiver/Transmitter
UDH
Unit Data Highway
UTC
Coordinated Universal Time
VLAN
Virtual Local Area Network
WAN
Wide Area Network
GEH-6421H Mark VI Control System Guide Volume I
CHAPTER 2
Chapter 2 System Architecture System Components ................................................................... 2-1 Levels of Redundancy ................................................................ 2-20 Control and Protection Features ................................................. 2-21 Turbine Protection ...................................................................... 2-34 Reliability and Availability ........................................................ 2-36 Third Party Connectivity ............................................................ 2-38
Introduction This chapter defines the architecture of the Mark VI turbine control system, including the system components, the three communication networks, and the various levels of redundancy that are possible. It also discusses system reliability and availability, and third-party connectivity to plant distributed control systems.
System Components This section summarizes the main subsystems that make up the Mark VI control system. These include the controllers, I/O boards, terminal boards, power distribution, cabinets, networks, operator interfaces, and the protection module.
Control Cabinet The control cabinet contains either a single (simplex) Mark VI control module or three TMR control modules. These are linked to their remote I/O by a single or triple high speed I/O network called IONet, and are linked to the UDH by their controller Ethernet port. Local or remote I/O is possible. The control cabinet requires 120/240 V ac and/or 125 V dc power. This is converted to 125 V dc to supply the modules.
I/O Cabinet The I/O cabinet contains either single or triple interface modules. These are linked to the controllers by IONet, and to the terminal boards by dedicated cables. The terminal boards are in the I/O cabinet close to the interface modules. Power requirements are 120/240 V ac and/or 125 V dc power.
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Unit Data Highway (UDH) The UDH connects the Mark VI control panels with the HMI or HMI/Data Server. The network media is UTP or fiber-optic Ethernet. Redundant cable operation is optional and, if supplied, unit operation continues even if one cable is faulted. Dual cable networks still comprise one logical network. Similar to the plant data highway (PDH), the UDH can have redundant, separately powered network switches, and fiber optic communication. UDH command data is replicated to all three controllers. This data is read by the Master communication controller board (VCMI) and transmitted to the other controllers. Only the UDH communicator transmits UDH data (refer to the section, UDH Communicator). Note The UDH network supports the Ethernet Global Data (EGD) protocol for communication with other Mark VIs, HRSG, Exciter, Static Starter, and Balance of Plant (BOP) control. To Optional Customer Network
HMI Viewer
Enterprise Layer
Router
HMI Viewer
HMI Viewer
Field Support
Supervisory Layer
PLANT DATA H IGHWAY PLANT DATA H IGHWAY
HMI Servers
Control Layer U NIT D ATA H IGHWAY U NIT DATA H IGHWAY Steam Turbine Control
Gas Turbine Control TMR
Mark VI
Mark VI
Mark VI
Generator Protection
Exciter
BOP
Gen. Protect
90-70 PLC
EXCITER
Mark VI
I/O Boards
Genius Bus
IONet
IONet
I/O Boards
I/O Boards
Typical Mark VI Integrated Control System
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GEH-6421H Mark VI Control System Guide Volume I
Human-Machine Interface (HMI) Typical HMI’s are computers running Windows operating system with communication drivers for the data highways, and CIMPLICITY operator display software. The operator initiates commands from the real time graphic displays, and can view real time turbine data and alarms on the CIMPLICITY graphic displays. Detailed I/O diagnostics and system configuration are available using the toolbox software. An HMI can be configured as a server or viewer, and can contain tools and utility programs. An HMI may be linked to one data highway, or redundant network interface boards can be used to link the HMI to both data highways for greater reliability. The HMI can be cabinet, control console or table-mounted.
Servers CIMPLICITY servers collect data on the UDH and use the PDH to communicate with viewers. Multiple servers can be used to provide redundancy. Note Redundant data servers are optional, and if supplied, communication with the viewers continues even if one server fails.
Computer Operator Interface (COI) The Computer Operator Interface (COI) consists of a set of product and application specific operator displays running on a small cabinet computer (10.4 or 12.1 inch touch screen) hosting Embedded Windows operating system. The COI is used where the full capability of a CIMPLICITY HMI is not required. Embedded Windows operating system uses only the components of the operating system required for a specific application. This results in all the power and development advantages of a Windows operating system. Development, installation or modification of requisition content requires the toolbox. For details, refer to the appropriate toolbox documentation. The COI can be installed in many different configurations, depending on the product line and specific requisition requirements. The only cabling requirements are for power and for the Ethernet connection to the UDH. Network communication is via the integrated auto-sensing 10/100BaseT Ethernet connection. Expansion possibilities for the computer are limited, although it does support connection of external devices through FDD, IDE, and USB connections. The COI can be directly connected to the Mark VI or Excitation Control System, or it can be connected through an EGD Ethernet switch. A redundant topology is available when the controller is ordered with a second Ethernet port.
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Chapter 2 System Architecture x 2-3
Interface Features EGD pages transmitted by the controller are used to drive numeric data displays. The refresh rate depends both on the rate at which the controller transmits the pages, and the rate at which the COI refreshes the fields. Both are set at configuration time in the toolbox. The COI uses a touch screen, and no keyboard or mouse is provided. The color of pushbuttons is driven by state feedback conditions. To change the state or condition, press the button. The color of the button changes if the command is accepted and the change implemented by the controller. Touching an input numeric field on the COI touch screen displays a numeric keypad and the desired number can be entered. An Alarm Window is provided and an alarm is selected by touching it. Then Ack, Silence, Lock, or Unlock the alarm by pressing the corresponding button. Multiple alarms can be selected by dragging through the alarm list. Pressing the button then applies to all selected alarms. For complete information, refer to GEI-10043, Computer Operator Interface (COI) for Mark VI or EX2100 Systems.
Link to Distributed Control System (DCS) External communication links are available to communicate with the plant distributed control system. A serial communication link, using Modbus protocol (RTU binary), can be supplied from an HMI or from a gateway controller. This allows the DCS operator access to real time Mark VI data, and provides for discrete and analog commands to be passed to the Mark VI control. In addition, an Ethernet link from the HMI supports periodic data messages at rates consistent with operator response, plus sequence of events (SOE) messages with data time tagged at a 1 ms resolution.
Plant Data Highway (PDH) The optional PDH connects the CIMPLICITY HMI/Data Server with remote operator stations, printers, historians, and other customer computers. It does not connect with the Mark VI directly. The media is UTP or fiber-optic Ethernet running at 10/100 Mbps, using the TCP/IP protocol. Redundant cables are required by some systems, but these form part of one single logical network. The hardware consists of two redundant Ethernet switches with optional fiber-optic outputs for longer distances, such as to the central control room. On small systems, the PDH and the Unit Data Highway (UDH) may physically be the same network, as long as there is no peer-to-peer control on the UDH.
Operator Console The turbine control console is a modular design, which can be expanded from two monitors, with space for one operator, to four monitors, with space for three operators. Printers can be table-mounted, or on pedestals under the counter. The full size console is 5507.04 mm (18 ft 0 13/16 in) long, and 2233.6 mm (7 ft 3 15/16 in) wide. The center section, with space for two monitors and a phone/printer bay, is a small console 1828.8 mm (6 ft) wide.
2-4 x Chapter 2 System Architecture
GEH-6421H Mark VI Control System Guide Volume I
Excitation Control System The excitation control system supplies dc power to the field of the synchronous generator. The exciter controls the generator ac terminal voltage and/or the reactive volt-amperes by means of the field current. The exciter is supplied in NEMA 1 freestanding floor-mounted indoor type metal cabinets. The cabinet lineup consists of several cabinets bolted together. Cable entry can be through the top or bottom.
Generator Protection The generator protection system is mounted in a single, indoor, freestanding cabinet. The ensclosure is NEMA 1, and weighs 1133 kg (2500 lbs). The generator cabinet interfacesto the Mark VI with hard-wired I/O, and has an optional Modbus interface to the HMI.
Static Starter Control System The static starter control system is used to start a gas turbine by running the generator as a starting motor. The static starter system is integrated into the control system along with the excitation control system. The control supplies the run, torque, and speed setpoint signals to the static starter, which operates in a closed loop control mode to supply variable frequency power to the generator stator. The excitation control system is controlled by the static starter to regulate the field current during startup. The control cabinet contains an Innovation Series™ controller in a Versa Module Eurocard (VME) control rack. The controller provides the Ethernet link to the UDH and the HMI, and communication ports for field control I/O and Modbus. The field control I/O are used for temperature inputs and diagnostic variables. The static starter cabinet is a ventilated NEMA 1 free standing enclosure made of 12gauge sheet steel on a rigid steel frame designed for indoor mounting.
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Control Module The control module is available as an integrated control and I/O module, or as a stand-alone control module only. The integrated control and I/O rack can be either a 21-slot or 13-slot VME size. The 13-slot rack can accommodate all the boards for control of a small turbine. The backplane has P1 and P2 connectors for the VME boards. The P1 connectors communicate data across the backplane, and the P2 connectors communicate data between the board and 37-pin J3 and J4 connectors located directly beneath each board. Cables run from the J3 and J4 connectors to the terminal boards. There can be one control module (simplex) or three triple modular redundant (TMR) control modules. Each of these configurations supports remote I/O over IONet. The simplex control modules can be configured to support up to three independent parallel IONet systems for higher I/O throughput. Multiple communication boards may be used in a control module to increase the IONet throughput. The following figure shows a 21-slot rack with a three-IONet VCMI communication board, and a UCVx controller. The UCVx must go in slot 2. The remaining slots are filled with I/O boards. Controller UCVx (slot 2)
VME Chassis, 21 slots
x
x
I/O Processor Boards
Fan
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Power Supply
UDH Port
VCMI Communication Board, with One or Three IONet Ports x
x
x
x
x
x
x
x
x
Note: This rack is for the UCVx controller, connectors J302 and J402 are not present. UCVB and UCVD controllers can be used in this rack.
x
x
x
x
x
x
x
x
x
x
x
x
Connectors for Cables to Terminal Boards (J3 & J4)
Control Module with Control, Communication, and I/O Boards
2-6 x Chapter 2 System Architecture
GEH-6421H Mark VI Control System Guide Volume I
The I/O racks and the I/O processor boards are shielded to control EMI/RFI emissions. This shielding also protects the processor boards against interference from external sources. Do not plug the UCVx controller into any rack that has J302 and J402 connectors.
The stand-along controller module is a VME rack with the UCVx controller board, VCMI communication board, and VDSK interface board as shown in the following figure. This version is for remote I/O systems. The rack is powered by an integrated power supply. VDSK supplies 24 V dc to the cooling fan mounted under the rack, and monitors the Power Distribution Module (PDM) through the 37-pin connector on the front. The VDSK board is ribbon cabled in the back to the VCMI to transmit the PDM diagnostics. VCMI Communication Board with Three IONet Ports (VCMI with One IONet is for Simplex systems)
Controller UCVx
x
x
x
x
x
x
x
x
Interface Board VDSK
VME Rack POWER SUPPLY
Power Supply
Cooling Fan behind Panel
Fan 24 Vdc Power
Rack with Controller, VCMI, and VDSK (No I/O Boards)
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Chapter 2 System Architecture x 2-7
Interface Module The interface module houses the I/O boards remote from the control module. The rack, shown in the following figure is similar to the control module VME rack, but without the controller, interface board VDSK, and cooling fan. Each I/O board occupies one or two slots in the module and has a backplane connection to a pair of 37-pin D connectors mounted on an apron beneath the VME rack. Cables run from the 37-pin connectors to the terminal boards. Most I/O boards can be removed, with power removed, and replaced without disconnecting any signal or power cable. Communication with the module is via a VCMI communication board with a single IONet port, located in the left slot. The module backplane contains a plug wired to slot 1, which is read by the communication board to obtain the identity of the module on the IONet. VME Chassis, 21 slots VCMI Communication Board with one IONet Port
x
x
x
x
x
x
x
I/O Processor Boards
x
x
x
x
x
x
x
x
x
x
x
x
x
x
Power Supply
IONet Link to Control Module
x
x
x
x
x
x
x
x
x
x
Note: Slot 2 cannot be used for an I/O processor board; it is reserved for a controller board
x
x
x
x
x
x
x
x
x
x
x
J3 & J4 Connectors for Cables to Terminal Boards
Interface Module with VCMI and I/O Boards
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Controller The controller is a single-slot VME board, housing a high-speed processor, DRAM, flash memory, cache, an Ethernet port, and two serial RS-232C ports. It must always be inserted in slot 2 of an I/O rack designed to accommodate it. These racks can be identified by the fact that there are no J3 and J4 connectors under slot 2. The controller provides communication with the UDH through the Ethernet port, and supports a low-level diagnostic monitor on the COM1 serial port. The base software includes appropriate portions of the existing Turbine Block Library of control functions for the steam, gas, and Land-Marine aero-derivative (LM) products. The controller can run its program at up to 100 Hz, (10 ms frame rate), depending on the size of the system configuration. External data is transferred to/from the controller over the VME bus by the VCMI communication board. In a simplex system, the data consists of the process I/O from the I/O boards, and in a TMR system, it consists of voted I/O. Refer to GEH-6421, Volume II. Typical Mark VI Controller (UCVx) x
Status LEDs STATUS
VMEbus SYSFAIL Flash Activity Power Status
Monitor Port for GE use S V G A
Keyboard/mouse port for GE use
M / K
COM1 RS-232C Port for Initial Controller Setup; COM2 RS-232C Port for Serial communication
C O M
Ethernet Status LEDs
1:2
Ethernet Port for Unit Data Highway Communication
L A N
Active RST P C M I P
Link
Notice: To connect batteries, user to set jumper E8 to pins 7-8 ("IN") and jumper E10 to ("IN")
M E Z Z A N I N E UCVE H2A x
UCVx Controller Front Cabinet
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Chapter 2 System Architecture x 2-9
VCMI Communication Board The VCMI board in the control and interface module communicates internally to the I/O boards in its rack, and to the other VCMI cards through the IONet. There are two versions, one with one Ethernet IONet port for simplex systems, and the other with three Ethernet ports for TMR systems. Simplex systems have one control module connected to one or more interface modules using a single cable. The VCMI with three separate IONet ports is used in TMR systems for communication with the three I/O channels Rx, Sx, and Tx, and with the two other control modules. This is shown in the following figure. Software Implemented Fault Tolerance (SIFT) voting is implemented in the VCMI board. Input data from each of the IONet connections is voted in each of the R, S, and T VCMI boards. The results are passed to the control signal database in the controllers (labeled UCVx in the diagram) through the backplane VME bus. Control Module R0 VCMI Board with Three IONet Ports
V C M I
U C V X
I/O Boards IONet - T to other Control, Interface, & Protection Modules IONet - S to other Control, Interface, & Protection Modules
IONet - R Interface Module R1 VCMI Board with One IONet Port
V C M I
I/O Boards
IONet to other Interface Modules & Protection Module VCMI Boards providing I/O Communication and I/O Voting
In TMR mode, the VCMI voter in the control module is always the Master of the IONet and also provides the IONet clock. Time synch messages from the time source on the UDH are sent to the controllers and then to the VCMIs. All input data from a single rack is sent in one or more IONet packets (approximately 1500 bytes per packet maximum). The VCMI in the control module broadcasts all data for all remote racks in one packet, and each VCMI in the remote rack extracts the appropriate data from the packet.
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IONet The IONet connection on the VCMI is a BNC for 10Base2 Ethernet. The interface circuit is high impedance allowing “T” tap connections with 50 : terminal at the first and last node. The cabling distances are restricted to 185 meters per segment with up to eight nodes, using RG-58C/U or equivalent cable. The Link Layer protocol is IEEE 802.3 standard Ethernet. The application layer protocol uses Asynchronous Device Language (ADL) messaging with special adaptations for the input/output handling and the state exchanges. The VCMI board acts as IONet Master and polls the remote interface module for data. The VCMI Master broadcasts a command to all slave stations on a single IONet causing them to respond with their message in a consecutive manner. To avoid collisions on the media, each station is told how long to delay before attempting to transmit. Utilizing this Master/slave mechanism, and running at 10 Mb/s, the IONet is capable of transmitting a 1000 byte packet every millisecond (8 MHz bit rate). Note IONet supports control operation at up to 100 times per second. In a multiple module or multiple cabinet system, powering down one module of a channel does not disrupt IONet communication between other modules within that channel. If one IONet stops communicating then the I/O boards, in that channel, time out and the outputs go to a safe state. This state does not affect TMR system operation. If two IONets stop then the I/O boards in both channels go to a safe state which would result in a turbine trip, if the turbine was generating.
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Chapter 2 System Architecture x 2-11
I/O Boards Most I/O boards, are single width VME boards, of similar design and front cabinet, using the same digital signal processor (TMS320C32). The central processing unit (CPU) is a high-speed processor designed for digital filtering and for working with data in IEEE 32-bit floating point format. The task scheduler operates at a 1 ms and 5 ms rate to support high-speed analog and discrete inputs. The I/O boards synchronize their input scan to complete a cycle before being read by the VCMI board. Contact inputs in the VCCC and VCRC are time stamped to 1 ms to provide a sequence of events (SOE) monitor. Each I/O board contains the required sensor characteristic library, for example thermocouple and RTD linearizations. Bad sensor data and alarm signal levels, both high and low, are detected and alarmed. The I/O configuration in the toolbox can be downloaded over the network to change the program online. This means that I/O boards can accept tune-up commands and data while running. Certain I/O boards, such as the servo and turbine board, contain special control functions in firmware. This allows loops, such as the valve position control, to run locally instead of in the controller. Using the I/O boards in this way provides fast response for a number of time critical functions. Servo loops, can be performed in the servo board at 200 times per second. Each I/O board sends an identification message (ID packet) to the VCMI when requested. The packet contains the hardware catalog number of the I/O board, the hardware revision, the board barcode serial number, the firmware catalog number, and the firmware version. Also each I/O board identifies the connected terminal boards via the ID wire in the 37-pin cable. This allows each connector on each terminal board to have a separate identity. I/O Processor Terminal Board Board
VAIC
TBAI (2)
I/O Signal Types
Analog inputs, 01mA, 420 mA, voltage
No. per I/O Processor Board
20
Type of Terminal Comments Board
TMR, simplex
4
Analog outputs, 420 mA, 0200 mA VAOC
TBAO
Analog outputs, 420 mA
16
TMR, simplex
VCCC and VCRC
TBCI (2)
Contact inputs
48
TRLY (2)
Relay Outputs (note 1)*
24
TMR, simplex
VCCC
TICI (2)
Point Isolated Contact inputs
48
TMR, simplex
VGEN
TGEN
Analog inputs, 420 mA
4
TMR, simplex
Potential transformers
2
Current transformers
3
TRLY
Relay outputs (optional)
12
TPRO
Pulse rate
3
(VCCC is two slots)
TMR, simplex
VPRO (3)
Potential transformers
2
Thermocouples
3
Analog inputs, 420 mA
3
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VCCC-only in place of TBCI. (optional)
for FAS (PLU) TMR
Emergency Protect
GEH-6421H Mark VI Control System Guide Volume I
TREG (2)
TREL TRES VPYR
TPYR
Solenoid drivers
6
Trip contact inputs
7
Emergency stop
2
Solenoid drivers
3
Trip contact inputs
7
Solenoid drivers
3
Trip contact inputs
7
Pyrometers (4 analog inputs each)
2
KeyPhasor shaft position sensors
2
TMR
Gas turbine Hardwire,Trip ,Clamp
TMR
Large steam
TMR, simplex
Small/medium steam
TMR, simplex
VRTD
TRTD,
Resistance Temperature Devices (RTD)
16
TMR, simplex
3 wire
VSVO
TSVO (2)
Servo outputs to valve hydraulic servo
4
TMR, simplex
Trip, Clamp, Input
LVDT inputs from valve
12
LVDT excitation
8
Pulse rate inputs for flow monitoring
2
Pulse rate excitation
2
VTCC
TBTC
Thermocouples
24
TMR, simplex
VTUR
TTUR
Pulse rate magnetic pickups
4
TMR, simplex
Potential transformers, gen. and bus
2
Shaft current and voltage monitor
2
Breaker interface
1
Flame detectors (Geiger Mueller)
8
TRPG
VVIB
Solenoid drivers (note 2)*
3
TRPL
Solenoid drivers
3
Emergency stop
2
TRPS
Solenoid drivers
3
Emergency stop
2
TVIB (2)
Shaft vibration probes (Bently Nevada)
16
Shaft proximity probes (Displacement)
8
Shaft proximity reference (KeyPhasor)
2
TMR, simplex
Gas turbine
TMR
Large steam
TMR, simplex
Small/med. steam
TMR, simplex
Buffered using BNC
*Note 1: Refer to the table in the section Relay Terminal Boards *Note 2: VTURH2 occupies two slots and supports two TRPG boards, flame detector support on only the first TRPG.
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Terminal Boards The terminal board provides the customer wiring connection point, and fans out the signals to three separate 37-pin D connectors for cables to the R, S, and T I/O boards. Each type of I/O board has its own special terminal board, some with a different combination of connectors. For example, one version of the thermocouple board does not fan out and has only two connectors for cabling to one I/O board. The other version does fan out and has six connectors for R, S, and T. Since the fan out circuit is a potential single point failure, the terminal board contains a minimum of active circuitry limited primarily to filters and protective devices. Power for the outputs usually comes from the I/O board, but for some relay and solenoid outputs, separate power plugs are mounted on the terminal board. TBAI Terminal Board x
Customer Wiring
x x x x x x x x x x x x
x x x x x x x x x x x x x
JT1
37-pin "D" shell type connectors with latching fasteners
JS1
Cable to VME Rack T
x
Shield Bar
x
Customer Wiring
BarrierType Terminal Blocks can be unplugged from board for maintenance
x x x x x x x x x x x x x
x x x x x x x x x x x x
JR1
x
Cable to VME Rack S
Cable to VME Rack R
Typical Terminal Board with Cabling to I/O Boards in VME Rack
DIN-rail Mounted Terminal Boards Smaller DIN-rail mounted terminal boards are available for simplex applications. These low cost, small size simplex control systems are designed for small gas and steam turbines. IONet is not used since the D-type terminal boards cable directly into the control chassis to interface with the I/O boards. The types of DIN-rail boards are shown in the following table.
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DIN–Rail Mounted Terminal Boards
DIN Euro Size Terminal Board
Number of Points
Description of I/O
Associated I/O Processor Board
DTTC
12
Thermocouple temperature inputs with one cold junction reference
VTCC
DRTD
8
RTD temperature inputs
VRTD
DTAI
10
Analog current or voltage inputs with on-board 24 V dc power supply
VAIC
2
Analog current outputs, with choice of 20 mA or 200 mA
DTAO
8
Analog current outputs, 0-20 mA
VAOC
DTCI
24
Contact Inputs with external 24 V dc excitation
VCRC (or VCCC)
DRLY
12
Form-C relay outputs, dry contacts, customer powered
VCRC (or VCCC)
DTRT
-------
Transition board between VTUR and DRLY for solenoid trip functions
VTUR
DTUR
4
Magnetic (passive) pulse rate pickups for speed and fuel flow measurement
VTUR
DSVO
2
Servo-valve outputs with choice of coil currents from 10 mA to 120 mA
VSVO
6
DVIB
DSCB
LVDT valve position sensors with on-board excitation
2
Active pulse rate probes for flow measurement, with 24 V dc excitation provided
8
Vibration, Position, or Seismic, or Accelerometer, or Velomiter
4
Position prox probes
1
KeyPhasor (reference)
6
Serial communication ports supporting RS-232C, RS-422 & RS-485.
GEH-6421H Mark VI Control System Guide Volume I
VVIB
VSCA
Chapter 2 System Architecture x 2-15
Relay Terminal Boards The following table provides a comparison of the features offered by the different relay terminal boards. Relay Terminal Boards
Board
Relays
12 form C relays 24dc@10A DRLYH1A
[email protected] 120ac@10A 240ac@3A
Power Feedback Relay type Distribution
Redundancy
Suppression Terminals
none
soldered sealed none, simplex only mechanical relays
No
72 Euro-box
none
none
soldered sealed none, simplex only mechanical relays
No
72 Euro-box
12 form C relays 24dc@3A
[email protected] 120/240ac@3A
6 fused branches, 1 special unfused
voted coil drive
socketed Coil drive = voted sealed TMR input or mechanical simplex input relays
MOV
48 Barrier
12 form C relays TRLYH1C
[email protected] 120/240ac@3A
6 fused branches, 1 special unfused
isolated contact voltage feedback
socketed Coil drive = voted sealed TMR input or mechanical simplex input relays
MOV & R-C
48 Barrier
12 form C relays TRLYH2C 24dc@3A
6 fused branches, 1 special unfused
isolated contact voltage feedback
socketed Coil drive = voted sealed TMR input or mechanical simplex input relays
MOV & R-C
48 Barrier
6 fused branches
ohm meter (dc solenoid integrity monitor)
socketed Coil drive = voted sealed TMR input or mechanical simplex input relays
MOV
24 Barrier
none
isolated soldered contact solid-state voltage relays feedback
Coil drive = voted TMR input or simplex input
No
24 Barrier
none
isolated soldered contact solid-state voltage relays feedback
Coil drive = voted TMR input or simplex input
No
24 Barrier
Coil drive = voted TMR input or simplex input
No
24 Barrier
12 form C relays 24dc@2A DRLYH1B
[email protected] 120ac@1A
[email protected]
TRLYH1B
6 form A relays TRLYH1D 24dc@3A
[email protected]
none
TRLYH1E
12 form A relays 120/240ac@6A
TRLYH2E
12 form A relays 24dc@7A
TRLYH3E
12 form A relays 125dc@3A
none
isolated soldered contact solid-state voltage relays feedback
12 form A relays
none without WPDF
nonvoted coil drive
soldered Relay contact sealed mechanical voting, TMR only relays
No
48 Barrier (24 used)
12 form A relays
With WPDF, nonvoted 12 fused outputs coil drive
soldered Relay contact sealed mechanical voting, TMR only relays
No
48 Barrier
TRLYH1F
TRLYH1F
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TRLYH2F
TRLYH2F
12 form B relays
none without WPDF
nonvoted coil drive
soldered sealed Relay contact mechanical voting, TMR only relays
No
48 Barrier (24 used)
12 form B relays
With WPDF, non12 fused voted outputs coil drive
soldered Relay contact sealed mechanical voting, TMR only relays
No
48 Barrier
Trip Terminal Boards The following table provides a comparison of the features offered by the different trip terminal boards.
Board
TMR
Simplex
Output Contacts, 125 V dc, 1 A
Output Contacts, 24 V dc, 3 A
ESTOP
Input Contacts Dry 125 V dc
Input Contacts Dry 125 V dc
Economy Resistor
TRPGH1A*
Yes
No
Yes
No
No
No
No
No
TRPGH1B
Yes
No
Yes
Yes
No
No
No
No
TRPGH2A*
No
Yes
Yes
No
No
No
No
No
TRPGH2B
No
Yes
Yes
Yes
No
No
No
No
TREGH1A*
Yes
No
Yes
No
Yes
Yes
No
Yes
TREGH1B
Yes
No
Yes
Yes
Yes
Yes
No
Yes
TREGH2B
Yes
No
Yes
Yes
Yes
No
Yes
Yes
TRPLH1A
Yes
No
Yes
Yes
Yes
No
No
No
TRELH1A
Yes
No
Yes
Yes
No
Yes
No
No
TRELH2A
Yes
No
Yes
Yes
No
No
Yes
No
TRPSH1A
Yes
Yes
Yes
Yes
Yes
No
No
No
TRESH1A
Yes
Yes
Yes
Yes
No
Yes
No
No
TRESH2A
Yes
Yes
Yes
Yes
No
No
Yes
No
* These boards will become obsolete
Power Sources A reliable source of power is provided to the rack power supplies from either a battery, or from multiple power converters, or from a combination of both. The multiple power sources are connected as high select in the Power Distribution Module (PDM) to provide the required redundancy. A balancing resistor network creates a floating dc bus using a single ground connection. From the 125 V dc, the resistor bridge produces +62.5 V dc (referred to as P125) and -62.5 V dc (referred to as N125) to supply the system racks and terminal boards. The PDM has ground fault detection and can tolerate a single ground fault without losing any performance and without blowing fuses. This fault is alarmed so it can be repaired.
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Turbine Protection Module The Turbine Protection Module (VPRO) and associated terminal boards (TPRO and TREG) provide an independent emergency overspeed protection for turbines that do not have a mechanical overspeed bolt. The protection module is separate from the turbine control and consists of triple redundant VPRO boards, each with their own on-board power supply, as shown in the following figure. VPRO controls the trip solenoids through relay voting circuits on the TREG, TREL, and TRES boards. VPRO S8
VPRO R8
IONet S IONet T
S E R
J 5
x
x I O N E T
x
x
J 3
x
J 6
x
J 5
P5 COM P28A P28B E T H R
J 4
F VPRO
RUN FAIL STAT 8 X 4 Y T 2 Z R 1 C S E R
To TPRO
To TREG
x
RUN FAIL STAT 8 X 4 Y T 2 Z R 1 C
Ground
To TPRO
x
x
x
x x
I O N E T
IONet R
x
x
x
VPRO T8
P A R A L
N x
J 3
P O W E R x
F VPRO x
x
I O N E T
RUN FAIL STAT X 8 Y 4 T 2 Z R 1 C S E R
J 6
J 5
P5 COM P28A P28B E T H R
J 4
P A R A L
N x
J 3
P O W E R x
F VPRO x
x
J 6
P5 COM P28A P28B E T H R
J 4
P A R A L
N x
x P O W E R x
To TREG
Power In
125 Vdc Turbine Protection Module with Cabling Connections
The TPRO terminal board provides independent speed pickups to each VPRO, which processes them at high speed. This high speed reduces the maximum time delay to calculate a trip and signal the ETR relay driver to 20 ms. In addition to calculating speed, VPRO calculates acceleration which is another input to the overspeed logic. TPRO fans out generator and line voltage inputs to each VPRO where an independent generator synchronization check is made. Until VPRO closes the K25A permissive relay on TTUR, generator synchronization cannot occur. For gas turbine applications, inputs from temperature sensors are brought into the module for exhaust over temperature protection. The VPRO boards do not communicate over the VME backplane. Failures on TREG are detected by VPRO and fed back to the control system over the IONet. Each VPRO has an IONet communication port equivalent to that of the VCMI.
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Operating Systems All operator stations, communication servers, and engineering workstations use the Windows operating system. The HMIs and servers run CIMPLICITY software, and the engineer's workstation runs toolbox software for system configuration. The I/O system, because of its TMR requirements, uses a proprietary executive system designed for this special application. This executive is the basis for the operating system in the VCMI and all of the I/O boards. The controller uses the QNX operating system from QNX Software Systems Ltd. This is a real time POSIX-compliant operating system ideally suited to high speed automation applications such as turbine control and protection
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Levels of Redundancy The need for higher system reliability has led vendors to develop different systems of increasing redundancy. Simplex systems are the simplest systems having only one chain, and are therefore the least expensive. Reliability is average. TMR systems have a very high reliability, and since the voting software is simple, the amount of software required is reasonable. Input sensors can be triplicated if required. Simplex System Input
Controller
Redundancy Type
Reliability (MTBF)
Simplex
Average
Triple
Very
(TMR)
High
Output
Triple Redundant System Input
Controller Vote
Input
Controller
Vote
Output
Vote
Input
Controller Single and Triple Redundant Systems
Simplex systems in a typical power plant are used for applications requiring normal reliability, such as control of auxiliaries and balance of plant (BOP). A single PLC with local and remote I/O might be used in this application. In a typical Mark VI, many of the I/O are non-critical and are installed and configured as simplex. These simplex I/O boards can be mixed with TMR boards in the same interface module. Triple Modular Redundant (TMR) control systems, such as Mark VI, are used for the demanding turbine control and protection application. Here the highest reliability ensures the minimum plant downtime due to control problems, since the turbine can continue running even with a failed controller or I/O channel. In a TMR system, failures are detected and annunciated, and can be repaired online. This means the turbine protection system can be relied on to be fully operational, if a turbine problem occurs.
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Control and Protection Features This section describes the fault tolerant features of the TMR part of the control system. The control system can operate in two different configurations: x
Simplex configuration is for non-redundant applications where system operation after a single failure is not a requirement.
x
TMR configuration is for applications where the probability of a single failure causing a process shutdown has to be taken to an extremely low value.
Triple Modular Redundancy A TMR system is a special case of N-modular redundancy where N=3. It is based on redundant modules with input and output voting. Input signal voting is performed by software using an approach known as Software Implemented Fault Tolerance (SIFT). Output voting is performed by hardware circuits that are an integral part of the output terminal boards. The voting of inputs and outputs provides a high degree of fault masking. When three signals are voted, the failure of any one signal is masked by the other two good signals. This is because the voting process selects the median of the three analog inputs. In the case of discrete inputs, the voting selects the two that agree. In fact, the fault masking in a TMR system hides the fault so well that special fault detection functions are included as part of the voting software. Before voting, all input values are compared to detect any large differences. This value comparison generates a system diagnostic alarm. In addition to fault masking, there are many other features designed to prevent fault propagation or to provide fault isolation. A distributed architecture with dc isolation provides a high degree of hardware isolation. Restrictions on memory access using dual-port memories prevent accidental data destruction by adjacent processors. Isolated power sources prevent a domino effect if a faulty module overloads its power supply.
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TMR Architecture The TMR control architecture has three duplicate hardware controller modules labeled R, S, and T. A high-speed network connects each control module with its associated set of I/O modules, resulting in three independent I/O networks. Each network is also extended to connect to separate ports on each of the other controllers. Each of the three controllers has a VCMI communication board with three independent I/O communication ports to allow each controller to receive data from all of the I/O modules on all three I/O networks. The three protection modules are also on the I/O networks. VCMI Board with Three IONet Ports
Control Module R0 V U C C I/O M V Boards I X
Control Module S0 V U C C I/O M V Boards I X
Control Module T0 V U C C I/O M V Boards I X
TMR System with Local & Remote I/O, Terminal Boards not shown
IONet - R IONet - S IONet - T
VCMI Board with One IONet Port
Interface Module R1 V C I/O M Boards I
Interface Module S1 V C I/O M Boards I
VPRO VPRO VPRO R8 S8 T8
Interface Module T1 V C I/O M Boards I
IONet Supports Multiple Remote I/O Racks
Protection Module
TMR Architecture with Local & Remote I/O, and Protection Module
Each of the three controllers is loaded with the same software image, so that there are three copies of the control program running in parallel. External computers, such as the HMI operator stations, acquire data from only the designated controller. The designated controller is determined by a simple algorithm. A separate protection module provides for very reliable trip operation. The VPRO is an independent TMR subsystem complete with its own controllers and integral power supplies. Separate independent sensor inputs and voted trip relay outputs are used
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Redundant Unit Data Highway
1
Control Cabinet
Termination Cabinet
V Power DC C Supply / M U C DC
I V H X 2
V D S K
Control Module
1
IONET Ethernet 10Base2 Thin Coax
I V H X 2
V D S K
IONET Ethernet 10Base2 Thin Coax
Control Module
DC
I V H X 2
V D S K
IONET Ethernet 10Base2 Thin Coax
Control Module
Input Power Converter Input Power Converter
Protection Modules
Power
Buss to
Supplies
Input Power Converter
IONET Interface to other I/O Cabinet Lineups (Optional)
DC / DC
Power Supply
V DC I I I C I I I / / / / 21 SLOT M / / / DC I O O O VME RACK O O O H 1
+125Vdc Internal
Power
Terminal Boards
Power Supply
V I I I C I I I / / / M / / / 21 SLOT O OO O O O I VME RACK H 1
Interface Module
Serial Power DC V U Supply / C M C
V I I I DC C I I I / 21 SLOT / / / M / / / I O O O VME RACK O O O DC H 1
Interface Module
Serial Power DC V U Supply / C DC M C
1
Power Supply
Interface Module
Serial
Input Power Converter Input Power Converter Input Power Converter Input Power Cond.
V V V P P P R R R O O O
+125Vdc Internal Power Busses to Power Supplies & Terminal Boards
T R I P
To Contact Input Excitatn. Terminal Solenoid Power Boards
Customer Sensor Cables
Customer Supplied Power Input(s)
Typical Cabinet Layout of Mark VI TMR System
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TMR Operation Voting systems require that the input data be voted, and the voted result be available for use on the next calculation pass. The sequential operations for each pass are input, vote, calculate, and output. The time interval that is allotted to these operations is referred to as the frame. The frame is set to a fixed value for a given application so that the control program operates at a uniform rate. For SIFT systems, a significant portion of the fault tolerance is implemented in software. The advantage to this approach is software does not degrade over time. The SIFT design requires little more than three identical controllers with some provision of transferring data between them. All of the data exchange, voting, and output selection may be performed by software. The exception to the all software approach is the modification to the hardware output circuitry for hardware voting. With each controller using the same software, the mode control software in each controller is synchronizing with, and responding to, an identical copy of itself that is operating in each of the other controllers. The three programs acting together are referred to as the distributed executive and coordinate all operations of the controllers including the sequential operations mentioned above. There are several different synchronization requirements. Frame synchronization enables all controllers and associated I/O modules to process the data at the same time for a given frame. The frame synchronization error is determined at the start of frame (SOF) and the controllers are required to adjust their internal timing so that all three controllers reach SOF of the same frame at the same time. The acceptable error in time of SOF is typically several microseconds in the 10 to 25 Hz control systems that are encountered. Large errors in SOF timing will affect overall response time of the control since the voter will cause a delay until at least two controllers have computed the new values. The constraining requirement for synchronization comes from the need to measure contact SOE times with an accuracy of 1 ms.
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Designated Controller Although three controllers R, S, and T contain identical hardware and software, some of the functions performed are individually unique. A single designated controller is automatically chosen to perform the following functions: x
Supply initialization data to the other two controllers at boot-up
x
Keep the Master time clock
x
Calculate the control state data for the cabinet if one of the other controllers fails.
The VCMIs determine the designated controller through a process of nomination and voting based upon local visibility of the IONet and whether a designated controller currently exists. If all controllers are equal, a priority scheme is used favoring first R, then S, and then T. If a controller, which was designated, is powered down and repowered, the designated controller will move and not come back if all controllers are equal. This ensures that a toggling designated controller is not automatically reselected.
UDH Communicator Controller communications takes place across the Unit Data Highway (UDH). A UDH communicator is a controller selected to provide the cabinet data to that network. This data includes both control signals (EGD) and alarms. Each controller has an independent, physical connection to the UDH. In the event that the UDH fractures and a controller becomes isolated from its companion controllers, it assumes the role of UDH communicator for that network fragment. While for one cabinet there can be only one designated controller, there may be multiple UDH communicators. The designated controller is always a UDH communicator.
Fault Tolerant EGD When a controller does not receive expected external EGD data from its UDH connection, (for example, due to a severed network) it will request that the data be forwarded across the IONet from another UDH communicator. One or more communicators may supply the data and the requesting controller uses the last data set received. Only the EGD data used in sequencing by the controllers is forwarded in this manner.
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Output Processing The system outputs are the portions of the calculated data that have to be transferred to the external hardware interfaces and then to the various actuators controlling the process. Most of the outputs from the TMR system are voted in the output hardware, but the system can also output individual signals in a simplex manner. Output voting is performed as close to the final control element as possible. Normally, outputs from the TMR system are calculated independently by the three voting controllers and each controller sends the output to its associated I/O hardware (for example, R controller sends to R I/O). The three independent outputs are then combined into a single output by a voting mechanism. Different signal types require different methods of establishing the voted value. The signal outputs from the three controllers fall into three groups: x
Signals exist in only one I/O channel and are driven as single ended nonredundant outputs
x
Signals exist in all three controllers and are sent as output separately to an external voting mechanism
x
Signals exist in all three controllers but are merged into a signal by the output hardware
For normal relay outputs, the three signals feed a voting relay driver, which operates a single relay per signal. For more critical protective signals, the three signals drive three independent relays with the relay contacts connected in the typical six-contact voting configuration. The following figure shows two types of output boards. Terminal Board, Relay Outputs I/O Board Channel R
Voted Relay Driver Coil
I/O Board Channel S
V
Relay Output
I/O Board Channel T
Terminal Board, High Reliability Relay Outputs I/O Board Channel R I/O Board Channel S I/O Board Channel T
Relay KR Coil Driver Relay Driver
KS
Relay Driver
KT
KR KS
KS KT
Relay Output
Coil KT KR Coil
Relay Output Circuits for Protection
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For servo outputs as shown in the following figure, the three independent current signals drive a three-coil servo actuator, which adds them by magnetic flux summation. Failure of a servo driver is sensed and a deactivating relay contact is opened. I/O Boards Servo Driver Channel R
D/A
Output Terminal Board
Coils on Servo Valve
Servo Driver Channel S
D/A
Servo Driver Channel T
D/A
Hydraulic Servo Valve
TMR Circuit to Combine Three Analog Currents into a Single Output
The following figure shows 4-20 mA signals combined through a 2/3 current sharing circuit that allows the three signals to be voted to one. This unique circuit ensures that the total output current is the voted value of the three currents. Failure of a 4-20 mA output is sensed and a deactivating relay contact is opened. I/O Boards 4-20 mA Driver Channel R
D/A
Output Terminal Board
Output Load
4-20 mA Driver Channel S
Current Feedback
D/A
4-20 mA Driver Channel T
D/A
TMR Circuits for Voted 4-20 mA Outputs
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Input Processing All inputs are available to all three controllers but there are several ways that the input data is handled. For those input signals that exist in only one I/O module, the value is used by all three controllers as common input without SIFT-voting as shown in the following figure. Signals that appear in all three I/O channels may be application-voted to create a single input value. The triple inputs either may come from three independent sensors or may be created from a single sensor by hardware fanning at the terminal board. A single input can be brought to the three controllers without any voting as shown in the following figure. This arrangement is used for non-critical, generic I/O, such as monitoring 4-20 mA inputs, contacts, thermocouples, and RTDs. I/O Rack Field Wiring Termin. Bd. I/O Board VCMI
Sensor
Direct Input
Signal Condition
Control Rack IONet
VCMI
Controller
Exchange No Vote
Control System Data Base
Alarm Limit
A
SC
R
S
T Single Input to Three Controllers, Not Voted
One sensor can be fanned to three I/O boards for medium-integrity applications as shown in the following figure. This configuration is used for sensors with mediumto-high reliability. Three such circuits are needed for three sensors. Typical inputs are 4-20 mA inputs, contacts, thermocouples, and RTDs. I/O Rack Field Wiring Termin. Bd. I/O Board VCMI
Sensors
Fanned Input
A
Control Rack IONet
VCMI
Controller
Exchange
Voter
Control System Data Base
SC R
R Voter
Voted (A)
SC S
S Voter
Voted (A)
SC T
T Voter
Voted (A)
Signal Prevote Condition
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Three independent sensors can be brought into the controllers without voting to provide the individual sensor values to the application. Median values can be selected in the controller if required. This configuration, shown in the following figure, is used for special applications only. Control Rack
I/O Rack Field Wiring Termin. Bd. I/O Board VCMI
Sensors
Common Input
IONet VCMI
Signal Condition
No Vote
Alarm Limit
Controller
Control System Data Base
Median Select Block
A
SC R
A B C
MSB R
B
SC S
A B C
MSB S
C
SC T
A B C
MSB T
Median (A,B,C) A B C
Median (A,B,C) A B C
Median (A,B,C) A B C
Three Independent Sensors with Common Input, Not Voted
The following figure shows three sensors, each one fanned and then SIFT-voted. This arrangement provides a high reliability system for current and contact inputs, and temperature sensors. Controller Rack
I/O Rack Field Wiring Termin. Bd. I/O Board VCMI
Sensors
C
Controller
Control System Data Base
SC R
R Voter
Voted "A" Control Voted "B" Block Voted "C"
Same
SC S
S Voter
Voted "A" Control Voted "B" Block Voted "C"
Same
SC T
T Voter
Voted "A" Control Voted "B" Block Voted "C"
A
B
VCMI
Voter
Fanned Input
Signal Prevote Condition Alarm Limit
IONet
Exchange
Three Sensors, Each One Fanned and Voted, for Medium to High Reliability Applications
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Speed inputs to high reliability applications are brought in as dedicated inputs and then SIFT-voted. The following figure shows the configuration. Inputs such as speed control and overspeed are not fanned so there is a complete separation of inputs with no hardware cross-coupling which could propagate a failure. RTDs, thermocouples, contact inputs, and 4-20 mA signals can also be configured this way. Control Rack
I/O Rack Field Wiring Termin. Bd. I/O Board VCMI
Sensors
Dedicated Signal Prevote Input Condition
IONet
VCMI
Controller
Exchange
Voter
Control System Data Base
Alarm Limit
A
SC R
R Voter
Voted (A,B,C)
B
SC S
S Voter
Voted (A,B,C)
C
SC T
T Voter
Voted (A,B,C)
Three Sensors with Dedicated Inputs, Software Voted for High Reliability Applications
State Exchange Voting all of the calculated values in the TMR system is unnecessary and not practical. The actual requirement is to vote the state of the controller database between calculation frames. Calculated values such as timers, counters, and integrators are dependent on the value from the previous calculation frame. Logic signals such as bistable relays, momentary logic with seal-in, cross-linked relay circuits, and feedbacks have a memory retention characteristic. A small section of the database values is voted each frame.
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Median Value Analog Voting The analog signals are converted to floating point format by the I/O interface boards. The voting operation occurs in each of the three controller modules (R, S, and T). Each module receives a copy of the data from the other two channels. For each voted data point, the module has three values including its own. The median value voter selects the middle value of the three as the voter output. This is the most likely of the three values to be closest to the true value. In the following figure shows some examples. The disagreement detector (see the section, Disagreement Detector) checks the signal deviations and sets a diagnostic if they exceed a preconfigured limit, thereby identifying failed input sensors or channels. Median Value Voting Examples Sensor Median Input Selected Value Value
Sensor Inputs
Sensor 1
981
Sensor 2
985
Sensor 3
978
Configured TMR Deviation = 30
Sensor Median Input Selected Value Value
1020
910
981
No TMR Diagnostic
985
Sensor Median Input Selected Value Value
978
985
985
978
978
TMR Diagnostic on Input 1
TMR Diagnostic on Input 1
Median Value Voting Examples with Normal and Bad Inputs
Two Out of Three Logic Voter Each of the controllers has three copies of the data as described above for the analog voter. The logical values are stored in the controller database in a format that requires a byte per logical value. Voting is a simple logic process, which inputs the three values and finds the two values that agree. The logical data has an auxiliary function called forcing which allows the operator to force the logical state to be either true or false and have it remain in that state until unforced. The logical data is packed in the input tables and the state exchange tables to reduce the bandwidth requirements. The input cycle involves receive, vote, unpack, and transfer to the controller database. The transfer to the database must leave the forced values as they are.
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Disagreement Detector A disagreement detector is provided to continuously scan the prevote input data sets and produce an alarm bit if a disagreement is detected between the three values in a voted data set. The comparisons are made between the voted value and each of the three prevote values. The delta for each value is compared with a user programmable limit value. The limit can be set as required to avoid nuisance alarms but give indication that one of the prevote values has moved out of normal range. Each controller is required to compare only its prevote value with the voted value, for example, R compares only the R prevote value with the voted value. Failure of one of the three voted input circuits has no effect on the controlled process since the fault is masked by SIFT. Without a disagreement detector, a failure could go unnoticed until occurrence of a second failure.
Peer I/O In addition to the data from the I/O modules, there is a class of data that comes from other controllers in other cabinets that are connected through a common data network. For the Mark VI controller the common network is the UDH. For integrated systems, this common network provides a data path between multiple turbine controllers and possibly the controls for the generator, the exciter, or the HRSG/boiler. Selected signals from the controller database may be mapped into a page of peer outputs that are broadcast periodically on the UDH to provide external panels a status update. For the TMR system this action is performed by the UDH communicator using the data from its internal voted database. Reception of peer data is handled independently by each controller.
Command Action Commands sent to the TMR control require special processing to ensure that the three voting controllers perform the requested action at the same time. Typically, the commanding device is a PC connected to the UDH and sending messages over a single network so there is no opportunity to vote the commands in each controller. Moreover, commands may be sent from one of several redundant computers at the operator position(s). When any TMR controller receives a command message, it synchronizes the corresponding response of all three controllers by retransmitting the command to its companions across the IONet and queuing it for action at the start of the next frame. By default the HMIs are predisposed to send all commands to the UDH communicator.
Rate of Response The control system can run selected control programs at the rate of 100 times per second, (10 ms frame rate) for simplex systems and 50 times per second (20 ms frame rate) for TMR systems.
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Failure Handling The general operating principle on failures is that corrective or default action takes place in both directions away from the fault. This means that, in the control hierarchy extending from the terminal mounts through I/O boards, backplanes, networks and main CPUs, when a fault occurs, there is a reaction at the I/O processor and also at the main controller if still operating. When faults are detected, health bits are reset in a hierarchical fashion. If a signal goes bad, the health bit is set false at the control module level. If a board goes bad, all signals associated with that board, whether input or output, have the health bits set false. A similar situation exists for the I/O rack. In addition, there are preconfigured default failure values defined for all input and output signals so that normal application code may cope with failures without excessive healthy bit referencing. Healthy bits in TMR systems are voted if the corresponding signal is TMR. Loss of Control Module in Simplex System - If a control module fails in a simplex system, the output boards go to the configured default output state after a timeout. The loss of the controller board propagates down through the IONet so that the output board knows what to do. This is accomplished by shutting down the IONet. Loss of Control Module in TMR System - If a control module fails in a TMR system, the TMR outputs and simplex outputs on that channel timeout to the configured default output state. TMR control continues using the other two control modules. Loss of I/O VCMI in TMR System - If the VCMI in an interface module in a TMR system fails, the outputs timeout to the configured default output state. The inputs are set to the configured default state so that resultant outputs, such as UDH, may be set correctly. Inputs and output healthy bits are reset. A failure of the VCMI in Rack 0 is viewed as equivalent to a failure of the control module itself. Loss of I/O VCMI in Simplex System - If the VCMI in an interface module in a simplex system fails, the outputs and inputs are handled the same as a TMR system. Loss of I/O Board in Simplex System - If an I/O board in a simplex system fails, hardware on the outputs from the I/O boards set the outputs to a low power default value given typical applications. Input boards have the input values set to the preconfigured default value in the Master VCMI board. Loss of Simplex I/O Board in TMR System - If the failed simplex I/O board is in a TMR system, the inputs and outputs are handled as described herein if they were in a simplex system. Loss of TMR I/O Board in TMR System - If a TMR I/O board fails in a TMR system, inputs and outputs are handled. TMR SIFT and hardware output voting keep the process running. Loss of IONet in Simplex System - If the IONet fails in a simplex system, the output boards in the I/O racks timeout and set the preconfigured default output values. The Master VCMI board defaults the inputs so that UDH outputs can be correctly set. Loss of IONet in TMR System - If the IONet fails in a simplex system, outputs follow the same sequence as for a Loss of Control Module in simplex. Inputs follow the same sequence as for Loss of I/O VCMI in TMR.
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Turbine Protection Turbine overspeed protection is available in three levels, control, primary, and emergency. Control protection comes through closed loop speed control using the fuel/steam valves. Primary overspeed protection is provided by the controller. The TTUR terminal board and VTUR I/O board bring in a shaft speed signal to each controller where they are median selected. If the controller determines a trip condition, the controller sends the trip signal to the TRPG terminal board through the VTUR I/O board. The three VTUR outputs are 2/3 voted in three-relay voting circuits (one for each trip solenoid) and power is removed from the solenoids. The following figure shows the primary and emergency levels of protection.
Software Voting High Speed Shaft
R
TTUR Terminal Board
High Speed Shaft S
High Speed Shaft
Controller R & VTUR Controller S & VTUR
T
TRPG Terminal Board Hardware Voting (Relays)
Primary Protection
Controller T & VTUR
Magnetic Speed Pickups (3 used)
Trip Solenoids (Up to three)
TPRO
High Speed Shaft R8
Terminal Board
High Speed Shaft S8
VPRO R8
VPRO S8 High Speed Shaft T8
TREG Terminal Board Hardware Voting (Relays)
Emergency Protection
VPRO T8
Magnetic Speed Pickups (3 used)
Trip Signal to Servo Terminal Board TSVO Primary and Emergency Overspeed Protection
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Emergency overspeed protection is provided by the independent triple redundant VPRO protection system. This uses three shaft speed signals from magnetic pickups, one for each protection module. These are brought into TPRO, a terminal board dedicated to the protection system. Either the controllers or the protection system can independently trip the turbine. Each VPRO independently determines when to trip, and the signals are passed to the TREG terminal board. TREG operates in a similar way to TRPG, voting the three trip signals in relay circuits and removing power from the trip solenoids. This system contains no software voting, making the three VPRO modules completely independent. The only link between VPRO and the other parts of the control system is the IONet cable, which transmits status information. Additional protection for simplex systems is provided by the protection module through the Servo Terminal Board, TSVO. Plug J1 on TREG is wired to plug JD1 on TSVO, and if this is energized, relay K1 disconnects the servo output current and applies a bias to force the control valve closed.
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Reliability and Availability System reliability and availability can be calculated using the component failure rates. These numbers are important for deciding when to use simplex circuits versus TMR circuits. TMR systems have the advantage of online repair discussed in the section, Online Repair for TMR Systems.
Online Repair for TMR Systems The high availability of the TMR system is a result of being able to do repair online. It is possible to shut down single modules for repair and leave the voting trio in full voting mode operation, which effectively masks the absence of the signals from the powered down module. However, there are some restrictions and special cases that require extra attention. Many signals are reduced to a single customer wire at the terminal boards so removal of the terminal board requires that the wires be disconnected momentarily. Each type of terminal board must be evaluated for the application and the signal type involved. Voltages in excess of 50 V are present in some customer wiring. Terminal boards that have only signals from one controller channel may be replaced at any time if the faulty signals are being masked by the voter. For other terminal boards such as the relay outputs, the individual relays may be replaced without disconnecting the terminal board. For those singular signals that are driven from only one I/O board, there is no redundancy or masking. These are typically used for non-critical functions such as pump drives, where loss of the control output simply causes the pump to run continuously. Application designers must avoid using such singular signals in critical circuits. The TMR system is designed such that any of the three controllers may send outputs to the singular signals, keeping the function operational even if the normal sending controller fails. Note Before performing an online repair, power down only the module (rack) that has the fault. Failure to observe this rule may cause an unexpected shutdown of the process (each module has its own power disconnect or switch). The modules are labeled such that the diagnostic messages identify the faulty module. Repair the faulty modules as soon as possible. Although the TMR system will survive certain multiple faults without a forced outage, a lurking fault problem may exist after the first unrepaired failure occurs. Multiple faults within the same module cause no concern for online repair since all faults will be masked by the other voters. However, once a second unrelated fault occurs in the same module set, then either of the faulty modules of the set that is powered down will introduce a dual fault in the same three signal set which may cause a process shutdown.
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Reliability Reliability is represented by the Mean Time Between Forced Outage (MTBFO) of the control system. The MTBFO is a function of which boards are being used to control and protect the turbine. The complete system MTBFO depends on the size of the system, number of simplex boards, and the amount of sensor triplication. In a simplex system, failure of the controller or I/O communication may cause a forced outage. Failure of a critical I/O module will cause a forced outage, but there are non-critical I/O modules, which can fail and be changed out without a shutdown. The MTBFO is calculated using published failure rates for components. Availability is the percentage of time the system is operating, taking into account the time to repair a failure. Availability is calculated as follows: MTBFO x 100% ----------------------MTBFO + MTTR where: MTTR is the Mean Time To Repair the system failure causing the forced outage. With a TMR system there can be failures without a forced outage because the system can be repaired while it continues to run. The MTBFO calculation is complex since essentially it is calculating the probability of a second (critical) failure in another channel during the time the first failure is being repaired. The time to repair is an important input to the calculation. The availability of a well-designed TMR system with timely online repair is effectively 100%. Possible forced outages may still occur if a second failure of a critical circuit comes before the repair can be completed. Other possible forced outages may occur if the repairman erroneously powers down the wrong module. Note To avoid possible forced outages from powering down the wrong module, check the diagnostics for identification of the modules which contain the failure. System reliability has been determined by calculating the Failures In Time (FIT) (failures per 109 hours) based on the Bellcore TR-332 Reliability Prediction Procedure for Electronic Equipment. The Mean Time Between Failures (MTBF) can be calculated from the FIT.
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Third Party Connectivity The Mark VI can be linked to the plant Distributed Control System (DCS) in three different ways as follows. x
Modbus link from the HMI Server RS-232C port to the DCS
x
A high speed 10 Mbaud Ethernet link using the Modbus over TCP/IP protocol
x
A high speed 10 Mbaud Ethernet link using the TCP/IP protocol with an application layer called GEDS Standard Messages (GSM)
The Mark VI can be operated from the plant control room. GSM supports turbine control commands, Mark VI data and alarms, the alarm silence function, logical events, and contact input sequence of events records with 1 ms resolution. The following figure shows the three options. Modbus is widely used to link to DCSs, but Ethernet GSM has the advantage of speed, distance, and functionality. To DCS
To DCS Serial Modbus
Ethernet Modbus
To DCS Ethernet GSM
UCVx Controller x
PLANT DATA HIGHWAY
HMI Server Node L A N
To Plant Data Highway (PDH) Ethernet
Ethernet UCVE
x
Ethernet UNIT DATA HIGHWAY
Optional Communication Links to Third-Party Distributed Control System
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CHAPTER 3
Chapter 3 Networks Network Overview ..................................................................... 3-1 Data Highways ........................................................................... 3-4 IONet.......................................................................................... 3-9 Ethernet Global Data (EGD) ...................................................... 3-12 Modbus Communications........................................................... 3-14 Ethernet Modbus Slave............................................................... 3-15 Serial Modbus Slave................................................................... 3-17 Ethernet GSM............................................................................. 3-22 PROFIBUS Communications..................................................... 3-24 Fiber-Optic Cables...................................................................... 3-27 Time Synchronization ................................................................ 3-32
Introduction This chapter defines the various communication networks in the control system. These networks provide communication with the operator interfaces, servers, controllers, and I/O. It also provides information on fiber-optic cables, including components and guidelines.
Network Overview The Mark VI system is based on a hierarchy of networks used to interconnect the individual nodes. These networks separate the different communication traffic into layers according to their individual functions. This hierarchy extends from the I/O and controllers, which provide real-time control of the turbine and its associated equipment, through the operator interface systems, and up to facility wide monitoring or distributed control systems (DCS). Each layer uses standard components and protocols to simplify integration between different platforms and improve overall reliability and maintenance. The layers are designated as the Enterprise, Supervisory, Control, and I/O. Note Ethernet is used for all Mark VI data highways and the I/O network.
Enterprise Layer The Enterprise layer serves as an interface from specific process control into a facility wide or group control layer. These higher layers are provided by the customer. The network technology used in this layer is generally determined by the customer and may include either Local Area Network (LAN) or Wide Area Network (WAN) technologies, depending on the size of the facility. The Enterprise layer is generally separated from other control layers through a router, which isolates the traffic on both sides of the interface. Where unit control equipment is required to communicate with a facility wide or DCS system, GE uses either a Modbus interface or a TCP/IP protocol known as GE Standard Messaging (GSM).
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Supervisory Layer The Supervisory layer provides operator interface capabilities such as to coordinate HMI viewer and server nodes, and other functions like data collection (Historian), remote monitoring, and vibration analysis. This layer may be used as a single or dual network configuration. A dual network provides redundant Ethernet switches and cables to prevent complete network failure if a single component fails. The network is known as the Plant Data Highway (PDH).
To Optional Customer Network
HMI Viewer
Enterprise Layer
Router
HMI Viewer
HMI Viewer
Field Support
Supervisory Layer
PLANT DATA H IGHWAY P LANT DATA H IGHWAY
HMI Servers
Control Layer U NIT
D ATA
H IGHWAY
U NIT DATA H IGHWAY Steam Turbine Control
Gas Turbine Control TMR
Mark VI
Mark VI
Mark VI
Generator Protection
Exciter
BOP
Gen. Protect
90-70 PLC
EXCITER
Mark VI
IONet
I/O Boards
Genius Bus
IONet
I/O Boards
I/O Boards
Mark VI Control as Part of Integrated Control System
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Control Layer The control layer provides continuous operation of the process equipment. The controllers on this layer are highly coordinated to support continuous operation without interruption. The controllers operate at a fundamental rate called the frame rate, which can be between 6-100 Hz. These controllers use Ethernet Global Data (EGD) to exchange data between nodes. Various levels of redundancy for the connected equipment are supported by the supervisory and control layers. Printer Printer Type 1 Redundancy Non-critical nodes such as printers can be connected without using additional communication devices. Network Switch B Network Switch A
Type 2 Redundancy Nodes that are only available in Simplex configuration can be connected with a redundant switch. The switch automatically senses a failed network component and fails-over to a secondary link.
Redundant Switch Network Switch B Network Switch A
Controller
Controller
Network Switch B Network Switch A
Dual
Type 3 Redundancy Nodes such as dual or TMR controllers are tightly coupled so that each node can send the same information. By connecting each controller to alternate networks, data is still available if a controller or network fails.
Network Switch B Network Switch A
TMR
Network Switch B
Type 4 Redundancy This type provides redundant controllers and redundant network links for reliability. This is useful if the active controller network interface cannot sense a failed network condition.
Network Switch A
Redundant Networks for Different Applications
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Data Highways Plant Data Highway (PDH) The PDH is the plant level supervisory network. The PDH connects the HMI Server with remote viewers, printers, historians, and external interfaces. There is no direct connection to the Mark VI controllers, which communicate over the UDH. Use of Ethernet with the TCP/IP protocol over the PDH provides an open system for thirdparty interfaces. The following figure shows the equipment connections to the PDH. Fiber-optic cable provides the best signal quality, completely free of electromagnetic interference (EMI) and radio frequency interference (RFI). Large point-to-point distances are possible, and since the cable does not carry electrical charges, ground potential problems are eliminated. GT #1 PEECC 220VAC UPS
ENET 0/1
ENET 0/0
GT #2 PEECC
GT #3 PEECC
CONSOLE AUX
SW1
SW5
SW9 PDH
PDH
PDH
UDH
UDH
UDH
ADH
ADH
ADH
CROSSOVER UTP
220VAC UPS SW6
SW2
TRUNK
CROSSOVER UTP
TRUNK
CROSSOVER UTP
TRUNK
220VAC UPS
220VAC UPS SW10 PDH
PDH
PDH
UDH
UDH
UDH
ADH
ADH
ADH
TRUNK
TRUNK
TRUNK
21 A B
A
A B
A B
NIC1
NIC1 NIC2
M
M
GT1_SVR PC Desk 18in. Desktop LCD(dual) Mouse
A B
A B
NIC1 NIC2
M uOSM SEE NOTE 6 PEECC Rack - uOSM
A B
NIC1 NIC2
M
M
GT2_SVR PC Desk 18in. Desktop LCD(dual) Mouse
M
GT3_SVR PC Desk 18in. Desktop LCD(dual) Mouse
UPS BY GE
220VAC UPS
220VAC
220VAC UPS
220VAC UPS
9
10
11
12
13
PDH
14
15
16
17
18
UDH
19
20
PDH
UDH
ADH
TRUNK
SW16
TRUNK
220VAC UPS
ADH
SW15
UDH
SW14
PDH
GSM 1
220VAC UPS
SW13
Customer Control Room 9
4
12
13
PDH
14
15
16
17
18
19
20
UDH
GSM 1 A B
A B
NIC1 NIC2
M
11
GSM 2 GSM 3
GSM 2 GSM 3
A B
10
M
M
CRM1_SVR 18in. Desktop LCD(dual) Mouse
220VAC UPS
A B
A B
NIC1 NIC2
CRM2_SVR 18in. Desktop LCD(dual) Mouse
220VAC UPS
A B
NIC1 NIC2
M
M
M
CRM3_SVR 18in. Desktop LCD(dual) Mouse
220VAC UPS
Typical Plant Data Highway Layout Drawing
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PDH Network Features
Feature
Description
Type of Network
Ethernet CSMA/CD in a single or redundant star configuration
Speed
100 Mb/s, Full Duplex
Media and Distance
Ethernet 100BaseTX for switch to controller/device connections. The cable is 22 to 26 AWG with unshielded twisted-pair, category 5e EIA/TIA 568 A/B. Distance is up to 100 meters. Ethernet 100BaseFX with fiber-optic cable for distances up to 2 km (1.24 miles).
Number of Nodes
Up to 1024 nodes supported
Protocols
Ethernet compatible protocol, typically TCP/IP based. Use GE Standard Messaging (GSM) or Modbus over Ethernet for external communications.
Message Integrity
32-bit Cyclic Redundancy Code (CRC) appended to each Ethernet packet plus additional checks in protocol used.
External Interfaces
Various third-party interfaces are available, GSM and Modbus are the most common.
Unit Data Highway (UDH) The UDH is an Ethernet-based network that provides direct or broadcast peer-to-peer communications between controllers and an operator/maintenance interface. It uses Ethernet Global Data (EGD) which is a message-based protocol for sharing information with multiple nodes based on UDP/IP. UDH network hardware is similar to the PDH hardware. The following figure shows redundant UDH networks with connections to the controllers and HMI servers. GT #1 PEECC
GT #1 - A192
Mark VI T
S
R
M1
SW1
M2
GT #2 PEECC T
TRANSCEIVER
SW3
S
R
M1
SW5
T
TRANSCEIVER
A
S
R
SW9
B
B 220VAC UPS
TRU NK
CROSSOVER UTP
220VAC UPS SW12 PDH
PDH U DH
UDH ADH
ADH ADH
AD H
ADH
ADH
A B
TRUNK
TRU NK
TRUNK
TRUNK
TRUNK
TRU NK
A B
A B
NIC1 NIC2
M
M
GT2_SVR PC Desk 18in. Desktop LCD(dual) Mouse
220VAC UPS
TRUNK
SW10
U DH
U DH
U DH
UDH
GT1_SVR PC Desk 18in. Desktop LCD(dual) Mouse
220VAC UPS
PDH
PDH
PDH
PDH
A B
A
ADH
TRU NK
CROSSOVER UTP
TRUNK
SW8
NIC1 NIC2
M
TRANSCEIVER
ADH
ADH
ADH
TRU NK
CROSSOVER UTP
TRUNK
A B
NIC1 NIC2
LCI SW11
UD H
220VAC UPS
220VAC UPS
SW6
M
M2
UDH
UDH
ADH
ADH
220VAC UPS
SW4
M1
PDH
UD H
UD H
UDH
A B
SW7
EX2100
PDH
PDH
220VAC UPS
220VAC UPS
220VAC UPS SW2
M
M2
GT #3 - A192
Mark VI
PDH
B
GT #3 PEECC
LCI
EX2100 PDH
PDH
A
GT #2 - A192
Mark VI
LCI
EX2100
M
GT3_SVR PC Desk 18in. Desktop LCD(dual) Mouse
220VAC UPS
220VAC UPS
A B
A B
220VAC UPS
11
12
13
14
15
16
PDH
17
18
19
20
UD H
PDH
U DH
AD H
TRUNK
A B
A B
NIC1 NIC2
M
M
CRM1_SVR 18in. Desktop LCD(dual) Mouse
10
A B
NIC1 NIC2
M
9
220VAC UPS
9
10
11
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13
PDH
14
15
16
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UD H
A B
NIC1 NIC2
M
M
CRM2_SVR 18in. Desktop LCD(dual) Mouse
SW16
TR UNK
220VAC UPS
ADH
SW15
UD H
SW14
PDH
220VAC UPS
SW13
Customer Control Room
M
UNIT DATA HIGHWAY (UDH)
CRM3_SVR 18in. Desktop LCD(dual) Mouse
220VAC UPS
Typical Unit Data Highway Layout Drawing
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Chapter 3 Networks x 3-5
UDH Network Features
Feature
Description
Type of Network
Ethernet , full duplex, in a single or redundant star configuration
Media and Distance
Ethernet 100BaseTX for switch to controller/device connections. The cable is 22 to 26 AWG unshielded twisted pair; category 5e EIA/TIA 568 A/B. Distance is up to 100 meters. Ethernet 100BaseFX with fiber-optic cable optional for distances up to 2 km (1.24 miles).
Number of Nodes
At least 25 nodes, given a 25 Hz data rate. For other configurations contact the factory.
Type of Nodes Supported
Controllers, PLCs, operator interfaces, and engineering workstations
Protocol
EGD protocol based on the UDP/IP
Message Integrity
32-bit CRC appended to each Ethernet packet plus integrity checks built into UDP and EGD
Time Sync. Methods
Network Time Protocol (NTP), accuracy ±1 ms.
Data Highway Ethernet Switches The UDH and PDH networks use Fast Ethernet switches. The system modules are cabled into the switches to create a star type network architecture. Redundancy is obtained by using two switches with an interconnecting cable. Redundant switches provide redundant, duplex communication links to controllers and HMIs. Primary and secondary designate the two redundant Ethernet links. If the primary link fails, the converter automatically switches the traffic on main over to the secondary link without interruption to network operation. At 10 Mb/s, using the minimum data packet size, the maximum data loss during fail-over transition is 2-3 packets. Note Switches are configured by GE for the control system, pre configured switches should be purchased from GE. Each switch is configured to accept UDH and PDH. GE Part # 323A4747NZP31(A,B or C)
Configuration
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A
B Single VLAN May me used for UDH or PDH
C
PDH
1-8
UDH
9-16
1-18,23-26
ADH
17-19
19-21
Uplinks
20-26
22 to Router
None
GEH-6421H Mark VI Control System Guide Volume I
Configuration 323A4747NZP31A is the standard configuration with 323A4747NZP31B being used for legacy systems with separate UDH and PDH networks. Part 323A4747NZP31C is obsolete and was used in special instances to provide connectivity between the PDH and the OSM system. GE Part # 323A4747NZP37(A or B)
Configuration
A
PDH
1-3
UDH
5-7
ADH
None
Uplinks
4,8,9-16
B Single VLAN May me used for UDH or PDH
Virtual LAN (VLAN) technology is used in the UDH and PDH infrastructure to provide separate and redundant network infrastructure using the same hardware. The multi-VLAN configuration (Configuration A) provides connectivity to both PDH and UDH networks. Supplying multiple switches at each location provides redundancy. The switch fabric provides separation of the data. Each uplink between switches carries each VLANs data encapsulated per IEEE 802.1q. The UDH VLAN data is given priority over the other VLANs by increasing its 802.1p priority.
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Selecting IP Addresses for UDH and PDH Use the following table to select IP addresses on the UDH and PDH. The standard IP address is 192.168.ABC.XYZ. Ethernet IP Address Rules
Network Type UDH
A
BC
Type
Network Number
1
01-99
X Controller/Device Number 1 = gas turbine controllers 2 = steam turbine controllers
Y Unit Number 1 = Unit 1 2 = Unit 2 • • 9 = Unit 9
Z Type of Device 1 = R0 2 = S0 3 = T0 4 = HRSG A 5 = HRSG B 6 = EX2000 or EX2100 A 7 = EX2000 or EX2100 B 8 = EX2000 or EX2100 C 9 = Not assigned 0 = Static Starter
0 = All other devices on the UDH
02 - 15 = Servers 16 - 25 = Workstations 26 - 37 = Other stations (Viewers) 38
= Turbine Historian
39
= OSM
40 - 99 = Aux Controllers, such as ISCs PDH
2
01 – 54
2 to 199 are reserved for customer supplied items 200 to 254 are reserved for GE supplied items such as viewers and printers
The following are examples of IP addresses: 192.168.104.133 would be UDH number 4, gas turbine unit number 3, T0 core. 192.168.102.215 would be UDH number 2, steam turbine unit number 1, HRSG B. 192.168.201.201 could be a CIMPLICITY Viewer supplied by GE, residing on PDH#1. 192.168.205.10 could be a customer-supplied printer residing on PDH#5. Note Each item on the network such as a controller, server, or viewer must have an IP address. The above addresses are recommended, but if this is a custom configuration, the requisition takes precedence.
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IONet IONet is an Ethernet 10Base2 network used to communicate data between the VCMI communication board in the control module, the I/O boards, and the three independent sections of the Protection Module . In large systems, it is used to communicate with an expansion VME board rack containing additional I/O boards. These racks are called interface modules since they contain exclusively I/O boards and a VCMI. IONet also communicates data between controllers in TMR systems. Note Remote I/O can be located up to 185 m (607 ft) from the controller. Another application is to use the interface module as a remote I/O interface located at the turbine or generator. The following figure shows a TMR configuration using remote I/O and a protection module. TMR System with Remote I/O Racks
R0 V C M I
S0
U C V X
V C M I
T0
U C V X
V C M I
R8 V P R O
U C V X
S8 V P R O
T8 V P R O
IONet - R IONet - S IONet - T
R1
IONet Supports Multiple Remote I/O Racks
V C M I
I/O Boards
S1 V C M I
I/O Boards
T1 V C M I
I/O Boards
UCVX is Controller, VCMI is Bus Master, VPRO is Protection Module, I/O are VME boards. (Terminal Boards not shown)
IONet Communications with Controllers, I/O, and Protection Modules
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Chapter 3 Networks x 3-9
IONet Features
IONet Feature
Description
Type of Network
Ethernet using extension of ADL protocol
Speed
10 Mb/s data rate
Media and Distance
Ethernet 10Base2, RG-58 coax cable is standard Distance to 185 m (607 ft) Ethernet 10BaseFL with fiber-optic cable and converters Distance is 2 km (1.24 miles)
Number of Nodes
16 nodes
Protocol
Extension of ADL protocol designed to avoid message collisions; Collision Sense (CSMA) functionality is still maintained
Message Size
Maximum packet size 1500 bytes
Message Integrity
32-bit CRC appended to each Ethernet packet
IONet - Communications Interface Communication between the control module (control rack) and interface module (I/O rack) is handled by the VCMI in each rack. In the control module, the VCMI operates as the IONet Master, while in the interface module it operates as an IONet slave. The VCMI establishes the network ID, and displays the network ID, channel ID, and status on its front cabinet LEDs. The VCMI serves as the Master frame counter for all nodes on the IONet. Frames are sequentially numbered and all nodes on IONet run in the same frame This ensures that selected data is being transmitted and operated on correctly.
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I/O Data Collection I/O Data Collection, Simplex Systems - When used in an interface module, the VCMI acts as the VME bus Master. It collects input data from the I/O boards and transmits it to the control module through IONet. When it receives output data from the control module it distributes it to the I/O boards. The VCMI in slot 1 of the control module operates as the IONet Master. As packets of input data are received from various racks on the IONet, the VCMI collects them and transfers the data through the VME bus to the I/O table in the controller. After application code completion, the VCMI transfers output values from the controller I/O table to the VCMI where the data is then broadcast to all the I/O racks. I/O Data Collection and Voting, TMR Systems - For a small TMR system, all the I/O may be in one module (triplicated). In this case the VCMI transfers the input values from each of the I/O boards through the VME bus to an internal buffer. After the individual board transfers are complete, the entire block of data is transferred to the pre-vote table, and also sent as an input packet on the IONet. As the packet is being sent, corresponding packets from the other two control modules are being received through the other IONet ports. Each of these packets is then transferred to the pre-vote table. After all packets are in the pre-vote table, the voting takes place. Analog data (floating point) goes through a median selector, while logical data (bit values) goes through a two-out-of-three majority voter. The results are placed in the voted table. A selected portion of the controller variables (the states such as counter/timer values and sequence steps) must be transferred by the Master VCMI boards to the other Master VCMI boards to be included in the vote process. At completion of the voting the voted table is transferred through the VME bus to the state table memory in the controller. For a larger TMR system with remote I/O racks, the procedure is very similar except that packets of input values come into the Master VCMI over IONet. After all the input data is accumulated in the internal buffer, it is placed in the pre-vote table and also sent to the other control modules over IONet. After all the packets and states are in the pre-vote table, they are voted, and the results are transferred to the controller. Output Data Packet - All the output data from a control module VCMI is placed in packets. These packets are then broadcast on the IONet and received by all connected interface and control modules. Each interface module VCMI extracts the required information and distributes to its associated I/O boards.
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Ethernet Global Data (EGD) EGD allows you to share information between controller components in a networked environment. Controller data configured for transmission over EGD are separated into groups called exchanges. Multiple exchanges make up pages. Pages can be configured to either a specific address (unicast) if supported or to multiple consumers at the same time (broadcast or multicast, if supported). Each page is identified by the combination of a Producer ID and an Exchange ID so the consumer recognizes the data and knows where to store it. EGD allows one controller component, referred to as the producer of the data, to simultaneously send information at a fixed periodic rate to any number of peer controller components, known as the consumers. This network supports a large number of controller components capable of both producing and consuming information. The exchange contains a configuration signature, which shows the revision number of the exchange configuration. If the consumer receives data with an unknown configuration signature then it makes the data unhealthy. In the case of a transmission interruption, the receiver waits three periods for the EGD message, after which it times out and the data is considered unhealthy. Data integrity is preserved by: x
32-bit cyclic redundancy code (CRC) in the Ethernet packet
x
Standard checksums in the UDP and IP headers
x
Configuration signature
x
Data size field EGD Communications Features
Feature
Description
Type of Communication Message Type
Supervisory data is transmitted either 480 or 960 ms. Control data is transmitted at frame rate. Broadcast - a message to all stations on a subnet Unicast - a directed message to one station Pages may be broadcast onto multiple Ethernet subnets or may be received from multiple Ethernet subnets, if the specified controller hardware supports multiple Ethernet ports. In TMR configurations, a controller can forward EGD data across the IONet to another controller that has been isolated from the Ethernet. AN exchange can be a maximum of 1400 bytes. Pages can contain multiple exchanges. The number of exchanges within a page and the number of pages within an EGD node are limited by each EGD device type. The Mark VI does not limit the number or exchanges or pages. Ethernet supports a 32-bit CRC appended to each Ethernet packet. Reception timeout (determined by EGD device type. The exchange times out after an exchange update had not occurred within four times the exchange period.), Using Sequence ID. Missing/out of order packet detection UDP and IP header checksums Configuration signature (data layout revision control) Exchange size validation EGD allows each controller to send a block of information to, or receive a block from, other controllers in the system. Integer, Floating Point, and Boolean data types are supported.
Redundancy
Fault Tolerance Sizes
Message Integrity
Function Codes
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In a TMR configuration, each controller receives UDH EGD data independently from a direct Ethernet connection. If the connection is broken a controller may request the missing data from the second or third controller through the IONet. One controller in a TMR configuration is automatically selected to transmit the EGD data onto the UDH. If the UDH fractures causing the controllers to be isolated from each other onto different physical network segments, multiple controllers are enabled for transmission, providing data to each of the segments. These features add a level of Ethernet fault tolerance to the basic protocol.
EGD
IONET
IONET
IONET
EGD
UNIT DATA HIGHWAY
Redundant path for UDH EGD
EGD
Unit Data Highway EGD TMR Configuration
In a DUAL configuration, each controller receives UDH EGD data independently from a direct Ethernet connection. If the connection is broken a controller may request the missing data from the second through the IONet. One controller in a DUAL configuration is automatically selected to transmit the EGD data onto the UDH. If the UDH fractures causing the controllers to be isolated from each other onto different physical network segments, each controller is enabled for transmission, providing data to both segments.
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Modbus Communications The Mark VI control platform can be a Modbus Slave on either the COM2 RS-232C serial connection or over Ethernet. In the TMR configuration, commands are replicated to multiple controllers so only one physical Modbus link is required. All the same functions are supported over Ethernet that are supported over the serial ports. All Ethernet Modbus messages are received on Ethernet port 502. Note The Modbus support is available in either the simplex or TMR configurations. Messages are transmitted and received using the Modbus RTU transmission mode where data is transmitted in 8-bit bytes. The other Modbus transmission mode where characters are transmitted in ASCII is not supported. The supported Modbus point data types are bits, shorts, longs and floats. These points can be scaled and placed into compatible Mark VI signal types. There are four Modbus register page types used: x
Input coils
x
Output coils
x
Input registers
x
Holding registers
Since the Mark VI has high priority control code operating at a fixed frame rate, it is necessary to limit the amount of CPU resources that can be taken by the Modbus interface. To limit the operation time, a limit on the number of commands per second received by the Mark VI is enforced. The Mark VI control code also can disable all Modbus commands by setting an internal logical signal. There are two diagnostic utilities that can be used to diagnose problems with the Modbus communications on a Mark VI. The first utility prints out the accumulated Modbus errors from a network and the second prints out a log of the most recent Modbus messages. This data can be viewed using the toolbox. Note For additional information on Mark VI Modbus communications, refer to the sections Ethernet Modbus Slave and Serial Modbus Slave and to document, GEI100535, Modbus Communications.
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Ethernet Modbus Slave Modbus is widely used in control systems to establish communication between distributed control systems, PLCs, and HMIs. The Mark VI controller supports Ethernet Modbus as a standard slave interface. Ethernet establishes high-speed communication between the various portions of the control system, and the Ethernet Modbus protocol is layered on top of the TCP/IP stream sockets. The primary purpose of this interface is to allow third party Modbus Master computers to read and write signals that exist in the controller, using a subset of the Modbus function codes. The Mark VI controller will respond to Ethernet Modbus commands received from any of the Ethernet ports supported by its hardware configuration. Ethernet Modbus may be configured as an independent interface or may share a register map with a serial Modbus interface. UNIT DATA HIGHWAY
Ethernet Modbus
Ethernet Modbus
Mark VI
90-70 PLC
ENET2
ENET1
CPU
I/ O
I/ O
I/ O
UCVx
VC MI
ENET1
ENET2
Simplex RS-232C
Serial Modbus Ethernet Modbus
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Chapter 3 Networks x 3-15
Ethernet Modbus Features
Feature
Description
Communication Type
Multidrop Ethernet CSMA/CD, employing TCP/IP with Modbus Application Protocol (MBAP) layered on top. Slave protocol only
Speed
10 Mb/s data rate
Media and Distance
Using 10Base2 RG-58 coax, the maximum distance is 185 m (607 ft). Using 10BaseT shielded twisted-pair, with media access converter, the maximum distance is 100 m (328 ft) Using 10BaseFL fiber-optics, with media access converter, a distance of several kilometers is possible Only the coax cable can be multidropped; the other cable types use a hub forming a Star network.
Message Integrity
Ethernet supports a 32-bit CRC appended to each Ethernet packet.
Redundancy
Responds to Modbus commands from any Ethernet interface supported by the controller hardware Supports register map sharing with serial Modbus
Function Codes 01 Read Coil
Read the current status of a group of 1 to 2000 Boolean signals
02 Read Input
Read the current status of a group of 1 to 2000 Boolean signals
03 Read Registers
Read the current binary value in 1 to 125 holding registers
04 Read Input Registers
Read the current binary values in 1 to125 analog signal registers
05 Force Coil
Force a single Boolean signal to a state of ON or OFF
06 Preset Register
Set a specific binary value into holding registers
07 Read Exception
Read the first 8 logic coils (coils 1-8) - short message length permits rapid reading
15 Force Coils
Force a series of 1 to 800 consecutive Boolean signals to a specific state
16 Preset Registers
Set binary values into a series of 1 to 100 consecutive holding registers
Status
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Serial Modbus Slave Serial Modbus is used to communicate between the Mark VI and the plant Distributed Control System (DCS). This is shown as the Enterprise layer in the introduction to this chapter. The serial Modbus communication link allows an operator at a remote location to make an operator command by sending a logical command or an analog setpoint to the Mark VI. Logical commands are used to initiate automatic sequences in the controller. Analog setpoints are used to set a target such as turbine load, and initiate a ramp to the target value at a predetermined ramp rate. Note The Mark VI controller also supports serial Modbus slave as a standard interface. The HMI Server supports serial Modbus as a standard interface. The DCS sends a request for status information to the HMI, or the message can be a command to the turbine control. The HMI is always a slave responding to requests from the serial Modbus Master, and there can only be one Master. Serial Modbus Features
Serial Modbus Feature Type of Communication
Description Master/slave arrangement with the slave controller following the Master; full duplex, asynchronous communication
Speed
19,200 baud is standard; 9,600 baud is optional
Media and Distance
Using an RS-232C cable without a modem, the distance is 15.24 m (50 ft); using an RS-485 converter it is 1.93 km (1.2 miles).
Mode
ASCII Mode - Each 8-bit byte in the message is sent as two ASCII characters, the hexadecimal representation of the byte. (Not available from the HMI server.) Remote Terminal Unit (RTU) Mode - Each 8-bit byte in the message is sent with no translation, which packs the data more efficiently than the ASCII mode, providing about twice the throughput at the same baud rate.
Redundancy
Supports register map sharing with Ethernet Modbus.
Message Security
An optional parity check is done on each byte and a CRC16 check sum is appended to the message in the RTU mode; in the ASCII mode an LRC is appended to the message instead of the CRC.
Note This section discusses serial Modbus communication in general terms. Refer to GEH-6410, Innovation Series Controller System Manual and HMI manuals for additional information. Refer to GEH-6126, HMI Application Guide and GFK-1180, CIMPLICITY HMI for Windows NT and Windows 95 User's Manual. For details on how to configure the graphic screens refer to GFK-1396, CIMPLICITY HMI for Windows NT and Windows 95 CimEdit Operation Manual.
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Modbus Configuration Systems are configured as single point-to-point RS-232C communication devices. A GE device on Serial Modbus is a slave supporting binary RTU (Remote Terminal Unit) full duplex messages with CRC. Both dedicated and broadcast messages are supported. A dedicated message is a message addressed to a specific slave device with a corresponding response from that slave. A broadcast message is addressed to all slaves without a corresponding return response. The binary RTU message mode uses an 8-bit binary character data for messages. RTU mode defines how information is packed into the message fields by the sender and decoded by the receiver. Each RTU message is transmitted in a continuous stream with a 2-byte CRC checksum and contains a slave address. A slave station’s address is a fixed unique value in the range of 1 to 255. The Serial Modbus communications system supports 9600 and 19,200 baud, none, even, or odd parity, and 7 or 8 data bits. Both the Master and slave devices must be configured with the same baud rate, parity, and data bit count. Modbus Function Codes
Function Codes
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Title
Message Description
01
01 Read Holding Coils
Read the current status of a group of 1 to 2000 Boolean signals
02
02 Read Input Coils
Read the current status of a group of 1 to 2000 Boolean signals
03
03 Read Holding Registers
Read the current binary values in 1 to 125 analog signal registers
04
04 Read Input Registers
Read the current binary values in 1 to125 analog signal registers
05
05 Force Single Holding Coil
Force (or write) a single Boolean signal to a state of ON or OFF
06
06 Preset Single Holding Register
Preset (or write) a specific binary value into a holding register
07
07 Read Exception Status
Read the first 8 logic coils (coils 1-8) - short message length permits rapid reading of these values
08
08 Loopback Test
Loopback diagnostic to test communication system
15
15 Force Multiple Coils
Force a series of 1 to 800 consecutive Boolean signals to a specific state
16
16 Preset Multiple Holding Registers
Set binary values into a series of 1 to 100 consecutive analog signals
GEH-6421H Mark VI Control System Guide Volume I
Hardware Configuration A Data Terminal Equipment Device (DTD) transmits serial data on pin 3 (TD) of a 9-pin RS-232C cable. A Data Communication Device (DCE) is identified as a device that transmits serial data on pin 2 (RD) of a 9-pin RS-232C cable. Refer to the following table. Using this definition, the GE slave Serial Modbus device is DTD because it transmits serial data on pin 3 (TD) of the 9-pin RS-232C cable. If the master serial Modbus device is also a DTD, connecting the master and slave devices together requires an RS-232C null modem cable. The RS-232C standard specifies 25 signal lines: 20 lines for routine operation, two lines for modem testing, and three remaining lines unassigned. Nine of the signal pins are used in a nominal RS-232C communication system. Cable references in this document will refer to the 9-pin cable definition found in the following table. Terms describing the various signals used in sending or receiving data are expressed from the point of view of the DTE. For example the signal, transmit data (TD), represents the transmission of data coming from the DTD going to the DCE. Each RS-232C signal uses a single wire. The standard specifies the conventions used to send sequential data as a sequence of voltage changes signifying the state of each signal. Depending on the signal group, a negative voltage (less than -3 V) represents either a binary 1 data bit, a signal mark, or a control off condition, while a positive voltage (greater that +3 V) represents either a binary zero data bit, a signal space, or a control on condition. Because of voltage limitations, an RS-232C cable may not be longer than 15.2 m (50 ft). Nine of the twenty-five RS-232C pins are used in a common asynchronous application. All nine pins are necessary in a system configured for hardware handshaking. The Modbus system does not use hardware handshaking; therefore it requires just three wires, receive data (RD), transmit data (TD), and signal ground (GND) to transmit and receive data. The nine RS-232C signals used in the asynchronous communication system can be broken down into four groups of signals: data, control, timing, ground.
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RS-232C Connector Pinout Definition
DB 9 DB 25
Description
DTE DTE Output Input
Signal Type
Function
1
8
Data Carrier Detect (DCD)
X
Contro l
Signal comes from the other RS-232C device telling the DTE device that a circuit has been established
2
3
Receive Data (RD)
X
Data
Receiving serial data
3
2
Transmit Data (TD)
X
Data
Transmitting serial data
4
20
Data Terminal Ready (DTR)
X
Contro l
DTE places positive voltage on this pin when powered up
5
7
Signal Ground (GND)
Groun d
Must be connected
6
6
Data Set Ready (DSR)
Contro l
Signal from other RS-232C device telling the DTE that the other RS-232C device is powered up
7
4
Request To Send (RTS)
Contro l
DTE has data to send and places this pin high to request permission to transmit
8
5
Clear To Send (CTS)
X
Contro l
DTE looks for positive voltage on this pin for permission to transmit data
9
22
Ring Indicator (RI)
X
Contro l
A modem signal indicating a ringing signal on the telephone line
X
X
Data Signal wires are used to send and receive serial data. Pin 2 (RD) and pin 3 (TD) are used for transmitting data signals. A positive voltage (> +3 V) on either of these two pins signifies a logic 0 data bit or space data signal. A negative voltage (< 3 V) on either of these two pins signifies a logic 1 data bit or mark signal. Control Signals coordinate and control the flow of data over the RS-232C cable. Pins 1 (DCD), 4 (DTR), 6 (DSR), 7 (RTS), and 8 (CTS) are used for control signals. A positive voltage (> +3 V) indicates a control on signal, while a negative voltage (< -3 V) signifies a control off signal. When a device is configured for hardware handshaking, these signals are used to control the communications. Timing Signals are not used in an asynchronous 9-wire cable. These signals, commonly called clock signals, are used in synchronous communication systems to synchronize the data rate between transmitting and receiving devices. The logic signal definitions used for timing are identical to those used for control signals. Signal Ground on both ends of an RS-232C cable must be connected. Frame ground is sometimes used in 25-pin RS-232C cables as a protective ground.
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Serial Port Parameters An RS-232C serial port is driven by a computer chip called a universal asynchronous receiver/transmitter (UART). The UART sends an 8-bit byte of data out of a serial port preceded with a start bit, the 8 data bits, an optional parity bit, and one or two stop bits. The device on the other end of the serial cable must be configured the same as the sender to understand the received data. The software configurable setup parameters for a serial port are baud rate, parity, stop, and data bit counts. Transmission baud rate signifies the bit transmission speed measured in bits per second. Parity adds an extra bit that provides a mechanism to detect corrupted serial data characters. Stop bits are used to pad a serial data character to a specific number of bits. If the receiver expects 11 bits for each character, the sum of the start bit, data bits, parity bit, and the specified stop bits should equal 11. The stop bits are used to adjust the total to the desired bit count. UARTs support three serial data transmission modes: simplex (one way only), full duplex (bi-directional simultaneously), and half duplex (non-simultaneous bidirectional). GE’s Modbus slave device supports only full duplex data transmission. Device number is the physical RS-232C communication port. Baud rate is the serial data transmission rate of the Modbus device measured in bits per second. The GE Modbus slave device supports 9,600 and 19,200 baud (default). Stop bits are used to pad the number of bits that are transmitted for each byte of serial data. The GE Modbus slave device supports 1 or 2 stop bits. The default is 1 stop bit. Parity provides a mechanism to error check individual serial 8-bit data bytes. The GE Modbus slave device supports none, even, and odd parity. The default is none. Code (byte size) is the number of data bits in each serial character. The GE Modbus slave device supports 7 and 8-bit data bytes. The default byte size is 8 bits.
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Ethernet GSM Some applications require transmitting alarm and event information to the DCS. This information includes high-resolution local time tags in the controller for alarms (25 Hz), system events (25 Hz), and sequence of events (SOEs) for contact inputs (1 ms). Traditional SOEs have required multiple contacts for each trip contact with one contact wired to the turbine control to initiate a trip and the other contact to a separate SOE instrumentation rack for monitoring. The Mark VI uses dedicated processors in each contact input board to time stamp all contact inputs with a 1 ms time stamp, thus eliminating the initial cost and long term maintenance of a separate SOE system. Note The HMI server has the turbine data to support GSM messages. An Ethernet link is available using TCP/IP to transmit data with the local time tags to the plant level control. The link supports all the alarms, events, and SOEs in the Mark VI cabinet. GE supplies an application layer protocol called GSM (GEDS Standard Messages), which supports four classes of application level messages. The HMI Server is the source of the Ethernet GSM communication. HMI View Node PLANT DISTRIBUTED CONTROL SYSTEM (DCS)
Ethernet GSM
Ethernet Modbus
PLANT DATA HIGHWAY PLANT DATA HIGHWAY
HMI Server Node
HMI Server Node
Modbus Communication
From UDH
From UDH
Communication to DCS from HMI using Modbus or Ethernet Options
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Administration Messages are sent from the HMI to the DCS with a Support Unit message, which describes the systems available for communication on that specific link and general communication link availability. Event Driven Messages are sent from the HMI to the DCS spontaneously when a system alarm occurs or clears, a system event occurs or clears, or a contact input (SOE) closes or opens. Each logic point is transmitted with an individual time tag. Periodic Data Messages are groups of data points, defined by the DCS and transmitted with a group time tag. All of the 5,000 data points in the Mark VI are available for transmission to the DCS at periodic rates down to 1 second. One or multiple data lists can be defined by the DCS using controller names and point names. Common Request Messages are sent from the DCS to the HMI including turbine control commands and alarm queue commands. Turbine control commands include momentary logical commands such as raise/lower, start/stop, and analog setpoint target commands. Alarm queue commands consist of silence (plant alarm horn) and reset commands as well as alarm dump requests which cause the entire alarm queue to be transmitted from the Mark VI to the DCS.
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PROFIBUS Communications PROFIBUS is used in wide variety of industrial applications. It is defined in PROFIBUS Standard EN 50170 and in other ancillary guideline specifications. PROFIBUS devices are distinguished as Masters or slaves. Masters control the bus and initiate data communication. They decide bus access by a token passing protocol. Slaves, not having bus access rights, only respond to messages received from Masters. Slaves are peripherals such as I/O devices, transducers, valves, and such devices. PROFIBUS is an open fieldbus communication standard. Note PROFIBUS functionality is only available in simplex, non-TMR Mark VI’s only. At the physical layer, PROFIBUS supports three transmission mediums: RS-485 for universal applications; IEC 1158-2 for process automation; and optical fibers for special noise immunity and distance requirements. The Mark VI PROFIBUS controller provides opto-isolated RS-485 interfaces routed to 9-pin D-sub connectors. Termination resistors are not included in the interface and must therefore be provided by external connectors. Various bus speeds ranging from 9.6 kbit/s to 12 Mbit/s are supported, although maximum bus lengths decrease as bus speeds increase. To meet an extensive range of industrial requirements, PROFIBUS consists of three variations: PROFIBUS-DP, PROFIBUS-FMS, and PROFIBUS-PA. Optimized for speed and efficiency, PROFIBUS-DP is utilized in approximately 90% of PROFIBUS slave applications. The Mark VI PROFIBUS implementation provides PROFIBUS-DP Master functionality. PROFIBUS-DP Masters are divided into Class 1 and Class 2 types. Class 1 Masters cyclically exchange information with slaves in defined message cycles, and Class 2 Masters provide configuration, monitoring, and maintenance functionality. Note The Mark VI operates as a PROFIBUS-DP Class 1 Master exchanging information (generally I/O data) with slave devices each frame. Mark VI UCVE controller versions are available providing one to three PROFIBUSDP Masters. Each may operate as the single bus Master or may have several Masters on the same bus. Without repeaters, up to 32 stations (Masters and slaves) may be configured per bus segment. With repeaters, up to 126 stations may exist on a bus. Note More information on PROFIBUS can be obtained at www.profibus.com.
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PROFIBUS Features
PROFIBUS Feature
Description
Type of Communication
PROFIBUS-DP Class 1 Master/slave arrangement with slaves responding to Masters once per frame; a standardized application based on the ISO/OSI model layers 1 and 2
Network Topology
Linear bus, terminated at both ends with stubs possible
Speed
9.6 kbit/s, 19.2 kbit/s, 93.75 kbit/s, 187.5 kbit/s, 500 kbit/s, 1.5 Mbit/s, 12 Mbit/s
Media
Shielded twisted pair cable
Number of Stations
Up to 32 stations per line segment; extendable to 126 stations with up to 4 repeaters
Connector
9-pin D-sub connector
Number of Masters
From 1-3 Masters per UCVE PROFIBUS Bus Length
kb/s
Maximum Bus Length in Meters
9.6
1200
19.2
1200
93.75
1200
187.5
1000
500
400
1500
200
12000
100
Configuration The properties of all PROFIBUS Master and slave devices are defined in electronic device data sheets called GSD files (for example, SOFTB203.GSD). PROFIBUS can be configured with configuration tools such as Softing AG’s PROFI-KON-DP. These tools enable the configuration of PROFIBUS networks comprised of devices from different suppliers based on information imported from corresponding GSD files. Note GSD files define the properties of all PROFIBUS devices. The third party tool is used rather than the toolbox to identify the devices making up PROFIBUS networks as well as specifying bus parameters and device options (also called parameters). The toolbox downloads the PROFIBUS configurations to Mark VI permanent storage along with the normal application code files. Note Although the Softing AG’s PROFI-KON-DP tool is provided as the PROFIBUS configurator, any such tool will suffice as long as the binary configuration file produced is in the Softing format. For additional information on Mark VI PROFIBUS communications, refer to document, GEI-100536, PROFIBUS Communications.
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I/O and Diagnostics PROFIBUS I/O transfer with slave devices is driven at the Mark VI application level by a set of standard block library blocks. Pairs of blocks read and write analog, Boolean, and byte-oriented data types. The analog blocks read 2, 4, 8 bytes, depending on associated signal data types, and handle the proper byte swapping. The Boolean blocks automatically pack and unpack bit-packed I/O data. The byteoriented blocks access PROFIBUS I/O as single bytes without byte swapping or bit packing. To facilitate reading and writing unsigned short integer-oriented PROFIBUS I/O (needed since unsigned short signals are not available), a pair of analog-to-word/word-to-analog blocks work in tandem with the PROFIBUS analog I/O blocks as needed. Data transfers initiated by multiple blocks operating during a frame are fully coherent since data exchange with slave devices takes place at the end of each frame. PROFIBUS defines three types of diagnostic messages generated by slave devices: x
Station-related diagnostics provide general station status.
x
Module-related diagnostics indicate certain modules having diagnostics pending.
x
Channel-related diagnostics specify fault causes at the channel (point) level.
Note PROFIBUS diagnostics can be monitored by the toolbox and the Mark VI application. Presence of any of these diagnostics can be monitored by the toolbox as well as in Mark VI applications by a PROFIBUS diagnostic block included in the standard block library.
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Fiber-Optic Cables Fiber-optic cable is an effective substitute for copper cable, especially when longer distances are required, or electrical disturbances are a serious problem. The main advantages of fiber-optic transmission in the power plant environment are: x
Fiber segments can be longer than copper because the signal attenuation per foot is less.
x
In high lightning areas, copper cable can pick up currents, which can damage the communications electronics. Since the glass fiber does not conduct electricity, the use of fiber-optic segments avoids pickup and reduces lightning-caused outages.
x
Grounding problems are avoided with optical cable. The ground potential can rise when there is a ground fault on transmission lines, caused by currents coming back to the generator neutral point, or lightning.
x
Optical cable can be routed through a switchyard or other electrically noisy area and not pick up any interference. This can shorten the required runs and simplify the installation.
x
Fiber optic-cable with proper jacket materials can be run direct buried in trays or in conduit.
x
High quality optical fiber cable is light, tough, and easily pulled. With careful installation, it can last the life of the plant.
Disadvantages of fiber optics include: x
The cost, especially for short runs, may be more for a fiber-optic link.
x
Inexpensive fiber-optic cable can be broken during installation, and is more prone to mechanical and performance degradation over time. The highest quality cable avoids these problems.
Components Basics Each fiber link consists of two fibers, one outgoing, and the other incoming to form a duplex channel. A LED drives the outgoing fiber, and the incoming fiber illuminates a phototransistor, which generates the incoming electrical signal. Multimode fiber, with a graded index of refraction core and outer cladding, is recommended for the optical links. The fiber is protected with buffering which is the equivalent of insulation on metallic wires. Mechanical stress is bad for fibers so a strong sheath is used, sometimes with pre-tensioned Kevlar fibers to carry the stress of pulling and vertical runs. Connectors for a power plant need to be fastened to a reasonably robust cable with its own buffering. The square connector (SC) type connector is recommended. This connector is widely used for LANs, and is readily available.
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Fiber-Optic Cable Multimode fibers are rated for use at 850 nm and 1300 nm wavelength. Cable attenuation is between 3.0 and 3.3 db/km at 850 nm. The core of the fiber is normally 62.5 microns in diameter, with a gradation of index of refraction. The higher index of refraction is at the center, gradually shifting to a medium index at the circumference. The higher index slows the light, therefore a light ray entering the fiber at an angle curves back toward the center, out toward the other side, back toward the center, etc. This ray travels further but goes faster because it spends most of its time closer to the circumference where the index is less. The index is graded to keep the delays nearly equal, thus preserving the shape of the light pulse as it passes through the fiber. The inner core is protected with a low index of refraction cladding, which for the recommended cable is 125 microns in diameter. 62.5/125 optical cable is the most common type of cable and should be used. Never look directly into a fiber. Although most fiber links use LEDs that cannot damage the eyes, some longer links use lasers, which can cause permanent damage to the eyes.
Guidelines on cables usage:
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x
Gel filled (or loose tube) cables should not be used because of difficulties making installations, and terminations, and the potential for leakage in vertical runs.
x
Use a high quality break out cable, which makes each fiber a sturdy cable, and helps prevent too sharp bends.
x
Sub-cables are combined with more strength and filler members to build up the cable to resist mechanical stress and the outside environment
x
Two types of cable are recommended, one with armor and one without. Rodent damage is a major cause of optical cable failure. If this is a problem in the plant, the armored cable should be used. If not, the armor is not recommended because it is heavier, has a larger bend radius, is more expensive, attracts lightning currents, and has lower impact and crush resistance.
x
Optical characteristics of the cable can be measured with an optical time domain reflectometer. Some manufacturers will supply the OTDR printouts as proof of cable quality. A simpler instrument is used by installer to measure attenuation, and they should supply this data to demonstrate the installation has a good power margin.
x
Cables described here have four fibers, enough for two fiber-optic links. This can be used to bring redundant communications to a central control room, or the extra fibers can be retained as spares for future plant enhancements. Cables with two fibers are available for indoor use.
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Fiber-Optic Converter Fiber-Optic connections are normally terminated at the 100BaseFX Fiber port of the Ethernet switch. Occasionally, the Mark VI communication system may require an Ethernet media converter to convert selected UDH and PDH electrical signals to fiber-optic signals. The typical media converter makes a two-way conversion of one or more Ethernet 100BaseTX signals to Ethernet 100Base FX signals.
100Base FX Port
TX
RX
Fiber
100BaseTX Port
Pwr
UTP/STP
Dimensions:
Power:
Data:
Width: 3.0 (76 mm) Height: 1.0 (25 mm) Depth: 4.75 (119 mm)
120 V ac, 60 Hz
100 Mbps, fiber optic
Media Converter, Ethernet Electric to Ethernet Fiber-Optic
Connectors The 100Base FX fiber-optic cables for indoor use in Mark VI have SC type connectors. The connector, shown in the following figure, is a keyed, snap-in connector that automatically aligns the center strand of the fiber with the transmission or reception points of the network device. An integral spring helps to keep the SC connectors from being crushed together, to avoid damaging the fiber. The two plugs can be held together as shown, or they can be separate.
.
Locating Key Fiber
. Solid Glass Center Snap-in connnectors SC Connector for Fiber-Optic Cables
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The process of attaching the fiber connectors involves stripping the buffering from the fiber, inserting the end through the connector, and casting it with an epoxy or other plastic. This requires a special kit designed for that particular connector. After the epoxy has hardened, the end of the fiber is cut off, ground, and polished. The complete process takes an experienced person about 5 minutes.
System Considerations When designing a fiber optic network, note the following considerations. Redundancy should be considered for continuing central control room (CCR) access to the turbine controls. Redundant HMIs, fiber-optic links, Ethernet switches, and power supplies are recommended. Installation of the fiber can decrease its performance compared to factory new cable. Installers may not make the connectors as well as experts can, resulting in more loss than planned. The LED light source can get dimmer over time, the connections can get dirty, the cable loss increases with aging, and the receiver can become less sensitive. For all these reasons there must be a margin between the available power budget and the link loss budget, of a minimum of 3 dB. Having a 6 dB margin is more comfortable, helping assure a fiber link that will last the life of the plant.
Installation Planning is important for a successful installation. This includes the layout for the required level of redundancy, cable routing distances, proper application of the distance rules, and procurement of excellent quality switches, UPS systems, and connectors.
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x
Install the fiber-optic cable in accordance with all local safety codes. Polyurethane and PVC are two possible options for cable materials that might NOT meet the local safety codes.
x
Select a cable strong enough for indoor and outdoor applications, including direct burial.
x
Adhere to the manufacturer's recommendations on the minimum bend radius and maximum pulling force.
x
Test the installed fiber to measure the losses. A substantial measured power margin is the best proof of a high quality installation.
x
Use trained people for the installation. If necessary hire outside people with fiber LAN installation experience.
x
The fiber switches and converters need reliable power, and should be placed in a location that minimizes the amount of movement they must endure, yet keep them accessible for maintenance.
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Component Sources The following are typical sources for fiber-optic cable, connectors, converters, and switches. Fiber-Optic Cable: Optical Cable Corporation 5290 Concourse Drive Roanoke, VA 24019 Phone: (540)265-0690 Siecor Corporation PO Box 489 Hickory, NC 28603-0489 Phone: (800)743-2673
Fiber-Optic Connectors: 3M - Connectors and Installation kit Thomas & Betts - Connectors and Assembly polishing kit Amphenol – Connectors and Termination kit
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Time Synchronization The time synchronization option synchronizes all turbine controls, generator controls, and operator interfaces (HMIs) on the Unit Data Highway to a Global Time Source (GTS). Typical GTSs are Global Positioning Satellite (GPS) receivers such as the StarTime GPS Clock or similar time processing hardware. The preferred time sources are Coordinated Universal Time (UTC) or GPS. A time/frequency processor board, either the BC620AT or BC627AT, is placed in the HMI computer. This board acquires time from the GTS with a high degree of accuracy. When the HMI receives the time signal, it makes the time information available to the turbine and generator controls on the network through Network Time Protocol (NTP). The HMI Server provides time to time slaves either by broadcasting time, or by responding to NTP time queries, or by both methods. Refer to RFC 1305 Network Time Protocol (Version 3) dated March 1992 for details. Redundant time synchronization is provided by supplying a time/frequency processor board in another HMI Server as a backup. Normally, the primary HMI Server on the UDH is the time Master for the UDH, and other computers without the time/frequency board are time slaves. The time slave computes the difference between the returned time and the recorded time of request and adjusts its internal time. Each time slave can be configured to respond to a time Master through unicast mode or broadcast mode. Local time is used for display of real-time data by adding a local time correction to UTC. A node’s internal time clock is normally global rather than local. This is done because global time steadily increases at a constant rate while corrections are allowed to local time. Historical data is stored with global time to minimize discontinuities.
Redundant Time Sources If either the GTS or time Master becomes inoperative, the backup is to switch the BC620AT or BC627AT to flywheel mode with a drift of ±2 ms/hour. In most cases, this allows sufficient time to repair the GTS without severe disruption of the plant’s system time. If the time Master becomes inoperative, then each of the time slaves picks the backup time Master. This means that all nodes on the UDH lock onto the identical reference for their own time even if the primary and secondary time Masters have different time bases for their reference. If multiple time Masters exist, each time slave selects the current time Master based on whether or not the time Master is tracking the GTS, which time Master has the best quality signal, and which Master is listed first in the configuration file.
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Selection of Time Sources The BC620AT and BC627AT boards support the use of several different time sources; however, the time synchronization software does not support all sources supported by the BC620AT board. A list of time sources supported by both the BC620AT and the time synchronization software includes: x
x
Modulated IRIG-A, IRIG-B, 2137, or NASA-36 timecode signals –
Modulation ratio 3:1 to 6:1
–
Amplitude 0.5 to 5 V peak to peak
Dc Level Shifted Modulated IRIG-A, IRIG-B, 2137, or NASA-36 timecode signals –
x
1 PPS (one pulse per second) using the External 1 PPS input signal of the BC620AT board –
x
TTL/CMOS compatible voltage levels
TTL/CMOS compatible voltage levels, positive edge on time
Flywheel mode using no signal, using the low drift clock on the BC620AT or BC627AT board –
Flywheel mode as the sole time source for the plant
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Notes
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CHAPTER 4
Chapter 4 Codes, Standards, and Environment Introduction ................................................................................ 4-1 Safety Standards ......................................................................... 4-1 Electrical..................................................................................... 4-2 Environment ............................................................................... 4-5
Introduction This chapter describes the codes, standards, and environmental guidelines used for the design of all printed circuits, modules, cores, panels, and cabinet line-ups in the control system. Requirements for harsh environments, such as marine applications, are not covered here.
Safety Standards EN 61010-1
Safety Requirements for Electrical Equipment for Measurement, Control, and Laboratory Use, Part 1: General Requirements
CAN/CSA 22.2 No. 1010.1-92
Safety Requirements for Electrical Equipment for Measurement, Control, and Laboratory Use, Part 1: General Requirements
ANSI/ISA 82.02.01 1999
Safety Standard for Electrical and Electronic Test, Measuring, Controlling, and Related Equipment – General Requirements
IEC 60529
Intrusion Protection Codes/NEMA 1/IP 20
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Electrical Printed Circuit Board Assemblies UL 796
Printed Circuit Boards
ANSI IPC guidelines ANSI IPC/EIA guidelines
Electromagnetic Compatibility (EMC) EN 50081-2
General Emission Standard
EN 55011
Radiated and Conducted RF Emissions
EN 50082-2
Generic Immunity Industrial Environment
EN/IEC 61000-4-2
Electrostatic Discharge Susceptibility
EN/IEC 61000-4-3
Radiated RF Immunity
EN/IEC 61000-4-4
Electrical Fast Transient Susceptibility
EN/IEC 61000-4-5
Surge Immunity
EN/IEC 61000-4-6
Conducted RF Immunity
EN/IEC 61000-4-11
Voltage Variation, Dips and Interruptions
ANSI/IEEE C37.90.1
Surge
Low Voltage Directive EN 61010-1 Safety Requirements for Electrical Equipment for Measurement, Control, and Laboratory Use, Part 1: General Requirements
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Supply Voltage Line Variations Ac Supplies – Operating line variations of ±10 % IEEE Std 141-1993 defines the Equipment Terminal Voltage – Utilization voltage. The above meets IEC 60204-1 1999, and exceeds IEEE Std 141-1993, and ANSI C84.1-1989. Dc Supplies – Operating line variations of -30 %, +20 % or 145 V dc. This meets IEC 60204-1 1999.
Voltage Unbalance Less than 2% of positive sequence component for negative sequence component Less than 2% of positive sequence component for zero sequence component This meets IEC 60204-1 1999 and IEEE Std 141-1993.
Harmonic Distortion Voltage: Less than 10% of total rms voltage between live conductors for 2nd through 5th harmonic Additional 2% of total rms voltage between live conductors for sum of 6th – 30th harmonic This meets IEC 60204-1 1999. Current: The system specification is not per individual equipment Less than 15% of maximum demand load current for harmonics less than 11 Less than 7% of maximum demand load current for harmonics between 11 and 17 Less than 6% of maximum demand load current for harmonics between 17 and 23 Less than 2.5% of maximum demand load current for harmonics between 23 and 35 The above meets IEEE Std 519 1992.
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Frequency Variations Frequency variation of ±5% when operating from ac supplies (20 Hz/sec slew rate) This exceeds IEC 60204-1 1999.
Surge Withstand 2 kV common mode, 1 kV differential mode This meets IEC 61000-4-5 (ENV50142), and ANSI C62.41 (combination wave).
Clearances NEMA Tables 7-1 and 7-2 from NEMA ICS1-2000 This meets IEC 61010-1:1993/A2: 1995, CSA C22.2 #14, and UL 508C.
Power Loss 100 % Loss of supply - minimum 10 ms for normal operation of power products 100 % Loss of supply - minimum 500 ms before control products require reset (only applicable to ac powered systems with DACAs; not applicable to dc-only powered Mark VIs). This exceeds IEC 61000-4-11.
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Environment Storage If the system is not installed immediately upon receipt, it must be stored properly to prevent corrosion and deterioration. Since packing cases do not protect the equipment for outdoor storage, the customer must provide a clean, dry place, free of temperature variations, high humidity, and dust. Use the following guidelines when storing the equipment: x
x
Place the equipment under adequate cover with the following requirements: –
Keep the equipment clean and dry, protected from precipitation and flooding.
–
Use only breathable (canvas type) covering material – do not use plastic.
Unpack the equipment as described, and label it. –
Maintain the following environment in the storage enclosure:
–
Recommended ambient storage temperature limits from -40 to 80°C (40 to 176 °F).
–
Surrounding air free of dust and corrosive elements, such as salt spray or chemical and electrically conductive contaminants
–
Ambient relative humidity from 5 to 95% with provisions to prevent condensation
–
No rodents
–
No temperature variations that cause moisture condensation Moisture on certain internal parts can cause electrical failure.
Condensation occurs with temperature drops of 15°C (27 °F) at 50% humidity over a 4 hour period, and with smaller temperature variations at higher humidity. If the storage room temperature varies in such a way, install a reliable heating system that keeps the equipment temperature slightly above that of the ambient air. This can include space heaters or cabinet space heaters (when supplied) inside each enclosure. A 100 W lamp can sometimes serve as a substitute source of heat.
To prevent fire hazard, remove all cartons and other such flammable materials packed inside units before energizing any heaters.
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Operating The Mark VI control components are suited to most industrial environments. To ensure proper performance and normal operational life, the environment should be maintained as follows: Temperature at bottom of module (acceptable): Control Module with running fans I/O Module
0 to 60°C (32 to 140 °F) 0 to 60°C (32 to 140 °F)
Enclosures should be designed to maintain this temperature range. Relative humidity: 5 to 95%, non-condensing. Note Higher ambient temperature decreases the life expectancy of any electronic component.
Environments that include excessive amounts of any of the following elements reduce panel performance and life: x
Dust, dirt, or foreign matter
x
Vibration or shock
x
Moisture or vapors
x
Rapid temperature changes
x
Caustic fumes
x
Power line fluctuations
x
Electromagnetic interference or noise introduced by: –
Radio frequency signals, typically from nearby portable transmitters
–
Stray high voltage or high frequency signals, typically produced by arc welders, unsuppressed relays, contactors, or brake coils operating near control circuits
The preferred location for the Mark VI control system cabinet would be in an environmentally controlled room or in the control room itself. The cabinet should be mounted where the floor surface allows for attachment in one plane (a flat, level, and continuous surface). The customer provides the mounting hardware. Lifting lugs are provided and if used, the lifting cables must not exceed 45° from the vertical plane. Finally, the cabinet is equipped with a door handle, which can be locked for security. Interconnecting cables can be brought into the cabinet from the top or the bottom through removable access plates. Convection cooling of the cabinet requires that conduits be sealed to the access plates. Also, air passing through the conduit must be within the acceptable temperature range as listed previously. This applies to both top and bottom access plates.
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Elevation Equipment elevation is related to the equivalent ambient air pressure. x
Normal Operation - 0 to1000 m (3300 ft) (101.3 KPa - 89.8 KPa)
x
Extended Operation - 1000 to 3050 m (3300 to 10,000 ft) (89.8 KPa - 69.7 KPa)
x
Shipping - 4600 m (15000 ft) maximum (57.2 KPa)
Note A guideline for system behavior as a function of altitude is that for altitudes above 1000 m (3300 ft), the maximum ambient rating of the equipment decreases linearly to a derating of 5°C (41°F) at 3050 m (10000 ft). The extended operation and shipping specifications exceed EN50178.
Contaminants Gas The control equipment withstands the following concentrations of corrosive gases at 50% relative humidity and 40°C (104 °F): Sulfur dioxide (SO2)
30 ppb
Hydrogen sulfide (H2S)
10 ppb
Nitrous fumes (NOx)
30 ppb
Chlorine (Cl2)
10 ppb
Hydrogen fluoride (HF)
10 ppb
Ammonia (NH3)
500 ppb
Ozone (O3)
5 ppb
The above meets EN50178 Section A.6.1.4 Table A.2 (m).
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Vibration Seismic Universal Building Code (UBC) - Seismic Code section 2312 Zone 4
Operating / Installed at Site Vibration of 1.0 G Horizontal, 0.5 G Vertical at 15 to 120 Hz See Seismic UBC for frequencies lower than 15 Hz.
Packaging The standard Mark VI cabinets meet NEMA 1 requirements (similar to the IP-20 cabinet). Optional cabinets for special applications meet NEMA 12 (IP-54), NEMA 4 (IP-65), and NEMA 4X (IP-68) requirements. Redundant heat exchangers or air conditioners, when required, can be supplied for the above optional cabinets.
UL Class 1 Division 2 Listed Boards Certain boards used in the Mark VI are UL listed (E207685) for Class 1 Division 2, Groups A, B, C, and D, Hazardous Locations, Temperature Class T4 using UL-1604. Division 2 is described by NFPA 70 NEC 1999 Article 500 (NFPA - National Fire Protection Assocation, NEC - National Electrical Code). The Mark VI boards/board combinations that are listed may be found under file number E207685 at the UL website and currently include: x
IS200VCMIH1B, H2B
x
IS200DTCCH1A, IS200VTCCH1C
x
IS200DRTDH1A, IS200VRTDH1C
x
IS200DTAIH1A, IS200VAICH1C
x
IS200DTAOH1A, IS200VAOCH1B
x
IS200DTCIH1A, IS200VCRCH1B
x
IS200DRLYH1B
x
IS200DTURH1A, IS200VTURH1B
x
IS200DTRTH1A
x
IS200DSVOH2B, IS200VSVOH1B
x
IS200DVIBH1B, IS200VVIBH1C
x
IS200DSCBH1A, IS200VSCAH2A
x
IS215UCVEH2A, M01A, M03A, M04A, M05A
x
IS215UCVDH2A
x
IS2020LVPSG1A
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CHAPTER 5
Chapter 5 Installation and Configuration Installation Support .................................................................... 5-1 Equipment Receiving and Handling........................................... 5-5 Weights and Dimensions............................................................ 5-6 Power Requirements................................................................... 5-11 Installation Support Drawings .................................................... 5-12 Grounding................................................................................... 5-17 Cable Separation and Routing .................................................... 5-25 Cable Specifications ................................................................... 5-31 Connecting the System ............................................................... 5-35 Startup Checks............................................................................ 5-41 Startup and Configuration .......................................................... 5-45
Introduction This chapter defines installation requirements for the Mark VI control system. Specific topics include GE installation support, wiring practices, grounding, typical equipment weights and dimensions, power dissipation and heat loss, and environmental requirements.
Installation Support GE’s system warranty provisions require both quality installation and that a qualified service engineer be present at the initial equipment startup. To assist the customer, GE offers both standard and optional installation support. Standard support consists of documents that define and detail installation requirements. Optional support is typically the advisory services that the customer may purchase.
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Early Planning To help ensure a fast and accurate exchange of data, a planning meeting with the customer is recommended early in the project. This meeting should include the customer’s project management and construction engineering representatives. It should accomplish the following: x
Familiarize the customer and construction engineers with the equipment
x
Set up a direct communication path between GE and the party making the customer’s installation drawings
x
Determine a drawing distribution schedule that meets construction and installation needs
x
Establish working procedures and lines of communication for drawing distribution
GE Installation Documents Installation documents consist of both general and requisition-specific information. The cycle time and the project size determine the quantity and level of documentation provided to the customer. General information, such as this document, provides product-specific guidelines for the equipment. They are intended as supplements to the requisition-specific information. Requisition documents, such as outline drawings and elementary diagrams provide data specific to a custom application. Therefore, they reflect the customer’s specific installation needs and should be used as the primary data source. As-Shipped drawings consist primarily of elementary diagrams revised to incorporate any revisions or changes made during manufacture and test. These are issued when the equipment is ready to ship. Revisions made after the equipment ships, but before start of installation, are sent as Field Change, with the changes circled and dated.
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Technical Advisory Options To assist the customer, GE Energy offers the optional technical advisory services of field engineers for: x
Review of customer’s installation plan
x
Installation support
These services are not normally included as installation support or in basic startup and commissioning services shown below. GE presents installation support options to the customer during the contract negotiation phase. Installation Support
Begin Installation
Startup
Commissioning
Complete Installation
Begin Formal Testing
Product Support - On going
System Acceptance Startup and Commissioning Services Cycle
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Installation Plan and Support It is recommended that a GE field representative review all installation/construction drawings and the cable and conduit schedule when completed. This optional review service ensures that the drawings meet installation requirements and are complete. Optional installation support is offered: planning, practices, equipment placement, and onsite interpretation of construction and equipment drawings. Engineering services are also offered to develop transition and implementation plans to install and commission new equipment in both new and existing (revamp) facilities.
Customer’s Conduit and Cable Schedule The customer’s finished conduit and cable schedule should include: x
Interconnection wire list (optional)
x
Level definitions
x
Shield terminations
The cable and conduit schedule should define signal levels and classes of wiring (see the section, Cable Separation and Routing). This information should be listed in a separate column to help prevent installation errors. The cable and conduit schedule should include the signal level definitions in the instructions. This provides all level restriction and practice information needed before installing cables. The conduit and cable schedule should indicate shield terminal practice for each shielded cable (refer to section, Connecting the System).
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Equipment Receiving and Handling Note For information on storing equipment, refer to Chapter 4 GE inspects and packs all equipment before shipping it from the factory. A packing list, itemizing the contents of each package, is attached to the side of each case. Upon receipt, carefully examine the contents of each shipment and check them with the packing list. Immediately report any shortage, damage, or visual indication of rough handling to the carrier. Then notify both the transportation company and GE Energy. Be sure to include the serial number, part (model) number, GE requisition number, and case number when identifying the missing or damaged part. Immediately upon receiving the system, place it under adequate cover to protect it from adverse conditions. Packing cases are not suitable for outdoor or unprotected storage. Shock caused by rough handling can damage electrical equipment. To prevent such damage when moving the equipment, observe normal precautions along with all handling instructions printed on the case. If assistance is needed contact: GE Energy Post Sales Service 1501 Roanoke Blvd. Salem, VA 24153-6492 Phone: Fax:
1 888 GE4 SERV (888 434 7378, United States) + 1 540 378 3280 (International) + 1 540 387 8606 (All)
Note "+" indicates the international access code required when calling from outside of the USA.
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Weights and Dimensions Cabinets A single Mark VI cabinet is shown below. This can house three controllers used in a system with all remote I/O. Dimensions, clearance, bolt holes, lifting lugs, and temperature information is included. Lift Bolts with 38 mm (1.5 in) dia hole, should be left in place after installation for Seismic Zone 4. If removed, fill bolt holes. Single Control Panel Total Weight 180 kg (400lbs) Window
Cabinet Depth 610.0 mm (24 in)
1842 mm (72.5)
A A
Cable Entry Space for wire entry in base of cabinet Equipment Access Front and rear access doors, no side access. Front door has clear plastic window.
Air Intake
Service Conditions NEMA1 enclosure for standard indoor use. 610 mm (24)
610 (24.0)
Six 16 mm (0.635 inch) dia holes in base for customers mounting studs or bolts
236.5 (9.31) 236.5 (9.31)
View of base looking down in direction "A" 475 (18.6875) Typical Controller Cabinet
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The controller cabinet is for small gas turbine systems (simplex only). It contains control, I/O, and power supplies, and weighs 620 kg (1,367 lbs) complete. One Panel Lineup (one door)
114.3 (4.5)
38.1 (1.5)
2400.3 (94.5)
57.9 (2.28)
A
865.63 (34.08) 906.53 (35.69)
925.58 (36.44)
Approx. Door Swing (See Note 2)
184.15 (7.25)
348.49 (13.72)
6 holes, 16 mm (0.635 inch) dia, in base for customers mounting studs or bolts.
387.6 (15.26) (2.47)
151.64 (5.97)
387.6 (15.26)
62.74
254.0 (10.0) 69.09 (2.72)
775.97 (30.55)
61.47 (2.42)
Notes: 1. All dimensions are in mm and (inches) unless noted. 2. Door swing clearance required at front as shown. Doors open 105 degrees max. and are removable by removing hinge pins. 3. All doors have provisions for pad locking. 4. Suggested mounting is 10 mm (0.375) expansion anchors. Length must allow for 71.1 mm (2.8) case sill. 5. Cross hatching indicates conduit entry with removable covers. 6. Lift angles should remain in place to meet seismic UBC zone 4 requirements. 7. No mechanical clearance required at back or ends. 8. Service conditions - indoor use at rated minimum and maximum ambient temperatures.
609.6 (24.0)
View of top looking down in direction of arrow "A"
317.25 (12.49)
View of base looking down in direction of arrow "A"
Typical Controller Cabinet
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The two-door cabinet shown in the following figure is for small gas turbine systems. It contains control, I/O, and power supplies, and weighs approximately 720 kg (1,590 lbs) complete. A 1600 mm wide version of this cabinet is available, and weighs approximately 912 kg ( 2,010 lbs) complete. Lift Angles with two 30.2 (1.18) holes, should be left in place for Seismic Zone 4, if removed, fill bolt holes.
Two Panel Lineup (Two Doors)
Total Weight Cabinet Depth
912 kg (2010lbs) 903.9 mm (35.59 in)
Cable Entry Removable covers top and bottom. 2400 mm (94.5)
Equipment Access Front doors only, no rear or side access. Door swing clearance 977.9 mm (38.5). Mounting Holes in Base Six 16 mm (0.635 in) dia holes in base of the cabinet for customers mounting studs or bolts, for details see GE dwgs.
A
1350 mm (53.15)
Service Conditions Standard NEMA1 enclosure for indoor use.
387.5 (15.26) 387.5 (15.26)
62.5 (2.46)
6 holes, 16 mm (0.635 inch) dia, in base for customers mounting studs or bolts.
1225.0 (48.23)
62.5 (2.46) View of base looking down in direction of arrow "A"
Typical Controller Cabinet
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A typical lineup for a complete Mark VI system is shown in the following figure. These cabinets contain controllers, I/O, and terminal boards, or they can contain just the remote I/O and terminal boards. Lift Angles front and back, should be left in place for Seismic Zone 4, if removed, fill bolt holes.
I/O
Three Cabinet Lineup (Five Doors)
Total Weight 1770 kg (3,900 lbs) Cabinet Depth 602 mm (23.7 in)
I/O
Control
I/O
Cable Entry Removable covers top and bottom.
Power 2324.3 mm (91.5)
Mounting Holes in Base Six 16 mm (0.635 in) dia holes in base of each of the three cabinets for customers mounting studs or bol ts, for details see GE dwgs.
A
1600 mm (62.99)
1600 mm (62.99)
1000 mm (39.37)
Service Conditions Standard NEMA1 enclosure for indoor use.
4200 mm (165.35)
237.5 (9.35) 237.5 (9.35)
62.5 (2.46)
1475.0 (58.07) 62.5 (2.46)
875.0 (34.45)
125.0 (4.92)
18 holes, 16 mm (0.635 in) dia, in base for customers mounting studs or bolts.
1475.0 (58.07)
125.0 (4.92)
Equipment Access Front doors only, no rear or side access. Door swing clearance 977.9 mm (38.5 in).
62.5 (2.46)
View of base looking down in direction of ar row "A"
Typical Mark VI Cabinet Lineup
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Control Console (Example) The turbine control HMI computers can be table-mounted, or installed in the optional control console shown in the following figure. The console is modular and expandable from an 1828.8 mm version with two computers. A 5507 mm version with four computers is shown. The console rests on feet and is not usually bolted to the floor. Full Console 5507 mm (18 '- 0 13/16 ") Short Console 1828.8 mm (72 ")
itor Mon le u d Mo
Main Module M M oni t od o r ul e
Modular Desktop
Printer
Phone
Monitor
Phone
Monitor
Printer Pedestal
2233.61 mm (7 '- 3 15/16")
Monitor
Monitor
1181.1mm (46.5 ")
Undercounter Keyboards
Turbine Control Console with Dimensions
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Power Requirements The Mark VI control cabinet can accept power from multiple power sources. Each power input source (such as the dc and two ac sources) should feed through its own external 30 A two-pole thermal magnetic circuit breaker before entering the Mark VI enclosure. The breaker should be supplied in accordance with required site codes. Power sources can be any combination of 24 V dc, 125 V dc and 120/240 V ac sources. The Mark VI power distribution hardware is configured for the required sources, and not all inputs may be available in a configuration. Input power is converted to 28 V dc for operation of the control electronics. Other power is distributed as needed for use with I/O signals. Power requirements for a typical three-bay (five-door) 4200 mm cabinet containing controllers, I/O, and terminal boards are shown in the following table. The power shown is the heat generated in the cabinet, which must be dissipated. For the total current draw, add the current supplied to external solenoids as shown in the notes below the table. These external solenoids generate heat inside the cabinet. Heat Loss in a typical 4200 mm (165 in) TMR cabinet is 1500 W fully loaded. For a single control cabinet containing three controllers only (no I/O), the following table shows the nominal power requirements. This power generates heat inside the control cabinet. Heat Loss in a typical TMR controller cabinet is 300 W. The current draw number in the following table is assuming a single voltage source, if two or three sources are used, they share the load. The actual current draw from each source cannot be predicted because of differences in the ac/dc converters. For further details on the cabinet power distribution system, refer to Volume II of this System Guide. Power Requirements for Cabinets
Cabinet 4200 mm Cabinet
Voltage
Frequency
125 V dc 120 V ac
Controller Cabinet
240 V ac 125 V dc 120 V ac 240 V ac
100 to 144 V dc (see Note 5) 108 to 132 V ac (see Note 6) 200 to 264 V ac 100 to 144 V dc (see Note 5) 108 to 132 V ac (see Note 6) 200 to 264 V ac
Current Draw
N/A
N/A
10.0 A dc (see Note 1)
50/60 Hz
± 3 Hz
17.3 A rms (see Notes 2 and 4)
50/60 Hz N/A
± 3 Hz N/A
8.8 A rms (see Notes 3 and 4) 1.7 A dc
50/60 Hz
± 3 Hz
3.8 A rms
50/60 Hz
± 3 Hz
1.9 A rms
* Notes on table (these are external and do not create cabinet heat load). 1
Add 0.5 A dc continuous for each 125 V dc external solenoid powered.
2
Add 6.0 A rms for a continuously powered ignition transformer (2 maximum).
3
Add 3.5 A rms for a continuously powered ignition transformer (2 maximum).
4
Add 2.0 A rms continuous for each 120 V ac external solenoid powered (in rush 10 A).
5
Supply voltage ripple is not to exceed 10 V peak-to-peak.
6
Supply voltage total harmonic distortion is not to exceed 5.0%.
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Installation Support Drawings This section describes GE installation support drawings. These drawings are usually B-size AutoCAD drawings covering all hardware aspects of the system. A few sample drawings include: x
System Topology
x
Cabinet Layout
x
Cabinet Layout
x
Circuit Diagram
In addition to the installation drawings, site personnel will need the I/O Assignments (IO Report).
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Typical System Topology Showing Interfaces
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HMI Server 1 (GEPS)
21 ''
21 ''
Operator
21 ''
2 1 ''
Alstom P320 Steam Turbine Control Unit #3
Centralog Centralog CVS CVS (ALSTOM) (ALSTOM)
* 350 logic and 150 analog points.
Printer
21 ''
21 ''
21 ''
21 ''
g
21 ''
g
Modbus
GEC
X1 EX2100 by GE PS
g
Gas Chromatograph #2
Aux Boiler Gas Chromatograph #1 Data via Gas Reduction Sta PLC (ERM)
Electrical Room
21 ''
21 ''
Water Treatment (400 PTS) Serial
Modbus
Air Cooled Cond.
C1 MarkVI (ICS)
g
Unit Data Highway
CEMS
Engineering Office
OSM
Plant Data Highway (GE PS)
EWS (ICS) Historian Unit 1 (ICS)
Laser printer Printer (ICS) (ICS)
Supervisor Work Sta (ICS)
Color inkjet (ICS)
HRSG1 HRSG2 BOP 1 MarkVI (ICS) MarkVI (ICS)MarkVI (ICS) H1 H2
g
Alarm printer
HMI Server 2 (GEPS )
S1 MarkVI (ICS) ST/BOP
g
Console IEC608 70 Printer -5-104 ST OP Sta ST OP Sta Alarm printer
(ALSTOM) (ALSTOM)
ST Interface (ICS)
21 ''
ST Interface (ICS)
Plant SCADA
GPS (ICS)
g
GT #1 LEC
EX2100 LS2100
g
PEECC #1
Gas Turbine Mark VI TMR Unit #1
g
Alarm Printer
17 "
Local GT Server
g
GT #2 LEC
EX2100 LS2100
g
PEECC #2
Gas Turbine Mark VI TMR Unit #2
g
Alarm Printer
17 "
Local GT Server
Typical I/O Cabinet Drawing showing Dimensions, Cable Access, Lifting Angles, and Mounting
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Panel Layout with Protection Module
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1J4
1I5
1J5
I/O Panel with Terminal Boards and Power Supplies
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Grounding This section defines grounding and signal-referencing practices for the Mark VI system. This can be used to check for proper grounding and Signal Reference Structure (SRS) after the equipment is installed. If checking the equipment after the power cable has been connected or after power has been applied to the cabling, be sure to follow all safety precautions for working around high voltages. To prevent electric shock, make sure that all power supplies to the equipment are turned off. Then discharge and ground the equipment before performing any act requiring physical contact with the electrical components or wiring. If test equipment cannot be grounded to the equipment under test, the test equipment's case must be shielded to prevent contact by personnel.
Equipment Grounding Equipment grounding and signal referencing have two distinct purposes: x
Equipment grounding protects personnel and equipment from risk of electrical shock or burn, fire, or other damage caused by ground faults or lightning.
x
Signal referencing helps protect equipment from the effects of internal and external electrical noise such as from lightning or switching surges.
Installation practices must simultaneously comply with all codes in effect at the time and place of installation, and practices, which improve the immunity of the installation. In addition to codes, IEEE Std 142-1991 IEEE Recommended Practice for Grounding of Industrial and Commercial Power Systems and IEEE Std 11001992 IEEE Recommended Practice for Powering and Grounding Sensitive Electronic Equipment provide guidance in the design and implementation of the system. Code requirements for safety of personnel and equipment must take precedence in the case of any conflict with noise control practices. The Mark VI system has no special or nonstandard installation requirements, if installed in compliance with all of the following: x
The NEC® or local codes
x
With a signal reference structure (SRS) designed to meet IEEE Std 1100
x
Interconnected with signal/power-level separation as defined later
This section provides equipment grounding and bonding guidelines for control and I/O cabinets. These guidelines also apply to motors, transformers, brakes, and reactors. Each of these devices should have its own grounding conductor going directly to the building ground grid. x
Ground each cabinet or cabinet lineup to the equipment ground at the source of power feeding it. –
See NEC Article 250 for sizing and other requirements for the equipment grounding conductor.
–
For dc circuits only, the NEC allows the equipment grounding conductor to be run separate from the circuit conductors.
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x
With certain restrictions, the NEC allows the metallic raceways or cable trays containing the circuit conductors to serve as the equipment grounding conductor: –
This use requires that they form a continuous, low-impedance path capable of conducting anticipated fault current.
–
This use requires bonding across loose-fitting joints and discontinuities. See NEC Article 250 for specific bonding requirements. This chapter includes recommendations for high frequency bonding methods.
–
If metallic raceways or cable trays are not used as the primary equipment grounding conductor, they should be used as a supplementary equipment grounding conductor. This enhances the safety of the installation and improves the performance of the Signal Reference Structure (see later).
x
The equipment grounding connection for the Mark VI cabinets is plated copper bus or stub bus. This connection is bonded to the cabinet enclosure using bolting that keeps the conducting path’s resistance at 1 ohm or less.
x
There should be a bonding jumper across the ground bus or floor sill between all shipping splits. The jumper may be a plated metal plate.
x
The non-current carrying metal parts of the equipment covered by this section should be bonded to the metallic support structure or building structure supporting this equipment. The equipment mounting method may satisfy this requirement. If supplementary bonding conductors are required, size them the same as equipment grounding conductors.
Building Grounding System This section provides guidelines for the building grounding system requirements. For specific requirements, refer to NEC article 250 under the heading Grounding Electrode System. The guidelines below are for metal framed buildings. For non-metal framed buildings, consult the GE factory. The ground electrode system should be composed of steel reinforcing bars in building column piers bonded to the major building columns. x
A buried ground ring should encircle the building. This ring should be interconnected with the bonding conductor running between the steel reinforcing bars and the building columns.
x
All underground, metal water piping should be bonded to the building system at the point where the piping crosses the ground ring.
x
NEC Article 250 requires that separately derived systems (transformers) be grounded to the nearest effectively grounded metal building structural member.
x
Braze or exothermically weld all electrical joints and connections to the building structure, where practical. This type of connection keeps the required good electrical and mechanical properties from deteriorating over time.
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Signal Reference Structure (SRS) On modern equipment communicating at high bandwidths, signals are typically differential and/or isolated electrically or optically. The modern SRS system replaces the older single-point grounding system with a much more robust system. The SRS system is also easier to install and maintain. The goal of the SRS is to hold the electronics at or near case potential to prevent unwanted signals from disturbing operation. The following conditions must all be met by an SRS: x
Bonding connections to the SRS must be less than 1/20 wavelength of the highest frequency to which the equipment is susceptible. This prevents standing waves. In modern equipment using high-frequency digital electronics, frequencies as high as 500 MHz should be considered, which translates to about 30 mm (1in).
x
SRS must be a good high frequency conductor. (Impedance at high frequencies consists primarily of distributed inductance and capacitance.) Surface area is more important than cross-sectional area because of skin effect. Conductivity is less important (steel with large surface area is better than copper with less surface area).
x
SRS must consist of multiple paths. This lowers the impedance and the probability of wave reflections and resonance
In general, a good signal referencing system can be obtained with readily available components in an industrial site. All of the items listed below can be included in an SRS: x
Metal building structural members
x
Galvanized steel floor decking under concrete floors
x
Woven wire steel reinforcing mesh in concrete floors
x
Steel floors in pulpits and power control rooms
x
Bolted grid stringers for cellular raised floors
x
Steel floor decking or grating on line-mounted equipment
x
Galvanized steel culvert stock
x
Metallic cable tray systems
x
Raceway (cableway) and raceway support systems
x
Embedded steel floor channels
Note All provisions may not apply to an installation.
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Connection of the protective earth terminal to the installation ground system must first comply with code requirements and second provide a low-impedance path for high-frequency currents, including lightning surge currents. This grounding conductor must not provide, either intentionally or inadvertently, a path for load current. The system should be designed such that in so far as is possible the control system is not an attractive path for induced currents from any source. This is best accomplished by providing a ground plane that is large and low impedance, so that the entire system remains at the same potential. A metallic system (grid) will accomplish this much better than a system that relies upon earth for connection. At the same time all metallic structures in the system should be effectively bonded both to the grid and to each other, so that bonding conductors rather than control equipment become the path of choice for noise currents of all types. In the Mark VI cabinet, the electronics cabinet is insulated from the chassis and bonded at one point. The grounding recommendations shown in the following figure. Call for the equipment grounding conductor to be 120 mm2 (AWG 4/0) gauge wire, connected to the building ground system. The Functional Earth (FE) is bonded at one point to the Protective Earth (PE) ground using two 25 mm2 (4 AWG) green/yellow bonding jumpers.
Control & I/O Electronics Panel Mark VIe Cabinet
Functional Earth (FE)
Equipment grounding conductor, Identified 120 mm sq. (4/0 AWG), insulated wire, short a distance as possible
Two 25 mm sq. (4 AWG) Green/Yellow insulated bonding jumpers
Protective Conductor Terminal Protective Earth (PE) PE
Building Ground System Grounding Recommendations for Single Mark VI Cabinet
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If acceptable by local codes, the bonding jumpers may be removed and a 4/0 AWG identified insulated wire run from FE to the nearest accessible point on the building ground system, or to another ground point as required by the local code. The distance between the two connections to building ground should be approximately 4.6 m (15 ft), but not less than 3 m (10 ft). Grounding for a larger system is shown in following figure. Here the FE is still connected to the control electronics section, but the equipment-grounding conductor is connected to the center cabinet chassis. Individual control and I/O panels are connected with bolted plates. On a cable carrying conductors and/or shielded conductors, the armor is an additional current carrying braid that surrounds the internal conductors. This type cable can be used to carry control signals between buildings. The armor carries secondary lightning-induced earth currents, bypassing the control wiring, thus avoiding damage or disturbance to the control system. At the cable ends and at any strategic places between, the armor is grounded to the building ground through the structure of the building with a 360° mechanical and electrical fitting. The armor is normally terminated at the entry point to a metal building or machine. Attention to detail in installing armored cables can significantly reduce induced lightning surges in control wiring.
I/O Panel
Control Electronics Panel
I/O Panel
Panel Grounding Connection Plates
Functional Earth (FE)
Equipment grounding conductor, Identified 120 mm sq. (4/0 AWG), insulated wire, short a distance as possible
Two 25 mm sq. 4AWG Green/Yellow Bonding Jumper wires
Protective Conductor Terminal (Chassis Safety Ground plate)
PE
Building Ground System Grounding Recommendations for Mark VI Cabinet Lineup
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Notes on Grounding Bonding to building structure - The cable tray support system typically provides many bonding connections to building structural steel. If this is not the case, supplemental bonding connections must be made at frequent intervals from the cable tray system to building steel. Bottom connected equipment - Cable tray installations for bottom connected equipment should follow the same basic principles as those illustrated for top connected equipment, paying special attention to good high frequency bonding between the cable tray and the equipment. Cable spacing - Maintain cable spacing between signal levels in cable drops, as recommended here. Conduit sleeves - Where conduit sleeves are used for bottom-entry cables, the sleeves should be bonded to the floor decking and equipment enclosure with short bonding jumpers. Embedded conduits - Bond all embedded conduits to the enclosure with multiple bonding jumper connections following the shortest possible path. Galvanized steel sheet floor decking - Floor decking can serve as a high frequency signal reference plane for equipment located on upper floors. With typical building construction, there will be a large number of structural connections between the floor decking and building steel. If this is not the case, then an electrical bonding connection must be added between the floor decking and building steel. These added connections need to be as short as possible and of sufficient surface area to be low impedance at high frequencies. High frequency bonding jumpers - Jumpers must be short, less than 500 mm (20 in) and good high frequency conductors. Thin, wide metal strips are best with length not more than three times width for best performance. Jumpers can be copper, aluminum, or steel. Steel has the advantage of not creating galvanic halfcells when bonded to other steel parts. Jumpers must make good electrical contact with both the enclosure and the signal reference structure. Welding is best. If a mechanical connection is used, each end should be fastened with two bolts or screws with star washers backed up by large diameter flat washers. Each enclosure must have two bonding jumpers of short, random lengths. Random lengths are used so that parallel bonding paths are of different quarter wavelength multiples. Do not fold bonding jumpers or make sharp bends. Metallic cable tray - System must be installed per NEC Article 318 with signal level spacing per the next section. This serve as a signal reference structure between remotely connected pieces of equipment. The large surface area of cable trays provides a low impedance path at high frequencies. Metal framing channel - Metal framing channel cable support systems also serves as part of the signal reference structure. Make certain that channels are well bonded to the equipment enclosure, cable tray, and each other, with large surface area connections to provide low impedance at high frequencies.
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Noise-sensitive cables - Try to run noise-sensitive cables tight against a vertical support to allow this support to serve as a reference plane. Cables that are extremely susceptible to noise should be run in a metallic conduit, preferably ferrous. Keep these cables tight against the inside walls of the metallic enclosure, and well away from higher-level cables. Power cables - Keep single-conductor power cables from the same circuit tightly bundled together to minimize interference with nearby signal cables. Keep 3-phase ac cables in a tight triangular configuration. Woven wire mesh - Woven wire mesh can serve as a high frequency signal reference grid for enclosures located on floors not accessible from below. Each adjoining section of mesh must be welded together at intervals not exceeding 500 mm (20 in) to create a continuous reference grid. The woven wire mesh must be bonded at frequent intervals to building structural members along the floor perimeter. Conduit terminal at cable trays - To provide the best shielding, conduits containing level L cables (see Leveling channels) should be terminated to the tray's side rails (steel solid bottom) with two locknuts and a bushing. Conduit should be terminated to ladder tray side rails with approved clamps. Where it is not possible to connect conduit directly to tray (such as with large conduit banks), conduit must be terminated with bonding bushings and bonded to tray with short bonding jumpers. Leveling channels - If the enclosure is mounted on leveling channels, bond the channels to the woven wire mesh with solid-steel wire jumpers of approximately the same gauge as the woven wire mesh. Bolt the enclosure to leveling steel, front and rear. Signal and power levels - See section, Cable Separation and Routing for guidelines. Solid-bottom tray - Use steel solid bottom cable trays with steel covers for lowlevel signals most susceptible to noise.
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Chapter 5 Installation and Configuration x 5-23
Level P
Level L Solid Bottom Tray
Enclosure
Bolt Leveling Channels Wire Mesh
Bond leveling channels to the woven wire mesh with solid steel wire jumpers of approximately the same gage as the wire mesh. Jumpers must be short, less than 200 mm (8 in). Weld to mesh and leveling steel at random intervals of 300 - 500 mm (12-20 in). Bolt the enclosure to the leveling steel, front and rear. See site specific GE Equipment Outline dwgs. Refer to Section 6 for examples.
Enclosure and Cable Tray Installation Guidelines
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Cable Separation and Routing This section provides recommended cabling practices to reduce electrical noise. These include signal/power level separation and cable routing guidelines. Note Electrical noise from cabling of various voltage levels can interfere with microprocessor-based control systems, causing a malfunction. If a situation at the installation site is not covered in this document, or if these guidelines cannot be met, please contact GE before installing the cable. Early planning enables the customer’s representatives to design adequate separation of embedded conduit. On new installations, sufficient space should be allowed to efficiently arrange mechanical and electrical equipment. On revamps, level rules should be considered during the planning stages to help ensure correct application and a more trouble-free installation.
Signal/Power Level Definitions Signal/power carrying cables are categorized into four defining levels: low, medium, high, and power. Each level can include classes.
Low-Level Signals (Level L) Low-level signals are designated as level L. In general these consist of: x
Analog signals 0 through ±50 V dc, B B
L3GenVolts
A L3BusVolts A>B AND B A A=B B
3
Trip_Mode1, CFG
Contact1, IO
L3SS_Comm, (SS)
A
Direct, CNST
A A=B B
Conditional, CNST
A A=B B
Trip1_En_Dir
Trip1_En_Cond
Trip1_En_Dir
Trip1_En_Cond
Trip1_Inhbt, SS
L3SS_Comm
L5Cont1_Trip, (SS) CONTACT1 TRIP
TDPU
TrpTimeDelay (sec.), CFG (J3, Contact1) L5Cont1_Trip
L86MR, SS
Trip1_Inhbt, SS
Inhbt_T1_Fdbk, (SS)
VPRO Protection Logic - Contact Inputs
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CONTACT INPUT TRIPS (CONT.): Trip_Mode2, CFG
Contact2, IO
Direct, CNST
A A=B B
Conditional, CNST
A A=B B
Trip2_En_Dir
Trip2_En_Cond
Trip2_En_Dir
Trip2_En_Cond
Trip2_Inhbt, SS
L3SS_Comm
L5Cont2_Trip, (SS) CONTACT2 TRIP
TDPU
TrpTimeDelay (sec.), CFG (J3, Contact2) L5Cont2_Trip
L86MR, SS
Trip2_Inhbt, SS
Inhbt_T2_Fdbk, (SS)
Trip_Mode3, CFG
Contact3, IO
Direct, CNST
A A=B B
Conditional, CNST
A A=B B
Trip3_En_Dir
Trip3_En_Cond
Trip3_En_Dir
Trip3_En_Cond
Trip3_Inhbt, SS
L3SS_Comm
L5Cont3_Trip, (SS) CONTACT3 TRIP
TDPU
TrpTimeDelay (sec.), CFG (J3, Contact3) L5Cont3_Trip
L86MR, SS
Trip3_Inhbt, SS
Inhbt_T3_Fdbk, (SS)
VPRO Protection Logic - Contact Inputs (continued)
GEH-6421H Mark VI Control System Guide Volume I
Chapter 8 Applications x 8-17
CONTACT INPUT TRIPS (CONT.): Trip_Mode4, CFG
Contact4, IO
Direct, CNST
A A=B B
Conditional, CNST
A A=B B
Trip4_En_Dir
Trip4_En_Cond
Trip4_En_Dir
Trip4_En_Cond
Trip4_Inhibit, SS
L5Cont4_Trip, (SS) CONTACT4 TRIP
TDPU
L3SS_Comm
TrpTimeDelay (sec.), CFG (J3, Contact4) L5Cont4_Trip
L86MR, SS
Trip4_Inhbt, SS
Inhbt_T4_Fdbk, (SS)
Trip_Mode5, CFG
Contact5, IO
Direct, CNST
A A=B B
Conditional, CNST
A A=B B
Trip5_En_Dir
Trip5_En_Cond
Trip5_En_Dir
Trip5_En_Cond
Trip5_Inhibit, SS
L3SS_Comm
L5Cont5_Trip, (SS) CONTACT5 TRIP
TDPU
TrpTimeDelay (sec.), CFG (J3, Contact5) L5Cont5_Trip
L86MR, SS
Trip5_Inhbt, SS
Inhbt_T5_Fdbk, (SS)
VPRO Protection Logic - Contact Inputs (continued)
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CONTACT INPUT TRIPS (CONT.): Trip_Mode6, CFG
Contact6, IO
Direct, CNST
A A=B B
Conditional, CNST
A A=B B
Trip6_En_Dir
Trip6_En_Cond
Trip6_En_Dir
Trip6_En_Cond
Trip6_Inhibit, SS
L3SS_Comm
L5Cont6_Trip, (SS) CONTACT6 TRIP
TDPU
TrpTimeDelay (sec.), CFG (J3, Contact4) L5Cont6_Trip
L86MR, SS
Trip6_Inhbt, SS
Inhbt_T6_Fdbk, (SS)
Trip_Mode7, CFG
Contact7, IO
Direct, CNST
A A=B B
Conditional, CNST
A A=B B
Trip7_En_Dir
Trip7_En_Cond
Trip7_En_Dir
Trip7_En_Cond
Trip7_Inhibit, SS
L3SS_Comm
L5Cont7_Trip, (SS) CONTACT7 TRIP
TDPU
TrpTimeDelay (sec.), CFG (J3, Contact5) L5Cont7_Trip
L86MR, SS
Trip7_Inhbt, SS
Inhbt_T7_Fdbk, (SS)
VPRO Protection Logic - Contact Inputs (continued)
GEH-6421H Mark VI Control System Guide Volume I
Chapter 8 Applications x 8-19
VPRO Protection Logic - Online Overspeed Test
OS1_Setpoint , SS
A
RPM
A-B OS_Setpoint, CFG (J5, PulseRate1)
|A|
A>B
B
RPM
A
A 1 RPM
OS1_SP_CfgEr System Alarm, if the two setpoints don't agree
B
A Min B OS_Setpoint_PR1
OS_Stpt_PR1 A
A
Mult
0.04
B OS_Tst_Delta CFG(J5, PulseRate1) RPM
A
A+B
Min
B
zero
B
OfflineOS1test, SS OnlineOS1
PulseRate1, IO
A A>=B
OS_Setpoint_PR1
OS1
B
OS1_Trip
OS1
Overspeed Trip
OS1_Trip
L86MRX
VPRO Protection Logic - Overspeed Trip, HP
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PR_Zero 1 0
PulseRate1, IO
Hyst
CFG
RPM
A PR1_Zero
AB B
PR1_Accel
S (Der)
A
PR1_Dec
AB Acc_Setpoint, CFG (J5,PulseRate1)
B
Dec1_Trip
PR1_DEC
Decel Trip Dec1_Trip
L86MR,SS
Acc_Trip, CFG (J5, PulseRate1) Enable
PR1_ACC
Acc1_Trip
Acc1_TrEnab Accel Trip
Acc1_Trip
L86MR,SS
*Note: where 100% is defined as the configured value of OS_Stpt_PR1 VPRO Protection Logic - Overspeed Trip, HP (continued)
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Chapter 8 Applications x 8-21
OS1_SP_CfgEr L5CFG1_Trip
L5CFG1_Trip
PR1_Zero
HP Config Trip
L86MR,SS PR1_Max_Rst
PR_Max_Rst PR1_Zero_Old
PR1_Zero
PR1_Zero
0.00 PR1_Max_Rst
Max
PR1_Max
PulseRate1
PR1_Zero
PR1_Zero_Old
VPRO Protection Logic - Overspeed Trip, HP (continued)
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OS2_Setpoint , SS
A
RPM
A-B OS_Setpoint, CFG
|A|
B
(J5, PulseRate2) RPM
A
A
OS2_SP_CfgEr
A>B 1 RPM
B
System Alarm, if the two setpoints don't agree
A Min B OS_Setpoint_PR2
OS_Stpt_PR2 A 0.04 OS_Tst_Delta CFG(J5, PulseRate2)
A
Mult
A
A+B
B
Min
B
RPM
zero
B
OfflineOS2test, SS OnlineOS2
PulseRate2, IO
A A>=B
OS_Setpoint_PR2
OS2
B
OS2_Trip
OS2
Overspeed Trip OS2_Trip
L86MR,SS
VPRO Protection Logic - Overspeed LP
GEH-6421H Mark VI Control System Guide Volume I
Chapter 8 Applications x 8-23
PulseRate2, IO A
PR2_Zero
AB B
S (Der)
PR2_Accel
A
PR2_Dec
AB Acc_Setpoint, CFG (J5,PulseRate2)
B
Dec2_Trip
PR2_DEC
Decel Trip LP Dec2_Trip
L86MR,SS
Acc_Trip, CFG (J5, PulseRate2) PR2_ACC
Acc2_Trip
PR2_MIN
Enable Acc2_TrEnab
Acc2_Trip Accel Trip LP
L86MR,SS
*Note: where 100% is defined as the configured value of OS_Stpt_PR2 VPRO Protection Logic - Overspeed LP (continued)
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OS2_SP_CfgEr
L5CFG2_Trip
PR2_Zero
LP Config Trip
L5CFG2_Trip L86MR,SS
PR2_Max_Rst
PR_Max_Rst PR2_Zero
PR2_Zero_Old
PR2_Zero
0.00 PR2_Max_Rst
Max
PR2_Max
PulseRate2 PR2_Zero_Old
PR2_Zero
PR1_MIN LPShaftLocked
PR2_Zero
LockRotorByp
LPShaftLocked
L86MR, SS
VPRO Protection Logic - Overspeed LP (continued)
GEH-6421H Mark VI Control System Guide Volume I
Chapter 8 Applications x 8-25
OS3_Setpoint , SS
A
RPM
A-B OS_Setpoint, CFG (J5, PulseRate3)
|A|
B
RPM
A
A
OS3_SP_CfgEr
A>B 1 RPM
B
System Alarm, if the two setpoints don't agree
A Min B OS_Stpt_PR3 A
A
Mult
A
B
Min
0.04 OS_Tst_Delta CFG(J5, PulseRate3)
OS_Setpoint_PR3
RPM
zero
A+B B
B
OfflineOS3tst, SS OnlineOS3tst, SS
PulseRate3, IO
A A>=B
OS_Setpoint_PR3
OS3
B
OS3_Trip
OS3
OS3_Trip
Overspeed Trip L86MRX
VPRO Protection Logic - Overspeed IP
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PulseRate3, IO A
PR3_Zero
AB B
PR3_Accel
S (Der)
A
PR3_Dec
AB Acc_Setpoint, CFG (J5,PulseRate3)
B
Dec3_Trip
PR3_DEC
Decel Trip IP Dec3_Trip
L86MR,SS
Acc_Trip, CFG (J5, PulseRate3) PR3_ACC
Acc3_Trip
PR3_MIN
Enable Acc3_TrEnab
Acc3_Trip Accel Trip IP
L86MR,SS
*Note: where 100% is defined as the configured value of OS_Stpt_PR2 VPRO Protection Logic - Overspeed IP (continued)
GEH-6421H Mark VI Control System Guide Volume I
Chapter 8 Applications x 8-27
OS3_SP_CfgEr L5CFG3_Trip
L5CFG3_Trip
PR3_Zero
IP Config Trip
L86MR,SS PR3_Max_Rst
PR_Max_Rst PR3_Zero_Old
PR3_Zero
PR3_Zero
0.00 PR3_Max_Rst
Max
PR3_Max
PulseRate3
PR3_Zero
PR3_Zero_Old
VPRO Protection Logic - Overspeed IP (continued)
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,CFG ,SS (SS)
== == ==
Notes: VPRO config data from signal space to signal space
TC1 (SS) TC2 (SS)
TC_MED(SS )
MED
TC3 (SS) Zer o OTSPBias(SS)
MA X
OTBias,SS L3SS_Com m OTBias_RampP,CF G OTBias_RampN,CF G OTBias_Dflt,CFG
ME D
A A+B
A
B
A-B B 1
Z
TC_ME D Overtemp_Trip,CF G
A A-B
OTSPBias
A A>= B B
B
L26T
OTSetpoint(SS)
OT_Trip_Enable,CF G OT_Trip (SS)
L26T
OT_Trip
L86MR,S S
VPRO Protection Logic - Over-Temperature
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Chapter 8 Applications x 8-29
RPM_94% RatedRPM_TA, CFG (VPRO, Config)
RPM_103.5% RPM_106% RPM_116% RPM_1%
Calc Trip Anticipate Speed references
RPM_116% OS1_TATrpSp,SS RPM
A AB
EVA M.W. Rate Out of Limit
F
B 0.0
P.U EVA Rate Limit (Downloaded) Negative Number
* EVA Test Functional Test
* Ext. EVA Dropout Delay #2
* Ext. EVA Enable IO_Cfg Download
OR
*EVA Perm. E
AND
S
Latch R 1
F
EVA Enable (Downloaded) IO_Cfg
Fixed 10 msec
OR
AND
Pickup Delay 1
Pickup Delay 1
Dropout Delay #1
* EVA Event
Fixed 5 sec. EVA Control EVA Event
G
Delay time (Downloaded) IO_Cfg
* Signal to/from Signal Space
Fixed 15 msec
EVA Valve Actuation Logic
GEH-6421H Mark VI Control System Guide Volume I
Chapter 8 Applications x 8-43
Intercept Valve Trigger The peak speed following rejection of 10% or greater rated load cannot be maintained within limits on some units by the normal speed and servo control action. Approximately 70% of turbine power is generated in the reheat and low-pressure turbine sections (the boiler re-heater volume represents a significant acceleration energy source). Fast closing of the IVs can therefore quickly reduce turbine power and peak overspeed. The action fulfills the first basic function of normal overspeed control, limiting peak speed. The Intercept Valve Trigger (IVT) signal is produced in the controller by the IVT algorithm and associated sequencing, see the previous figure, EVA Valve Actuation Logic.
Early Valve Actuation (EVA) The EVA function may be implemented on sites where instability, such as loss of synchronization, presents a problem. EVA closes the IVs for approximately one second upon sensing a fault that is not a load rejection. This action reduces the available mechanical power, thereby inhibiting the loss of synchronization that can occur as a result of increased machine angle (unbalance between mechanical and electrical power). If the fault persists, the generator loses synchronization and the turbine is tripped by the overspeed control or out-of-step relaying. The EVA is enabled in the toolbox by selecting Enable for the EVA_Enab parameter. The conditions for EVA action are as follows: x
The difference between mechanical power (reheat pressure) and electrical power (megawatts) exceeds the configured EVA unbalance threshold (EVA_Unbal) input value.
x
Electrical power (megawatts) decreases at a rate equivalent to (or greater than) one of three rates configured for EVA megawatt rate threshold (EVA_Rate). This value is adjustable according to three settings: HIgh, MEdium, and LOw. These settings correspond to 50, 35, and 20 ms rates respectively.
Note The megawatt signal is derived from voltage and current signals provided by customer-supplied transformers located on the generator side of the circuit breaker. The EVA_Unbal value represents the largest fault a particular generator can sustain without losing synchronization. Although the standard setting for this constant is 70%, it may be adjusted up or down 0 to 2 per unit from the toolbox. All EVA events are annunciated.
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Fast Overspeed Trip in VTUR In special cases where a faster overspeed trip system is required, the VTUR Fast Overspeed Trip algorithms may be enabled. The system employs a speed measurement algorithm using a calculation for a predetermined tooth wheel. Two overspeed algorithms are available in VTUR as follows: x
PR_Single. This uses two redundant VTUR boards by splitting up the two redundant PR transducers, one to each board.
x
PR_Max. This uses one VTUR board connected to the two redundant PR transducers. PR_Max allows broken shaft and deceleration protection without the risk of a nuisance trip if one transducer is lost.
The fast trips are linked to the output trip relays with an OR-gate as shown in the following figures. VTUR computes the overspeed trip, not the controller, so the trip is very fast. The time from the overspeed input to the completed relay dropout is 30 msec or less.
GEH-6421H Mark VI Control System Guide Volume I
Chapter 8 Applications x 8-45
Input, PR1
Input Config. param.
PR1Type, PR1Scale
Signal Space Inputs
VTUR, Firmware Scaling
RPM
2 PulseRate2 PulseRate3 PulseRate4
PulseRate1
d RPM/sec Accel1 dt RPM PulseRate2 ------ Four Pulse Rate Circuits ------RPM/sec Accel2 Accel1 PulseRate3 Accel2 RPM Accel3 RPM/sec Accel3 Accel4 RPM PulseRate4 RPM/sec Accel4 Fast Overspeed Protection
FastTripType
PR_Single
PR1Setpoint PR1TrEnable PR1TrPerm PR2Setpoint PR2TrEnable PR2TrPerm PR3Setpoint PR3TrEnable PR3TrPerm
PR4Setpoint PR4TrEnable PR4TrPerm InForChanA AccASetpoint
PulseRate1 A A>B B
S
PulseRate2 A A>B B
S
AccBSetpoint
FastOS2Trip
R PulseRate3 A A>B B PulseRate4 A A>B B
S R
FastOS3Trip
S
FastOS4Trip
R Accel1 Accel2 Input Accel3 cct. Accel4 select
AccelA
A A>B B
R
A A>B B
R
S
AccelAEnab AccelAPerm InForChanB
FastOS1Trip
R
Accel1 Accel2 Input Accel3 cct. Accel4 select
AccelB
AccATrip
S
AccBTrip
AccelBEnab AccelBPerm ResetSys, VCMI, Mstr
PTR1 PTR1_Output PTR2 PTR2_Output PTR3 PTR3_Output PTR4 PTR4_Output PTR5 PTR5_Output PTR6 PTR6 Output
OR Primary Trip Relay, normal Path, True= Run Primary Trip Relay, normal Path, True= Run
AND
Fast Trip Path False = Run
True = Run
Output, J4,PTR1
AND True = Run Output, J4,PTR2
-------------Total of six circuits -----
True = Run
Output, J4,PTR3
True = Run
Output, J4A,PTR4
True = Run
Output, J4A,PTR5
True = Run
Output, J4A,PTR6
Fast Overspeed Algorithm, PR-Single
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Input Config. Input, PR1 param. PR1Type, 2 PR1Scale
VTUR, Firmware
Scaling PulseRate1
PulseRate2
RPM
Accel1 Accel2 Accel3 Accel4
PulseRate3 PulseRate4 FastTripType PR_Max
RPM/sec RPM RPM/sec RPM RPM/sec RPM RPM/sec
d dt ------ Four Pulse Rate Circuits -------
Signal Space inputs PulseRate1 Accel1 PulseRate2 Accel2 PulseRate3 Accel3 PulseRate4 Accel4
Fast Overspeed Protection
DecelPerm DecelEnab DecelStpt InForChanA InForChanB Accel1 Accel2 Accel3 Accel4 PulseRate1 PulseRate2 PulseRate3 PulseRate4
Input cct. Select for AccelA and AccelB
AccelA AccelB
A AB B
PulseRate1 PulseRate2
MAX
FastOS1Stpt FastOS1Enab FastOS1Perm
S
DecelTrip
R
PR1/2Max A A>B B
S
FastOS1Trip
R PR3/4Max PulseRate3
FastOS2Stpt FastOS2Enab FastOS2Perm
PulseRate4
A A>B B
S
FastOS2Trip
R
PR1/2Max PR3/4Max DiffSetpoint
MAX
A |A-B| B
N/C N/C A A>B B
S
FastDiffTrip
R
DiffEnab DiffPerm ResetSys, VCMI, Mstr
PTR1
OR
Primary Trip Relay, normal Path, True= Run
AND
Primary Trip Relay, normal Path, True= Run
AND
PTR1_Output PTR2 PTR2_Output PTR3 PTR3_Output PTR4 PTR5 PTR5_Output PTR6 PTR6_Output
FastOS3Trip FastOS4Trip
-------------Total of six circuits ---------
Fast Trip Path False = Run True = Run Output, J4,PTR1
True = Run
Output, J4,PTR2
True = Run
Output, J4,PTR3
True = Run
Output, J4A,PTR4
True = Run
Output, J4A,PTR5
True = Run
Output, J4A,PTR6
Fast Overspeed Algorithm, PR-Max
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Chapter 8 Applications x 8-47
Compressor Stall Detection Gas turbine compressor stall detection is included with the VAIC firmware and is executed at a rate of 200 Hz. There is a choice of two stall algorithms and both use the first four analog inputs, scanned at 200 Hz. One algorithm is for small LM gas turbines and uses two pressure transducers. The other algorithm is for heavy-duty gas turbines and uses three pressure transducers, refer to the figures below. Real-time inputs are separated from the configured parameters for clarity. The parameter CompStalType selects the type of algorithm required, either two transducers or three. PS3 is the compressor discharge pressure, and a drop in this pressure (PS3 drop) is an indication of a possible compressor stall. In addition to the drop in pressure, the algorithm calculates the rate of change of discharge pressure, dPS3dt, and compares these values with configured stall parameters (KPS3 constants). Refer to the figures below. The compressor stall trip is initiated by VAIC, and the signal is sent to the controller where it is used to initiate a shutdown. The shutdown signal can be used to set all the fuel shut-off valves (FSOV) through the VCRC and TRLY or DRLY board.
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Input Config param.
Input, cctx* Low_Input, Low_Value, High_Input, High Value SysLim1Enabl, Enabl SysLim1Latch, Latch SysLim1Type, >= SysLimit1, xxxx ResetSys, VCMI, Mstr
VAIC, 200 Hz scan rate
*Note: where x, y, represent any two of the input circuits 1 thru 4.
AnalogInx*
Scaling 4
Sys Lim Chk #1
SysLimit1_x*
4
Sys Lim Chk #2 4
SysLimit2_x*
SysLim2Enabl, Enabl SysLim2Latch, Latch SysLim2Type, B B
DeltaFault PS3Sel Selection Definition
SelMode
If PS3B_Fail & not PS3A_Fail then PS3Sel = PS3A; ElseIf PS3A_Fail & not PS3B_Fail then PS3Sel = PS3B; ElseIf DeltaFault then PS3Sel = Max (PS3A, PS3B) ElseIf SelMode = Avg then PS3Sel = Avg (PS3A, PS3B) ElseIf SelMode = Max then PS3Sel = Max (PS3A, PS3B) Else then PS3SEL = old value of PS3SEL
Max PS3A PS3B PS3A_Fail PS3B_Fail
d DPS3DTSel __ dt PressRateSel X
AND
stall_set S Latch R
TD
-DPS3DTSel Mid
A
X
PS3_Fail A
AND
A>B
A+B
-DPS3DTSel
-1 TimeDelay KPS3_Drop_Mx KPS3_Drop_Mn KPS3_Drop_I KPS3_Drop_S
PressSel
PS3Sel
B
B
z-1
PS3Sel
PS3i
KPS3_Delta_S
A
A+B
KPS3_Delta_I KPS3_Delta_Mx KPS3_Drop_L CompStalPerm
stall_timeout X MIN
B
delta_ref A
delta AB AND PS3i_Hold B
stall_delta
CompStall
B
A
PS3Sel BA-B
stall_permissive
MasterReset, VCMI, Mstr
Small (LM) Gas Turbine Compressor Stall Detection Algorithm
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Chapter 8 Applications x 8-49
VAIC, 200 Hz scan rate
Input Config. param.
Scaling Input, cctx* Low_Input, Low_Value, High_Input, High Value 4 SysLim1Enabl, Enabl 4 SysLim1Latch, Latch SysLim1Type, >= SysLimit1, xxxx ResetSys, VCMI, Mstr
*Note: where x, y, z, represent any three of the input circuits 1 thru 4.
Signal Space inputs AnalogInx*
Sys Lim Chk #1 SysLimit1_x*
Sys Lim Chk #2
SysLimit2_x*
4 SysLim2Enabl, Enabl SysLim2Latch, Latch SysLim2Type, B
A+B B
X
B
z-1
PS3Sel
PS3i
stall_timeout X
stall_set
KPS3_Delta_S A
A+B
KPS3_Delta_I
B
KPS3_Delta_Mx
MIN
AND
delta_ref A
delta AB
KPS3_Drop_L
B
CompStalPerm
AND
A
PS3i_Hold PS3Sel
A-B B
stall_permissive
MasterReset, VCMI, Mstr
Heavy Duty Gas Turbine Compressor Stall Detection Algorithm
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GEH-6421H Mark VI Control System Guide Volume I
Rate of Change of Pressure- dPS3dt, psia/sec
180 0 A. B. C. D.
140 0
B. Delta PS3 drop (PS3 initial - PS3 actual) , DPS3, psid
200 0 25 0
D
KPS3_Drop_S KPS3_Drop_I KPS3_Drop_Mn KPS3_Drop_Mx
20 0 A
120 0 100 0
15 0
80 0 60 0
10 0 G
40 0
E
20 C 0
5 0 E. KPS3_Delta_S F. KPS3_Delta_I G. KPS3_Delta_Mx
B 0 F -200 0
100
200
300
400
500
600
0 700
Initial Compressor Discharge Pressure PS3 Configurable Compressor Stall Detection Parameters
The variables used by the stall detection algorithm are defined as follows: PS3
Compressor discharge pressure
PS3I
Initial PS3
KPS3_Drop_S
Slope of line for PS3I versus dPS3dt
KPS3_Drop_I
Intercept of line for PS3I versus dPS3dt
KPS3_Drop_Mn
Minimum value for PS3I versus dPS3dt
KPS3_Drop_Mx
Maximum value for PS3I versus dPS3dt
KPS3_Delta_S
Slope of line for PS3I versus Delta PS3 drop
KPS3_Delta_I
Intercept of line for PS3I versus Delta PS3 drop
KPS3_Delta_Mx
Maximum value for PS3I versus Delta PS3 drop
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Chapter 8 Applications x 8-51
Ground Fault Detection Sensitivity Ground fault detection on the floating 125 V dc power bus is based upon monitoring the voltage between the bus and the ground. The bus voltages with respect to ground are normally balanced (in magnitude), that is the positive bus to ground is equal to the negative bus to ground. The bus is forced to the balanced condition by the bridging resistors, Rb as shown in the following figure. Bus leakage (or ground fault) from one side will cause the bus voltages with respect to ground to be unbalanced. Ground fault detection is performed by the VCMI using signals from the PDM. Refer to Volume II of this System Guide. P125 Vdc Rf
Rb
Vout,Pos Monitor1
Grd Fault
Jumper Grd
Vout,Neg Monitor2
Rb N125 Vdc
Electrical Circuit Model Rb/2 Vbus/2
Rf
Vout, Bus Volts wrt Ground
Ground Fault on Floating 125 V dc Power Bus
There is a relationship between the bridge resistors, the fault resistance, the bus voltage, and the bus to ground voltage (Vout) as follows: Vout = Vbus*Rf / [2*(Rf + Rb/2)] Therefore the threshold sensitivity to ground fault resistance is as follows: Rf = Vout*Rb / (Vbus – 2*Vout). The ground fault threshold voltage is typically set at 30 V, that is Vout = 30 V. The bridging resistors are 82 K each. Therefore, from the formula above, the sensitivity of the control panel to ground faults, assuming it is on one side only, is as shown in the following figure. Note On Mark V, the bridging resistors are 33 K each so different Vout values result.
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Sensitivity to Ground Faults
Vbus Bus voltage
Vout - Measured Bus to ground voltage (threshold)
Rb (Kohms) bridge resistors (balancing)
Rf (Kohms) fault resistor
Control System
105
30
82
55
Mark VI
125
30
82
38
Mark VI
140
30
82
31
Mark VI
105
19
82
23
Mark VI
125
19
82
18
Mark VI
140
19
82
15
Mark VI
105
10
82
10
Mark VI
125
10
82
8
Mark VI
140
10
82
7
Mark VI
105
30
33
22
Mark V
125
30
33
15
Mark V
140
30
33
12
Mark V
The results for the case of 125 V dc bus voltage with various fault resistor values is shown in the following figure.
Fault, Rf
40.0 Fault Resistance (Rf) Vs Threshold Voltage (Vout) at 125 V dc on Mark VI
30.0 20.0 10.0 0.0 0
10
20
30
Voltage, Vout Threshold Voltage as Function of Fault Resistance
Analysis of Results On Mark VI, when the voltage threshold is configured to 30 V and the voltage bus is 125 V dc, the fault threshold is 38 :. When the voltage threshold is configured to 17 V and the voltage bus is 125 V dc, the fault threshold is 15 :. The sensitivity of the ground fault detection is configurable. Balanced bus leakage decreases the sensitivity of the detector.
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Notes
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Glossary of Terms application code Software that controls the machines or processes, specific to the application.
ARCNet Attached Resource Computer Network. A LAN communications protocol developed by Datapoint Corporation.The physical (coax and chip) and datalink (token ring and board interface) layer of a 2.5 MHz communication network which serves as the basis for DLAN+.
ASCII American Standard for Code for Information Interchange (ASCII). An 8-bit code used for data.
Asynchronous Device Language (ADL) An application layer protocol used for I/O communication on IONet.
attributes Information, such as location, visibility, and type of data that sets something apart from others. In signals, an attribute can be a field within a record.
Balance of Plant (BOP) Plant equipment other than the turbine that needs to be controlled.
Basic Input/Output System (BIOS) Performs the controller boot-up, which includes hardware self-tests and the file system loader. The BIOS is stored in EEPROM and is not loaded from the toolbox.
baud A unit of data transmission. Baud rate is the number of bits per second transmitted.
Bently Nevada A manufacturer of shaft vibration monitoring equipment.
bit Binary Digit. The smallest unit of memory used to store only one piece of information with two states, such as One/Zero or On/Off. Data requiring more than two states, such as numerical values 000 to 999, requires multiple bits (see Word).
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block Instruction blocks contain basic control functions, which are connected together during configuration to form the required machine or process control. Blocks can perform math computations, sequencing, or continuous control. The toolbox receives a description of the blocks from the block libraries.
board Printed wiring board.
Boolean Digital statement that expresses a condition that is either True or False. In the toolbox, it is a data type for logical signals.
Bus An electrical path for transmitting and receiving data.
byte A group of binary digits (bits); a measure of data flow when bytes per second.
CIMPLICITY Operator interface software configurable for a wide variety of control applications.
COM port Serial controller communication ports (two). COM1 is reserved for diagnostic information and the Serial Loader. COM2 is used for I/O communication.
Computer Operator Interface (COI) Interface that consists of a set of product and application specific operator displays running on a small cabinet computer hosting Embedded Windows NT.
configure To select specific options, either by setting the location of hardware jumpers or loading software parameters into memory.
Current Transformer (CT) Measures current in an ac power cable.
Cyclic Redundancy Check (CRC) Detects errors in Ethernet and other transmissions.
data server A computer which gathers control data from input networks and makes the data available to computers on output networks.
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GEH-6421H Mark VI Control System Guide Volume I
dead band A range of values in which the incoming signal can be altered without changing the output response.
device A configurable component of a process control system.
DIN-rail European standard mounting rail for electronic modules.
Distributed Control System (DCS) Control system, usually applied to control of boilers and other process equipment.
DLAN+ GE Energy LAN protocol, using an ARCNET controller chip with modified ARCNET drivers. A communication link between exciters, drives, and controllers, featuring a maximum of 255 drops with transmissions at 2.5 MBPS.
Ethernet LAN with a 10/100 M baud collision avoidance/collision detection system used to link one or more computers together. Basis for TCP/IP and I/O services layers that conform to the IEEE 802.3 standard, developed by Xerox, Digital, and Intel.
Ethernet Global Data (EGD) Control network and protocol for the controller. Devices share data through EGD exchanges (pages).
EX2000 (Exciter) Latest version of GE generator exciter control; regulates the generator field current to control the generator output voltage.
fanned input An input to the terminal board which is connected to all three TMR I/O boards.
fault code A message from the controller to the HMI indicating a controller warning or failure.
Finder A subsystem of the toolbox for searching and determining the usage of a particular item in a configuration.
firmware The set of executable software that is stored in memory chips that hold their content without electrical power, such as EEPROM.
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Glossary of Terms x G-3
flash A non-volatile programmable memory device.
forcing Setting a live signal to a particular value, regardless of the value blockware or I/O is writing to that signal.
frame rate Basic scheduling period of the controller encompassing one complete inputcompute-output cycle for the controller. It is the system-dependent scan rate.
function The highest level of the blockware hierarchy, and the entity that corresponds to a single .tre file.
gateway A device that connects two dissimilar LANs or connects a LAN to a wide-area network (WAN), computer, or a mainframe. A gateway can perform protocol and bandwidth conversion.
Graphic Window A subsystem of the toolbox for viewing and setting the value of live signals.
health A term that defines whether a signal is functioning as expected.
Heartbeat A signal emitted at regular intervals by software to demonstrate that it is still active.
hexadecimal (hex) Base 16 numbering system using the digits 0-9 and letters A-F to represent the decimal numbers 0-15. Two hex digits represent 1 byte.
I/O Input/output interfaces that allow the flow of data into and out of a device.
I/O drivers Interface the controller with input/output devices, such as sensors, solenoid valves, and drives, using a choice of communication networks.
I/O mapping Method for moving I/O points from one network type to another without needing an interposing application task.
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GEH-6421H Mark VI Control System Guide Volume I
initialize To set values (addresses, counters, registers, and such) to a beginning value prior to the rest of processing.
Innovation Series Controller A process and logic controller used for several types of GE industrial control systems.
insert Adding an item either below or next to another item in a configuration, as it is viewed in the hierarchy of the Outline View of the toolbox.
instance Update an item with a new definition.
IONet The Mark VI I/O Ethernet communication network (controlled by the VCMIs)
IP Address The address assigned to a device on an Ethernet communication network.
logical A statement of a true sense, such as a Boolean.
macro A group of instruction blocks (and other macros) used to perform part of an application program. Macros can be saved and reused.
Mark VI Turbine Controller A controller hosted in one or more VME racks that perform turbine-specific speed control, logic, and sequencing.
median The middle value of three values; the median selector picks the value most likely to be closest to correct.
Modbus A serial communication protocol developed by Modicon for use between PLCs and other computers.
module A collection of tasks that have a defined scheduling period in the controller.
non-volatile The memory specially designed to store information even when the power is off.
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Glossary of Terms x G-5
online Online mode provides full CPU communications, allowing data to be both read and written. It is the state of the toolbox when it is communicating with the system for which it holds the configuration. Also, a download mode where the device is not stopped and then restarted.
pcode A binary set of records created by the toolbox, which contain the controller application configuration code for a device. Pcode is stored in RAM and Flash memory.
period The time between execution scans for a Module or Task. Also a property of a Module that is the base period of all of the Tasks in the Module.
pin Block, macro, or module parameter that creates a signal used to make interconnections.
Plant Data Highway (PDH) Ethernet communication network between the HMI Servers and the HMI Viewers and workstations
Potential Transformer (PT) Measures voltage in a power cable.
Power Distribution Module (PDM) The PDM distributes 125 V dc and 115 V ac to the VME racks and I/O terminal boards.
Power Load Unbalance (PLU) Detects a load rejection condition which can cause overspeed.
product code (runtime) Software stored in the controller’s Flash memory that converts application code (pcode) to executable code.
PROFIBUS An open fieldbus communication standard defined in international standard EN 50 170 and is supported in simplex Mark VI systems.
Programmable Logic Controller (PLC) Designed for discrete (logic) control of machinery. It also computes math (analog) function and performs regulatory control.
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GEH-6421H Mark VI Control System Guide Volume I
Proximitor Bently Nevada's proximity probes used for sensing shaft vibration.
QNX A real time operating system used in the controller.
realtime Immediate response, referring to process control and embedded control systems that must respond instantly to changing conditions.
reboot To restart the controller or toolbox.
Redundant Power Supply Module (RPSM) IS2020RPSM Redundant Power Supply Module for VME racks that mounts on the side of the control rack instead of the power supply. The two power supplies that feed the RPSM are mounted remotely.
register page A form of shared memory that is updated over a network. Register pages can be created and instanced in the controller and posted to the SDB.
Relay Ladder Diagram (RLD) A ladder diagram that represents a relay circuit. Power is considered to flow from the left rail through contacts to the coil connected at the right.
resources Also known as groups. Resources are systems (devices, machines, or work stations where work is performed) or areas where several tasks are carried out. Resource configuration plays an important role in the CIMPLICITY system by routing alarms to specific users and filtering the data users receive.
runtime See product code.
runtime errors Controller problems indicated on the front cabinet by coded flashing LEDS, and also in the Log View of the toolbox.
sampling rate The rate at which process signal samples are obtained, measured in samples/second.
Sequence of Events (SOE) A high-speed record of contact closures taken during a plant upset to allow detailed analysis of the event.
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Glossary of Terms x G-7
Serial Loader Connects the controller to the toolbox computer using the RS-232C COM ports. The Serial Loader initializes the controller flash file system and sets its TCP/IP address to allow it to communicate with the toolbox over the Ethernet.
server A computer which gathers data over the Ethernet from plant devices, and makes the data available to computer-based operator interfaces known as viewers.
signal The basic unit for variable information in the controller.
simplex Operation that requires only one set of control and I/O, and generally uses only one channel. The entire Mark VI control system can operate in simplex mode, or individual VME boards in an otherwise TMR system can operate in implex mode.
simulation Running a system without all of the configured I/O devices by modeling the behavior of the machine and the devices in software.
Software Implemented Fault Tolerance (SIFT) A technique for voting the three incoming I/O data sets to find and inhibit errors. Note that Mark VI also uses output hardware voting.
stall detection Detection of stall condition in a gas turbine compressor.
static starter This runs the generator as a motor to bring a gas turbine up to starting speed.
Status_S GE proprietary communications protocol that provides a way of commanding and presenting the necessary control, configuration, and feedback data for a device. The protocol over DLAN+ is Status_S. It can send directed, group, or broadcast messages.
Status_S pages Devices share data through Status_S pages. They make the addresses of the points on the pages known to other devices through the system database.
symbols Created by the toolbox and stored in the controller, the symbol table contains signal names and descriptions for diagnostic messages.
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GEH-6421H Mark VI Control System Guide Volume I
task A group of blocks and macros scheduled for execution by the user.
TCP/IP Communication protocols developed to inter-network dissimilar systems. It is a de facto UNIX standard, but is supported on almost all systems. TCP controls data transfer and IP provides the routing for functions, such as file transfer and e-mail.
time slice Division of the total module scheduling period. There are eight slices per single execution period. These slices provide a means for scheduling modules and tasks to begin execution at different times.
toolbox A Windows-based software package used to configure the Mark VI controllers, also exciters and drives.
trend A time-based plot to show the history of values, similar to a recorder, available in the Turbine Historian and the toolbox.
Triple Module Redundancy (TMR) An operation that uses three identical sets of control and I/O (channels R, S, and T) and votes the results.
Unit Data Highway (UDH) Connects the Mark VI controllers, static starter control system, excitation control system, PLCs, and other GE provided equipment to the HMI Servers.
validate Makes certain that toolbox items or devices do not contain errors, and verifies that the configuration is ready to be built into pcode.
Windows NT Advanced 32-bit operating system from Microsoft for 386-based computers and above.
word A unit of information composed of characters, bits, or bytes, that is treated as an entity and can be stored in one location. Also, a measurement of memory length, usually 4, 8, or 16-bits long.
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Notes
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GEH-6421H Mark VI Control System Guide Volume I
Index A
F
Acronyms and Abbreviations 1-3 Alarms Overview 7-6 ANSI 4-1 Application Code 8-4
Fault Detection 8-52 Fiber-Optic Cables 3-27 firmware 2-12
B Building Grounding System 5-18
C Cable Separation and Routing 5-25 Cable Specifications 5-31 CIMPLICITY 6-4 Communications 3-10, 3-14 Code Download 5-46 Components 2-1, 3-27 Computer Operator Interface (COI) 2-3, 6-7 Connecting the System 5-35 Command action 2-32 Control Cabinet 2-1 Control Module 2-6 Contaminants 4-7 Control and Protection 2-21 Control Layer 3-3 Controller 2-9
D Data Highway Ethernet Switches 3-6 Data Highways 3-4 Designated Controller 2-25 Diagnostic Alarms 7-9 Disagreement Detector 2-32
E Early Planning 5-2 EGD 3-12 Electrical 4-2 Elevation 4-7 Enterprise Layer 3-1 Environment 4-5 Equipment Grounding 5-17 Ethernet Global Data (EGD) 3-12 Ethernet GSM 3-22 Ethernet Modbus Slave 3-15 Excitation Control system 2-5
GEH-6421H Mark VI Control System Guide Volume I
G GE Installation Documents 5-2 Generator Protection 2-15 Grounding 5-17 Ground Fault Detection 8-52
H How To Get Help 1-3 Human-Machine Interface (HMI) 2-3
I I/O Cabinets 2-1 I/O boards 2-12 interface modules 2-1 Input Processing 2-28 Installation Support 5-1 Installation Support Drawings 5-12 Interface Features 6-7 IONet 2-11, 3-9 IP Address 3-8
L Levels of Redundancy 2-20 Link to Distributed Control System (DCS) 2-4
M MTBFO 2-37 Median Value Analog Voting 2-31 Modbus 3-14
N NEMA 1-4 Network Overview 3-1
O Online Repair 2-36 Output Processing 2-26
Index x I-1
P Plant Data Highway (PDH) 2-4, 3-4 Power Requirements 5-11 Process Alarms 7-7
Q QNX 2-19
R Related Documents 1-2
S SOE 1-4, 3-22, 6-9 Startup Checks 5-41 State Exchange 2-30 Storage 4-5 System Components 2-1
T TMR 2-22, 2-36 Totalizers 7-11 Turbine Historian 6-8
U UDH Communicator 2-25 Unit Data Highway (UDH) 2-2, 3-5
V Vibration 4-8 Voting 2-31, 3-11
W Windows NT G-9
I-2 x Index
GEH-6421H Mark VI Control System Guide Volume I
g GE Energy
General Electric Company 1501 Roanoke Blvd. Salem, VA 24153-6492 USA +1 540 387 7000 www.geenergy.com
GEH-6421 Vol I 041004
GE Power Systems
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM SPEEDTRONIC Mark VI Control contains a number of control, protection and sequencing systems designed for reliable and safe operation of the gas turbine. It is the objective of this chapter to describe how the gas turbine control requirements are met, using simplified block diagrams and one–line diagrams of the SPEEDTRONIC Mark VI control, protection, and sequencing systems. A generator drive gas turbine is used as the reference.
celeration, speed, temperature, shutdown, and manual control functions illustrated in Figure 1. Sensors monitor turbine speed, exhaust temperature, compressor discharge pressure, and other parameters to determine the operating conditions of the unit. When it is necessary to alter the turbine operating conditions because of changes in load or ambient conditions, the control modulates the flow of fuel to the gas turbine. For example, if the exhaust temperature tends to exceed its allowable value for a given operating condition, the temperature control system reduces the fuel supplied to the turbine and thereby limits the exhaust temperature.
CONTROL SYSTEM Basic Design Control of the gas turbine is done by the startup, acTO CRT DISPLAY
FUEL TEMPERATURE
TO CRT DISPLAY FSR MINIMUM VALUE SELECT LOGIC
SPEED
ACCELERATION RATE
FUEL SYSTEM
TO TURBINE TO CRT DISPLAY
START UP SHUT DOWN MANUAL
id0043
Figure 1 Simplified Control Schematic
Operating conditions of the turbine are sensed and utilized as feedback signals to the SPEEDTRONIC control system. There are three major control loops – startup, speed, and temperature – which may be in control during turbine operation. The output of these control loops is connected to a minimum value gate circuit as shown in Figure 1. The secondary control Fund_Mk_VI
modes of acceleration, manual FSR, and shutdown operate in a similar manner. Fuel Stroke Reference (FSR) is the command signal for fuel flow. The minimum value select gate connects the output signals of the six control modes to the FSR controller; the lowest FSR output of the six 1
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems
LOGIC
FSRSU
CQTC
FSR LOGIC
TNHAR
FSRACC
ACCELERATION CONTROL
FSRMAN
MANUAL FSR
TNH
TNH
START-UP CONTROL
TNHAR FSRMIN
LOGIC
FSR
FSRSU FSRACC
FSRC
FSRMAN FSRSD
MIN GATE
FSRN
FSR
FSRT
LOGIC TNHCOR
FSRSD
FSRC
FSRMIN
FSR
CQTC
SHUTDOWN CONTROL
FSRMIN
SPEED CONTROL TTUR VTUR PR/D
77NH
LOGIC
TNR
LOGIC
TNRI
LOGIC TNH FSRN
TNR
TNRI
ISOCHRONOUS ONLY
TEMPERATURE CONTROL LOGIC
96CD
TBAI VAIC A/D
TTRX TTRX
FSR
FSRT LOGIC
TBTC VTCC TTXD
TTXM
TTXD
A/D
FSR
TTXM
MEDIAN
id0038V
Figure 2 Block Diagram – Control Schematic
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
2
Fund_Mk_VI
GE Power Systems control loops is allowed to pass through the gate to the fuel control system as the controlling FSR. The controlling FSR will establish the fuel input to the turbine at the rate required by the system which is in control. Only one control loop will be in control at any particular time and the control loop which is controlling FSR will be displayed on the .
The following speed detectors and speed relays are typically used: –L14HR Zero–Speed (approx. 0% speed) –L14HM speed)
–L14HA Accelerating Speed (approx. 50% speed)
Figure 2 shows a more detailed schematic of the control loops. This can be referenced during the explanation of each loop to show the interfacing.
–L14HS speed)
Operating Speed (approx. 95%
The zero–speed detector, L14HR, provides the signal when the turbine shaft starts or stops rotating. When the shaft speed is below 14HR, or at zero– speed, L14HR picks–up (fail safe) and the permissive logic initiates turning gear or slow–roll operation during the automatic start–up sequence of the turbine.
Start–up/Shutdown Sequence and Control Start–up control brings the gas turbine from zero speed up to operating speed safely by providing proper fuel to establish flame, accelerate the turbine, and to do it in such a manner as to minimize the low cycle fatigue of the hot gas path parts during the sequence. This involves proper sequencing of command signals to the accessories, starting device and fuel control system. Since a safe and successful start–up depends on proper functioning of the gas turbine equipment, it is important to verify the state of selected devices in the sequence. Much of the control logic circuitry is associated not only with actuating control devices, but enabling protective circuits and obtaining permissive conditions before proceeding.
The minimum speed detector L14HM indicates that the turbine has reached the minimum firing speed and initiates the purge cycle prior to the introduction of fuel and ignition. The dropout of the L14HM minimum speed relay provides several permissive functions in the restarting of the gas turbine after shutdown. The accelerating speed relay L14HA pickup indicates when the turbine has reached approximately 50 percent speed; this indicates that turbine start–up is progressing and keys certain protective features.
The gas turbine uses a static start system whereby the generator serves as a starting motor. A turning gear is used for rotor breakaway.
The high–speed sensor L14HS pickup indicates when the turbine is at speed and that the accelerating sequence is almost complete. This signal provides the logic for various control sequences such as stopping auxiliary lube oil pumps and starting turbine shell/exhaust frame blowers.
General values for control settings are given in this description to help in the understanding of the operating system. Actual values for control settings are given in the Control Specifications for a particular machine.
Should the turbine and generator slow during an underfrequency situation, L14HS will drop out at the under–frequency speed setting. After L14HS drops out the generator breaker will trip open and the Turbine Speed Reference (TNR) will be reset to 100.3%. As the turbine accelerates, L14HS will again pick up; the turbine will then require another start signal before the generator will attempt to auto– synchronize to the system again.
Speed Detectors An important part of the start–up/shutdown sequence control of the gas turbine is proper speed sensing. Turbine speed is measured by magnetic pickups and will be discussed under speed control. Fund_Mk_VI
Minimum Speed (approx. 16%
3
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems The actual settings of the speed relays are listed in the Control Specification and are programmed in the processors as EEPROM control constants.
OR LOWER” allows manual adjustment of FSR setting between FSRMIN and FSRMAX. While the turbine is at rest, electronic checks are made of the fuel system stop and control valves, the accessories, and the voltage supplies. At this time, “SHUTDOWN STATUS” will be displayed on the . Activating the Master Operation Switch (L43) from “OFF” to an operating mode will activate the ready circuit. If all protective circuits and trip latches are reset, the “STARTUP STATUS” and “READY TO START” messages will be displayed, indicating that the turbine will accept a start signal. Clicking on the “START” Master Control Switch (L1S) and “EXECUTE” will introduce the start signal to the logic sequence.
START–UP CONTROL The start–up control operates as an open loop control using preset levels of the fuel command signal FSR. The levels are: “ZERO”, “FIRE”, “WARM– UP”, “ACCELERATE” and “MAX”. The Control Specifications provide proper settings calculated for the fuel anticipated at the site. The FSR levels are set as Control Constants in the SPEEDTRONIC Mark VI start–up control.
The start signal energizes the Master Control and Protection circuit (the “L4” circuit) and starts the necessary auxiliary equipment. The “L4” circuit permits pressurization of the trip oil system. With the “L4” circuit permissive and starting clutch automatically engaged, the starting device starts turning. Startup status message “STARTING” will be displayed on the . See point “A” on the Typical Start–up Curve Figure 3.
Start–up control FSR signals operate through the minimum value gate to ensure that other control functions can limit FSR as required. The fuel command signals are generated by the SPEEDTRONIC control start–up software. In addition to the three active start–up levels, the software sets maximum and minimum FSR and provides for manual control of FSR. Clicking on the targets for “MAN FSR CONTROL” and “FSR GAG RAISE
SPEED – % 100
80 ACCELERATE IGNITION & CROSSFIRE 60
WARMUP IGV – DEGREES
1 MIN
START AUXILIARIES & DIESEL WARMUP
Tx – °F/10
PURGE COAST
40
DOWN
20
FSR – % C
0 A
B
APPROXIMATE TIME – MINUTES
D
id0093
Figure 3 Mark VI Start-up Curve
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
4
Fund_Mk_VI
GE Power Systems The starting clutch is a positive tooth type overrunning clutch which is self–engagifng in the breakaway mode and overruns whenever the turbine rotor exceeds the turning gear speed.
eration. This is done by programming a slow rise in FSR. See point “C” on Figure 3. As fuel is increased, the turbine begins the acceleration phase of start–up. The clutch is held in as long as the turning gear provides torque to the gas turbine. When the turbine overruns the turning gear, the clutch will disengage, shutting down the turning gear. Speed relay L14HA indicates the turbine is accelerating.
When the turbine ‘breaks away’ the turning gear will rotate the turbine rotor from 5 to 7 rpm. As the static starter begins it’s sequence, and accelerates the rotor the starting clutch will automatically disengage the turning gear from the turbine rotor. The turbine speed relay L14HM indicates that the turbine is turning at the speed required for proper purging and ignition in the combustors. Gas fired units that have exhaust configurations which can trap gas leakage (i.e., boilers) have a purge timer, L2TV, which is initiated with the L14HM signal. The purge time is set to allow three to four changes of air through the unit to ensure that any combustible mixture has been purged from the system. The starting means will hold speed until L2TV has completed its cycle. Units which do not have extensive exhaust systems may not have a purge timer, but rely on the starting cycle and natural draft to purge the system.
The start–up phase ends when the unit attains full– speed–no–load (see point “D” on Figure 3). FSR is then controlled by the speed loop and the auxiliary systems are automatically shut down. The start–up control software establishes the maximum allowable levels of FSR signals during start– up. As stated before, other control circuits are able to reduce and modulate FSR to perform their control functions. In the acceleration phase of the start–up, FSR control usually passes to acceleration control, which monitors the rate of rotor acceleration. It is possible, but not normal, to reach the temperature control limit. The display will show which parameter is limiting or controlling FSR.
The L14HM signal or completion of the purge cycle (L2TVX) ‘enables’ fuel flow, ignition, sets firing level FSR, and initiates the firing timer L2F. See point “B” on Figure 3. When the flame detector output signals indicate flame has been established in the combustors (L28FD), the warm–up timer L2W starts and the fuel command signal is reduced to the “WARM–UP” FSR level. The warm–up time is provided to minimize the thermal stresses of the hot gas path parts during the initial part of the start–up.
Fired Shutdown A normal shutdown is initiated by clicking on the “STOP” target (L1STOP) and “EXECUTE”; this will produce the L94X signal. If the generator breaker is closed when the stop signal is initiated, the Turbine Speed Reference (TNR) counts down to reduce load at the normal loading rate until the reverse power relay operates to open the generator breaker; TNR then continues to count down to reduce speed. When the STOP signal is given, shutdown Fuel Stroke Reference FSRSD is set equal to FSR.
If flame is not established by the time the L2F timer times out, typically 60 seconds, fuel flow is halted. The unit can be given another start signal, but firing will be delayed by the L2TV timer to avoid fuel accumulation in successive attempts. This sequence occurs even on units not requiring initial L2TV purge.
When the generator breaker opens, FSRSD ramps from existing FSR down to a value equal to FSRMIN, the minimum fuel required to keep the turbine fired. FSRSD latches onto FSRMIN and decreases with corrected speed. When turbine speed drops below a defined threshold (Control Constant K60RB) FSRSD ramps to a blowout of one flame detector. The sequencing logic remembers which flame detectors were functional when the breaker opened. When any of the functional flame detectors
At the completion of the warm–up period (L2WX), the start–up control ramps FSR at a predetermined rate to the setting for “ACCELERATE LIMIT”. The start–up cycle has been designed to moderate the highest firing temperature produced during accelFund_Mk_VI
5
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems Speed/Load Reference
senses a loss of flame, FSRMIN/FSRSD decreases at a higher rate until flame–out occurs, after which fuel flow is stopped.
The speed control software will change FSR in proportion to the difference between the actual turbine– generator speed (TNH) and the called–for speed reference (TNR).
Fired shut down is an improvement over the former fuel shut off at L14HS drop out. By maintaining flame down to a lower speed there is significant reduction in the strain developed on the hot gas path parts at the time of fuel shut off.
The called–for–speed, TNR, determines the load of the turbine. The range for generator drive turbines is normally from 95% (min.) to 107% (max.) speed. The start–up speed reference is 100.3% and is preset when a “START” signal is given.
SPEED CONTROL The Speed Control System controls the speed and load of the gas turbine generator in response to the actual turbine speed signal and the called–for speed reference. While on speed control the control mode message “SPEED CTRL”will be displayed.
TNR MAX. 107
HIGH SPEED STOP
104
“FSNL”
95 TNR MIN.
LOW SPEED STOP
MAX FSR
RATED FSR
100
MINIMUM FSR
Three magnetic sensors are used to measure the speed of the turbine. These magnetic pickup sensors (77NH–1,–2,–3) are high output devices consisting of a permanent magnet surrounded by a hermetically sealed case. The pickups are mounted in a ring around a 60–toothed wheel on the gas turbine compressor rotor. With the 60–tooth wheel, the frequency of the voltage output in Hertz is exactly equal to the speed of the turbine in revolutions per minute.
FULL SPEED NO LOAD FSR
SPEED REFERENCE % (TNR)
Speed Signal
FUEL STROKE REFERENCE (LOAD) (FSR) id0044
The voltage output is affected by the clearance between the teeth of the wheel and the tip of the magnetic pickup. Clearance between the outside diameter of the toothed wheel and the tip of the magnetic pickup should be kept within the limits specified in the Control Specifications (approx. 0.05 inch or 1.27 mm). If the clearance is not maintained within the specified limits, the pulse signal can be distorted. Turbine speed control would then operate in response to the incorrect speed feedback signal.
Figure 4 Droop Control Curve
The turbine follows to 100.3% TNH for synchronization. At this point the operator can raise or lower TNR, in turn raising or lowering TNH, via the 70R4CS switch on the generator control panel or by clicking on the targets on the , if required. Refer to Figure 4. Once the generator breaker is closed onto the power grid, the speed is held constant by the grid frequency. Fuel flow in excess of that necessary to maintain full speed no load will result in increased power produced by the generator. Thus the speed control loop becomes a load control loop and the speed reference is a convenient control
The signal from the magnetic pickups is brought into the Mark VI panel, one mag pickup to each controller , where it is monitored by the speed control software. FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
6
Fund_Mk_VI
GE Power Systems of the desired amount of load to be applied to the turbine–generator unit.
units have the same droop, all will share a load increase equally. Load sharing and system stability are the main advantages of this method of speed control.
Droop speed control is a proportional control, changing FSR in proportion to the difference between actual turbine speed and the speed reference. Any change in actual speed (grid frequency) will cause a proportional change in unit load. This proportionality is adjustable to the desired regulation or “Droop”. The speed vs. FSR relationship is shown on Figure 4.
Normally 4% droop is selected and the setpoint is calibrated such that 104% setpoint will generate a speed reference which will produce an FSR resulting in base load at design ambient temperature. When operating on droop control, the full–speed– no–load FSR setting calls for a fuel flow which is sufficient to maintain full speed with no generator load. By closing the generator breaker and raising TNR via raise/lower, the error between speed and reference is increased. This error is multiplied by a
If the entire grid system tends to be overloaded, grid frequency (or speed) will decrease and cause an FSR increase in proportion to the droop setting. If all
SPEED CONTROL FSNL TNR SPEED REFERENCE + –
+
ERROR SIGNAL
+
FSRN
TNH SPEED DROOP
SPEED CHANGER LOAD SET POINT
MAX. LIMIT L83SD RATE MEDIAN SELECT
L70R RAISE L70L LOWER
TNR
L83PRES PRESET LOGIC
SPEED REFERENCE
PRESET OPERATING MIN.
L83TNROP MIN. SELECT LOGIC START-UP OR SHUTDOWN
id0040
Figure 5 Speed Control Schematic Fund_Mk_VI
7
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems gain constant dependent on the desired droop setting and added to the FSNL FSR setting to produce the required FSR to take more load and thus assist in holding the system frequency. Refer to Figures 4 and 5.
Synchronizing
The minimum FSR limit (FSRMIN) in the SPEEDTRONIC Mark VI system prevents the speed control circuits from driving the FSR below the value which would cause flameout during a transient condition. For example, with a sudden rejection of load on the turbine, the speed control system loop would want to drive the FSR signal to zero, but the minimum FSR setting establishes the minimum fuel level that prevents a flameout. Temperature and/or
Automatic synchronizing is accomplished using synchronizing algorithms programmed into and software. Bus and generator voltage signals are input to the core which contains isolation transformers, and are then paralleled to . software drives the synch check and synch permissive relays, while provides the actual breaker close command. See Figure 6.
start–up control can drive FSR to zero and are not influenced by FSRMIN.
AUTO SYNCH AUTO SYNCH PERMISSIVE CALCULATED PHASE WITHIN LIMITS GEN VOLTS REF
LINE VOLTS REF
A A>B B
CALCULATED SLIP WITHIN LIMITS AND
L83AS AUTO SYNCH PERMISSIVE
A A>B B
CALCULATED ACCELERATION
AND
L25 BREAKER CLOSE
CALCULATED BREAKER LEAD TIME
id0048V
Figure 6 Synchronizing Control Schematic
There are three basic synchronizing modes. These may be selected from external contacts, i.e., generator panel selector switch, or from the SPEEDTRONIC Mark VI .
For synchronizing, the unit is brought to 100.3% speed to keep the generator “faster” than the grid, assuring load pick–up upon breaker closure. If the system frequency has varied enough to cause an unacceptable slip frequency (difference between generator frequency and grid frequency), the speed matching circuit adjusts TNR to maintain turbine speed 0.20% to 0.40% faster than the grid to assure the correct slip frequency and permit synchronizing.
1. OFF – Breaker will not be closed by SPEEDTRONIC Mark VI control 2. MANUAL – Operator initiated breaker closure when permissive synch check relay 25X is satisfied
For added protection a synchronizing check relay is provided in the generator panel. It is used in series with both the auto synchronizing relay and the manual breaker close switch to prevent large out– of–phase breaker closures.
3. AUTO – System will automatically match voltage and speed and then close the breaker at the appropriate time to hit top dead center on the synchroscope FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
8
Fund_Mk_VI
GE Power Systems turbine occurs in the flame zone of the combustion chambers. The combustion gas in that zone is diluted by cooling air and flows into the turbine section through the first stage nozzle. The temperature of that gas as it exits the first stage nozzle is known as the “firing temperature” of the gas turbine; it is this temperature that must be limited by the control system. From thermodynamic relationships, gas turbine cycle performance calculations, and known site conditions, firing temperature can be determined as a function of exhaust temperature and the pressure ratio across the turbine; the latter is determined from the measured compressor discharge pressure (CPD). The temperature control system is designed to measure and control turbine exhaust temperature rather than firing temperature because it is impractical to measure temperatures directly in the combustion chambers or at the turbine inlet. This indirect control of turbine firing temperature is made practical by utilizing known gas turbine aero– and thermo–dynamic characteristics and using those to bias the exhaust temperature signal, since the exhaust temperature alone is not a true indication of firing temperature.
ACCELERATION CONTROL Acceleration control compares the present value of the speed signal with the value at the last sample time. The difference between these two numbers is a measure of the acceleration. If the actual acceleration is greater than the acceleration reference, FSRACC is reduced, which will reduce FSR, and consequently the fuel to the gas turbine. During start–up the acceleration reference is a function of turbine speed; acceleration control usually takes over from speed control shortly after the warm–up period and brings the unit to speed. At “Complete Sequence”, which is normally 14HS pick–up, the acceleration reference is a Control Constant, normally 1% speed/second. After the unit has reached 100% TNH, acceleration control usually serves only to contain the unit’s speed if the generator breaker should open while under load.
EXHASUT TEMPERATURE (Tx)
ISOTHERMAL
Firing temperature can also be approximated as a function of exhaust temperature and fuel flow (FSR) and as a function of exhaust temperature and generator output (DWATT). Either FSR or megawatt exhaust temperature control curves are used as back–up to the primary CPD–biased temperature control curve.
COMPRESSOR DISCHARGE PRESSURE (CPD)
These relationships are shown on Figures 7 and 8. The lines of constant firing temperature are used in the control system to limit gas turbine operating temperatures, while the constant exhaust temperature limit protects the exhaust system during start– up.
id0045
Figure 7 Exhaust Temperature vs. Compressor Discharge Pressure
Exhaust Temperature Control Hardware
TEMPERATURE CONTROL Chromel–Alumel exhaust temperature thermocouples are used and, typically 27 in number. These thermocouples circumferentially inside the exhaust diffuser. They have individual radiation shields that allow the radial outward diffuser flow to pass over
The Temperature Control System will limit fuel flow to the gas turbine to maintain internal operating temperatures within design limitations of turbine hot gas path parts. The highest temperature in the gas Fund_Mk_VI
9
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems tive exhaust temperature value, compares this value with the setpoint, and then generates a fuel command signal to the analog control system to limit exhaust temperature. ISOTHERMAL EXHASUT TEMPERATURE (Tx)
Temperature Control Command Program The temperature control command program compares the exhaust temperature control setpoint with the measured gas turbine exhaust temperature as obtained from the thermocouples mounted in the exhaust plenum; these thermocouples are scanned and cold junction corrected by programs described later. These signals are accessed by . The temperature control command program in (Figure 9) reads the exhaust thermocouple temperature values and sorts them from the highest to the lowest. This array (TTXD2) is used in the combustion monitor program as well as in the Temperature Control Program. In the Temperature Control Program all exhaust thermocouple inputs are monitored and if any are reading too low as compared to a constant, they will be rejected. The highest and lowest values are then rejected and the remaining values are averaged, that average being the TTXM signal.
FUEL STROKE REFERENCE (FSR) id0046
Figure 8 Exhaust Temperature vs. Fuel Control Command Signal
these 1/16” diameter (1.6mm) stainless steel sheathed thermocouples at high velocity, minimizing the cooling effect of the longer time constant, cooler plenum walls. The signals from these individual, ungrounded detectors are sent to the SPEEDTRONIC Mark VI control panel through shielded thermocouple cables and are divided amongst controllers .
If a Controller should fail, this program will ignore the readings from the failed Controller. The TTXM signal will be based on the remaining Controllers’ thermocouples and an alarm will be generated.
Exhaust Temperature Control Software
The TTXM value is used as the feedback for the exhaust temperature comparator because the value is not affected by extremes that may be the result of faulty instrumentation. The temperature–control– command program in compares the exhaust temperature control setpoint (calculated in the temperature–control–bias program and stored in the computer memory) TTRXB to the TTXM value to determine the temperature error. The software program converts the temperature error to a fuel stroke reference signal, FSRT.
The software contains a series of application programs written to perform the exhaust temperature control and monitoring functions such as digital and analog input scan. A major function is the exhaust temperature control, which consists of the following programs: 1. Temperature control command 2. Temperature control bias calculations 3. Temperature reference selection
Temperature Control Bias Program
The temperature control software determines the cold junction compensated thermocouple readings, selects the temperature control setpoint, calculates the control setpoint value, calculates the representaFUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
Gas turbine firing temperature is determined by the measured parameters of exhaust temperature and 10
Fund_Mk_VI
GE Power Systems
. TO COMBUSTION MONITOR
TTXD2
TTXDR SORT HIGHEST TO LOWEST
TTXDS TTXDT
REJECT LOW TC’s
QUANTITY
REJECT HIGH AND LOW
TTXM
AVERAGE REMAINING
OF TC’s USED
CORNER
TEMPERATURE CONTROL REFERENCE
TEMPERATURE CONTROL FSRMIN
CPD FSRMAX SLOPE
SLOPE
TTRXB MEDIAN SELECT
MIN SELECT
FSRT
TTXM + FSR
+
GAIN CORNER FSR ISOTHERMAL id0032V
Figure 9 Temperature Control Schematic
compressor discharge pressure (CPD) or exhaust temperature and fuel consumption (proportional to FSR). In the computer, firing temperature is limited by a linearized function of exhaust temperature and CPD backed up by a linearized function of exhaust temperature and FSR (See Figure 8). The temperature control bias program (Figure 10) calculates the exhaust temperature control setpoint TTRXB based on the CPD data stored in computer memory and constants from the selected temperature–reference table. The program calculates another setpoint based on FSR and constants from another temperature– reference table.
DIGITAL INPUT DATA
SELECTED TEMPERATURE REFERENCE TABLE
COMPUTER MEMORY
TEMPERATURE CONTROL BIAS PROGRAM
COMPUTER MEMORY
CONSTANT STORAGE id0023
Figure 10 Temperature Control Bias
perature setpoint. The constants TTKn_K (FSR bias corner) and TTKn_M (FSR bias slope) are used with the FSR data to determine the FSR bias exhaust temperature setpoint. The values for these constants are
Figure 11 is a graphical illustration of the control setpoints. The constants TTKn_C (CPD bias corner) and TTKn_S (CPD bias slope) are used with the CPD data to determine the CPD bias exhaust temFund_Mk_VI
11
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems Temperature Reference Select Program
EXHAUST TEMPERATURE
given in the Control Specifications–Control System Settings drawing. The temperature–control–bias program also selects the isothermal setpoint TTKn_I. The program selects the minimum of the three setpoints, CPD bias, FSR bias, or isothermal for the final exhaust temperature control reference. During normal operation with gas or light distillate fuels, this selection results in a CPD bias control with an isothermal limit, as shown by the heavy lines on Figure 11. The CPD bias setpoint is compared with the FSR bias setpoint by the program and an alarm occurs when the CPD setpoint is higher. For units operating with heavy fuel, FSR bias control will be selected to minimize the effect of turbine nozzle plugging on firing temperature. The FSR bias setpoint will then be compared with the CPD bias setpoint and an alarm will occur when the FSR setpoint exceeds the CPD setpoint. A ramp function is provided in the program to limit the rate at which the setpoint can change. The maximum and minimum change in ramp rates (slope) are programmed in constants TTKRXR1 and TTKRXR2. Consult the Control Sequence Program (CSP) and the Control Specifications drawing for the block diagram illustration of this function and the value of the constants. Typical rate change limit is 1.5°F per second. The output of the ramp function is the exhaust temperature control setpoint which is stored in the computer memory.
TTKn_K
TTKn_I
The exhaust temperature control function selects control setpoints to allow gas turbine operation at various firing temperatures. The temperature–reference–select program (Figure 12) determines the operational level for control setpoints based on digital input information representing temperature control requirements. Three digital input signals are decoded to select one set of constants which define the control setpoints necessary to meet those requirements. A typical digital signal is “BASE SELECT”, selected by clicking on the appropriate target on the operator interface .
FUEL CONTROL SYSTEM The gas turbine fuel control system will change fuel flow to the combustors in response to the fuel stroke reference signal (FSR). FSR actually consists of two separate signals added together, FSR1 being the called–for liquid fuel flow and FSR2 being the called–for gas fuel flow; normally, FSR1 + FSR2 = FSR. Standard fuel systems are designed for operation with liquid fuel and/or gas fuel. This chapter will describe a dual fuel system. It starts with the servo drive system, where the setpoint is compared with the feedback signal and converted to a valve position. It will describe liquid, gas and dual fuel operation and how the FSR from the control systems previously described is conditioned and sent as a set point to the servo system.
ISOTHERMAL
TTKn_C
DIGITAL INPUT DATA
CPD FSR
TEMPERATURE REFERENCE SELECT
SELECTED TEMPERATURE REFERENCE TABLE
CONSTANT STORAGE id0054 id0106
Figure 11 Exhaust Temperature Control Setpoints
Figure 12 Temperature Reference Select Program
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
12
Fund_Mk_VI
GE Power Systems Servo Drive System
actuator. If the hydraulic actuator has spring return, hydraulic oil will be ported to one side of the cylinder and the other to drain. A feedback signal provided by a linear variable differential transformer (LVDT, Figure 13) will tell the control whether or not it is in the required position. The LVDT outputs an AC voltage which is proportional to the position of the core of the LVDT. This core in turn is connected to the valve whose position is being controlled; as the valve moves, the feedback voltage changes. The LVDT requires an exciter voltage which is provided by the VSVO card.
The heart of the fuel system is a three coil electro– hydraulic servovalve (servo) as shown in Figure 13. The servovalve is the interface between the electrical and mechanical systems and controls the direction and rate of motion of a hydraulic actuator based on the input current to the servo. 3-COIL TORQUE MOTOR TORQUE MOTOR ARMATURE
TORQUE MOTOR N
N
Figure 14 shows the major components of the servo positioning loops. The digital (microprocessor signal) to analog conversion is done on the VSVO card; this represents called–for fuel flow. The called–for fuel flow signal is then compared to a feedback representing actual fuel flow. The difference is amplified on the VSVO card and sent through the TSVO card to the servo. This output to the servos is monitored and there will be an alarm on loss of any one of the three signals from .
JET TUBE FORCE FEEDBACK SPRING
S
S
FAIL SAFE BIAS SPRING
P
R 1
P 2
Â
SPOOL VALVE
FILTER DRAIN
PS
Liquid Fuel Control
1350 PSI
The liquid fuel system consists of fuel handling components and electrical control components. Some of the fuel handling components are: primary fuel oil filter, fuel oil stop valve, three fuel pumps, fuel bypass valve, fuel pump pressure relief valve, flow divider, combined selector valve/pressure gauge assembly, false start drain valve, fuel lines, and fuel nozzles. The electrical control components are: liquid fuel pressure switch (upstream) 63FL–2, fuel oil stop valve limit switch 33FL, liquid fuel pump bypass valve servovalve 65FP, flow divider magnetic speed pickups 77FD–1, –2, –3 and SPEEDTRONIC control cards TSVO and VSVO. A diagram of the system showing major components is shown in Figure 15.
HYDRAULIC ACTUATOR
TO
LVDT
ABEX Servovalve
id0029
Figure 13 Electrohydraulic Servovalve
The servovalve contains three electrically isolated coils on the torque motor. Each coil is connected to one of the three Controllers . This provides redundancy should one of the Controllers or coils fail. There is a null–bias spring which positions the servo so that the actuator will go to the fail safe position should ALL power and/or control signals be lost. If the hydraulic actuator is a double–action piston, the control signal positions the servovalve so that it ports high–pressure oil to either side of the hydraulic
Fund_Mk_VI
The fuel bypass valve is a hydraulically actuated valve with a linear flow characteristic. Located
13
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
TSVO
LVDT
TSVO
VSVO REF
14
Figure 14 Servo Positioning Loops
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
POSTION FEEDBACK 3.2KHZ
EXCITATION
D/A
FUEL
REF
SERVO VALVE
3.2KHZ
VSVO D/A
TORQUE MOTOR HYDRAULIC ACTUATOR
HIGH PRESSURE OIL
VSVO REF
3.2KHZ
EXCITATION
D/A
LVDT
Fund_Mk_VI id0026
GE Power Systems
POSTION FEEDBACK
GE Power Systems between the inlet (low pressure) and discharge (high pressure) sides of the fuel pump, this valve bypasses excess fuel delivered by the fuel pump back to the fuel pump inlet, delivering to the flow divider the
fuel necessary to meet the control system fuel demand. It is positioned by servo valve 65FP, which receives its signal from the controllers.
FQ1
FSR1
TSVO
FQROUT TNH L4 L20FLX
VSVO PR/A
BY-PASS VALVE ASM. P R
40µ
63FL-2
65FP DIFFERENTIAL PRESSURE GUAGE
FLOW DIVIDER
TYPICAL FUEL NOZZLES
77FD-1
OH HYDRAULIC SUPPLY
COMBUSTION CHAMBER OFV
FUEL STOP VALVE
VR4 AD
OF FUEL PUMP (QTY 3)
M
33FL FALSE START DRAIN VALVE CHAMBER OFD
OLTCONTROL OIL
77FD-2 TO DRAIN 77FD-3 id0031V
Figure 15 Liquid Fuel Control Schematic
The flow divider divides the single stream of fuel from the pump into several streams, one for each combustor. It consists of a number of matched high volumetric efficiency positive displacement gear pumps, again one per combustor. The flow divider is driven by the small pressure differential between the inlet and outlet. The gear pumps are mechanically connected so that they all run at the same speed, making the discharge flow from each pump equal. Fuel flow is represented by the output from the flow divider magnetic pickups (77FD–1, –2 & –3). These are non–contacting magnetic pickups, giving a pulse signal frequency proportional to flow divider speed, which is proportional to the fuel flow delivered to the combustion chambers.
VSVO card modulates servovalve 65FP based on inputs of turbine speed, FSR1 (called–for liquid fuel flow), and flow divider speed (FQ1). Fuel Oil Control – Software When the turbine is run on liquid fuel oil, the control system checks the permissives L4 and L20FLX and does not allow FSR1 to close the bypass valve unless they are ‘true’ (closing the bypass valve sends fuel to the combustors). The L4 permissive comes from the Master Protective System (to be discussed later) and L20FLX becomes ‘true’ after the turbine vent timer times out. These signals control the opening and closing of the fuel oil stop valve. The FSR signal from the controlling system goes through the fuel splitter where the liquid fuel requirement becomes FSR1. The FSR1 signal is multiplied by TNH, so fuel flow becomes a function of
The TSVO card receives the pulse rate signals from 77FD–1, –2, and –3 and outputs an analog signal which is proportional to the pulse rate input. The Fund_Mk_VI
15
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems Gas Fuel Control
speed – an important feature, particularly while the unit is starting. This enables the system to have better resolution at the lower, more critical speeds where air flow is very low. This produces the FQROUT signal, which is the digital liquid fuel flow command. At full speed TNH does not change, therefore FQROUT is directly proportional to FSR.
The dry low NOx II (DLN–2) control system regulates the distribution of gas fuel to a multi–nozzle combustor arrangement. The fuel flow distribution to each fuel nozzle assembly is a function of combustion reference temperature (TTRF1) and IGV temperature control mode. By a combination of fuel staging and shifting of combustion modes from diffusion at ignition through premix at higher loads, low nitrous oxide (NOx) emissions are achieved.
FQROUT then goes to the VSVO card where it is changed to an analog signal to be compared to the feedback signal from the flow divider. As the fuel flows into the turbine, speed sensors 77FD–1, –2, and –3 send a signal to the TSVO card, which in turn outputs the fuel flow rate signal (FQ1) to the VSVO card. When the fuel flow rate is equal to the called– for rate (FQ1 = FSR1), the servovalve 65FP is moved to the null position and the bypass valve remains “stationary” until some input to the system changes. If the feedback is in error with FQROUT, the operational amplifier on the VSVO card will change the signal to servovalve 65FP to drive the bypass valve in a direction to decrease the error.
Fuel gas is controlled by the gas stop/speed ratio valve (SRV), the primary, secondary and quaternary gas control valves (GCV) , and the premix splitter valve (PMSV). The premix splitter valve controls the split between secondary and tertiary gas flow. All valves are servo controlled by signals from the SPEEDTRONIC control panel (Figure 16). It is the gas control valve which controls the desired gas fuel flow in response to the command signal FSR. To enable it to do this in a predictable manner, the speed ratio valve is designed to maintain a predetermined pressure (P2) at the inlet of the gas control valve as a function of gas turbine speed.
The flow divider feedback signal is also used for system checks. This analog signal is converted to digital counts and is used in the controller’s software to compare to certain limits as well as to display fuel flow on the . The checks made are as follows:
There are three main DLN–2 combustion modes: Primary, Lean–Lean, and Premix. Primary mode exists from light off to 81% corrected speed, fuel flow to primary nozzles only. Lean– Lean is from 81% corrected speed to a preselected combustion reference temperature, with fuel to the primary and tertiary nozzles. In Premix operation fuel is directed to secondary, tertiary and quaternary nozzles. Minimum load for this operation is set by combustion reference temperature and IGV position.
L60FFLH:Excessive fuel flow on start–up L3LFLT1:Loss of LVDT position feedback L3LFBSQ:Bypass valve is not fully open when the stop valve is closed. L3LFBSC:Servo current is detected when the stop valve is closed.
The fuel gas control system consists primarily of the following components: gas strainer, gas supply pressure switch 63FG, stop/speed ratio valve assembly, fuel gas pressure transducer(s) 96FG, gas fuel vent solenoid valve 20VG, control valve assembly, LVDT’s 96GC–1, –2, –3, –4, –5, –6, 96SR–1, –2, 96 PS–1, –2, electro–hydraulic servovalves 90SR, 65GC and 65PS, dump valve(s) VH–5, three pressure gauges, gas manifold with ‘pigtails’ to respec-
L3LFT:Loss of flow divider feedback If L60FFLH is true for a specified time period (nominally 2 seconds), the unit will trip; if L3LFLT1 through L3LFT are true, these faults will trip the unit during start–up and require manual reset. FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
16
Fund_Mk_VI
GE Power Systems tive fuel nozzles, and SPEEDTRONIC control cards TBQB and TCQC. The components are shown schematically in Figure 17. A functional explana-
tion is graphs.
contained
in
subsequent
para-
DLN–2 GAS FUEL SYSTEM T
SGCV
SRV PGCV
PMSV
S
SINGLE BURNING ZONE
P QGCV
5 BURNERS
* Q
GAS SKID
TURBINE COMPARTMENT
SRV SPEED/RATIO VALVE
T TERTIARY MANIFOLD, 1 NOZ. PREMIX ONLY
PGCV GAS CONTROL, PRIMARY
S SECONDARY MANIFOLD, 4 NOZ. PREMIX INJ.
SGCV GAS CONTROL, SECONDARY
P PRIMARY MANIFOLD, 4 NOZ. DIFFUSION INJ.
QGCV GAS CONTROL, QUATERNARY
Q QUAT MANIFOLD, CASING. PREMIX ONLY
PMSV PREMIX SPLITTER VALVE
*
PURGE AIR (PCD AIR SUPPLY)
Figure 16 DLN–2 Gas Fuel System
Fund_Mk_VI
17
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems
VSVO TSVO
POS1
SPEED RATIO VALVE CONTROL
FSR2
FPRG POS2
VSVO
TSVO GAS CONTROL VALVE POSITION FEEDBACK
GAS CONTROL VALVE SERVO
FPG
TBAI VAIC
TSVO
96FG-2A 96FG-2B 20VG
96FG-2C TRANSDUCERS
VENT
COMBUSTION CHAMBER 63FG-3 STOP/ RATIO VALVE
GAS CONTROL VALVE
GAS P2
Electrical Connection LVDT’S 96GC-1,2
LVDT’S 96SR-1,2
Hydraulic Piping
GAS MANIFOLD
Gas Piping VH5-1 DUMP RELAY TRIP
90SR SERVO
65GC SERVO
HYDRAULIC SUPPLY
id0059V
Figure 17 Gas Fuel Control System
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
18
Fund_Mk_VI
GE Power Systems Gas Control Valves
then output to the servo valve through the TSVO card. The gas control valve stem position is sensed by the output of a linear variable differential transformer (LVDT) and fed back through the TSVO card to an operational amplifier on the VSVO card where it is compared to the FSROUT input signal at a summing junction. There are two LVDTs providing feedback ; two of the three controllers are dedicated to one LVDT each, while the third selects the highest feedback through a high–select diode gate. If the feedback is in error with FSROUT, the operational amplifier on the VSVO card will change the signal to the hydraulic servovalve to drive the gas control valve in a direction to decrease the error. In this way the desired relationship between position and FSR2 is maintained and the control valve correctly meters the gas fuel. See Figure 18.
The position of the gas control valve plug is intended to be proportional to FSR2 which represents called– for gas fuel flow. Actuation of the spring–loaded gas control valve is by a hydraulic cylinder controlled by an electro–hydraulic servovalve. When the turbine is to run on gas fuel the permissives L4, L20FGX and L2TVX (turbine purge complete) must be ‘true’, similar to the liquid system. This allows the Gas Control Valve to open. The stroke of the valve will be proportional to FSR. FSR goes through the fuel splitter (to be discussed in the dual fuel section) where the gas fuel requirement becomes FSR2, which is then conditioned for offset and gain. This signal, FSROUT, goes to the VSVO card where it is converted to an analog signal and OFFSET GAIN
FSR2
+
+
HIGH SELECT
L4
TBQC
L3GCV FSROUT ANALOG I/O
GAS CONTROL VALVE
ELECTRICAL CONNECTION GAS PIPING HYDRAULIC PIPING
ÎÎ ÎÎ ÎÎ
GAS CONTROL VALVE POSITION LOOP CALIBRATION
LVDT’S 96GC-1, -2
SERVO VALVE
POSITION LVDT
GAS P2
FSR id0027V
Figure 18 Gas Control Valve Control Schematic Fund_Mk_VI
19
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems
TNH GAIN VSVO
OFFSET
+
FPRG
+
D A
L4
FPG
L3GRV HIGH POS2 SELECT
96FG-2A 96FG-2B 96FG-2C SPEED RATIO VALVE GAS
ÎÎÎ ÎÎÎ ÎÎÎ
VAIC
96SR-1,2 LVDT’S
OPERATING CYLINDER PISTON TRIP OIL
TBAI
DUMP RELAY TSVO
SERVO VALVE LEGEND ELECTRICAL CONNECTION
HYDRAULIC OIL
GAS PIPING HYDRAULIC PIPING
P2 or PRESSURE CONTROL VOLTAGE
DIGITAL
TNH Speed Ratio Valve Pressure Calibration id0058V
Figure 19 Stop/Speed Ratio Valve Control Schematic
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
20
Fund_Mk_VI
GE Power Systems The plug in the gas control valve is contoured to provide the proper flow area in relation to valve stroke. The gas control valve uses a skirted valve disc and venturi seat to obtain adequate pressure recovery. High pressure recovery occurs at overall valve pressure ratios substantially less than the critical pressure ratio. The net result is that flow through the control valve is independent of valve pressure drop. Gas flow then is a function of valve inlet pressure P2 and valve area only.
The stop/speed ratio valve provides a positive stop to fuel gas flow when required by a normal shut– down, emergency trip, or a no–run condition. Hydraulic trip dump valve VH–5 is located between the electro–hydraulic servovalve 90SR and the hydraulic actuating cylinder. This dump valve is operated by the low pressure control oil trip system. If permissives L4 and L3GRV are ‘true’ the trip oil (OLT) is at normal pressure and the dump valve is maintained in a position that allows servovalve 90SR to control the cylinder position. When the trip oil pressure is low (as in the case of normal or emergency shutdown), the dump valve spring shifts a spool valve to a position which dumps the high pressure hydraulic oil (OH) in the speed ratio/stop valve actuating cylinder to the lube oil reservoir. The closing spring atop the valve plug instantly shuts the valve, thereby shutting off fuel flow to the combustors.
As before, an open or a short circuit in one of the servo coils or in the signal to one coil does not cause a trip. Each GCV has two LVDTs and can run correctly on one. Stop/Speed Ratio Valve
In addition to being displayed, the feedback signals and the control signals of both valves are compared to normal operating limits, and if they go outside of these limits there will be an alarm. The following are typical alarms:
The speed ratio/stop valve is a dual function valve. It serves as a pressure regulating valve to hold a desired fuel gas pressure ahead of the gas control valve and it also serves as a stop valve. As a stop valve it is an integral part of the protection system. Any emergency trip or normal shutdown will move the valve to its closed position shutting off gas fuel flow to the turbine. This is done either by dumping hydraulic oil from the Stop/Speed Ratio Valve VH–5 hydraulic trip relay or driving the position control closed electrically.
L60FSGH: Excessive fuel flow on start–up L3GRVFB: Loss of LVDT feedback on the SRV L3GRVO: SRV open prior to permissive to open L3GRVSC: Servo current to SRV detected prior to permissive to open L3GCVFB: Loss of LVDT feedback on the GCV
The stop/speed ratio valve has two control loops. There is a position loop similar to that for the gas control valve and there is a pressure control loop. See Figure 19. Fuel gas pressure P2 at the inlet to the gas control valve is controlled by the pressure loop as a function of turbine speed. This is done by proportioning it to turbine speed signal TNH, with an offset and gain, which then becomes Gas Fuel Pressure Reference FPRG. FPRG then goes to the VSVO card to be converted to an analog signal. P2 pressure is measured by 96FG which outputs a voltage proportional to P2 pressure. This P2 signal (FPG) is compared to the FPRG and the error signal (if any) is in turn compared with the 96SR LVDT feedback to reposition the valve as in the GCV loop. Fund_Mk_VI
L3GCVO: GCV open prior to permissive to open L3GCVSC: Servo current to GCV detected prior to permissive to open L3GFIVP: Intervalve (P2) pressure low The servovalves are furnished with a mechanical null offset bias to cause the gas control valve or speed ratio valve to go to the zero stroke position (fail safe condition) should the servovalve signals or power be lost. During a trip or no–run condition, a positive voltage bias is placed on the servo coils holding them in the ‘valve closed’ position. 21
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems Premix Splitter Valve
FUEL SPLITTER A=B
The Premix splitter valve (PMSV) regulates the split of secondary/tertiary gas fuel flow between the secondary and tertiary gas fuel manifolds. The valve is referenced to the secondary fuel passages, i.e. 0% valve stroke corresponds to 0% secondary fuel flow. Unlike the SRV and GCV’s the flow through the splitter valve is not linear with valve position.The control system linearizes the fuel split setpoint and the resulting valve position command FSRXPOUT is used as the position reference.
A=B MAX. LIMIT
L84TG TOTAL GAS L84TL TOTAL LIQUID
MIN. LIMIT L83FZ PERMISSIVES
MEDIAN SELECT
RAMP RATE L83FG GAS SELECT L83FL LIQUID SELECT FSR
FSR1 LIQUID REF. FSR2 GAS REF. id0034
Dual Fuel Control
Figure 20 Fuel Splitter Schematic
Turbines that are designed to operate on both liquid and gaseous fuel are equipped with controls to provide the following features:
Fuel Transfer – Liquid to Gas If the unit is running on liquid fuel (FSR1) and the “GAS” target on the screen is selected the following sequence of events will take place, providing the transfer and fuel gas permissives are true (refer to Figure 21):
1.Transfer from one fuel to the other on command. 2. Allow time for filling the lines with the type of fuel to which turbine operation is being transferred.
FSR1 will remain at its initial value, but FSR2 will step to a value slightly greater than zero, usually 0.5%. This will open the gas control valve slightly to bleed down the intervalve volume. This is done in case a high pressure has been entrained. The presence of a higher pressure than that required by the speed/ratio controller would cause slow response in initiating gas flow.
3. Operation of liquid fuel nozzle purge when operating totally on gas fuel. 4. Operation of gas fuel nozzle purge when operating totally on liquid fuel. The software diagram for the fuel splitter is shown in Figure 20.
After a typical time delay of thirty seconds to bleed down the P2 pressure and fill the gas supply line, the software program ramps the fuel commands, FSR2 to increase and FSR1 to decrease, at a programmed rate through the median select gate. This is complete in thirty seconds.
Fuel Splitter As stated before FSR is divided into two signals, FSR1 and FSR2, to provide dual fuel operation. See Figure 20.
When the transfer is complete logic signal L84TG (Total Gas) will de–energize the liquid fuel forwarding pump, close the fuel oil stop valve by de–energizing the liquid fuel dump valve 20FL, and initiate the purge sequence.
FSR is multiplied by the liquid fuel fraction FX1 to produce the FSR1 signal. FSR1 is then subtracted from the FSR signal resulting in FSR2, the control signal for the secondary fuel. FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
22
Fund_Mk_VI
GE Power Systems Fuel Transfer – Gas to Liquid Transfer from Full Gas to Full Distillate
Transfer from gas to liquid is essentially the same sequence as previously described, except that gas and liquid fuel command signals are interchanged. For instance, at the beginning of a transfer, FSR2 remains at its initial value, but FSR1 steps to a value slightly greater than zero. This will command a small liquid fuel flow. If there has been any fuel leakage out past the check valves, this will fill the liquid fuel piping and avoid any delay in delivery at the beginning of the FSR1 increase.
UNITS
FSR2
FSR1 PURGE
TIME
SELECT DISTILLATE
Transfer from Full Distillate to Full Gas
UNITS
FSR1
FSR2 PURGE
The rest of the sequence is the same as liquid–to– gas, except that there is usually no purging sequence.
TIME
SELECT GAS
Transfer from Full Distillate to Mixture
Gas Fuel Purge
UNITS
FSR1
Primary gas fuel purge is required during premix steady state and liquid fuel operation. This system involves a double block and bleed arrangement, wherby two purge valves (VA13–1, –2) are shut when primary gas is flowing and intervalve vent solenoid (20VG–2) is open to bleed any leakage across the valves. The purge valves are air operated through solenoid valves 20PG–1, –2. When there is no primary gas flow, the purge valves open and allow compressor discharge air to flow through the primary fuel nozzle passages. Secondary purge is required for the secondary and tertiary nozzles when secondary and tertiary fuel flow is reduced to zero and when operating on liquid fuel. This is a block and bleed arrangement similar to the primary purge with two purge valves (VA13–3, –4), intervalve vent solenoid (20VG–3), and solenoid valves 20PG–3, –4.
FSR2 PURGE SELECT GAS
TIME SELECT MIX id0033
Figure 21 Fuel Transfer
Liquid Fuel Purge To prevent coking of the liquid fuel nozzles while operating on gas fuel, some atomizing air is diverted through the liquid fuel nozzles. The following sequence of events occurs when transfer from liquid to gas is complete. Air from the atomizing air system flows through a cooler (HX4–1), through the fuel oil purge valve (VA19–3) and through check valve VCK2 to each fuel nozzle.
MODULATED INLET GUIDE VANE SYSTEM
The fuel oil purge valve is controlled by the position of a solenoid valve 20PL–2 . When this valve is energized , actuating air pressure opens the purge oil check valve, allowing air flow to the fuel oil nozzle purge check valves.
Fund_Mk_VI
The Inlet Guide Vanes (IGVs) modulate during the acceleration of the gas turbine to rated speed, loading and unloading of the generator, and deceleration of the gas turbine. This IGV modulation maintains proper flows and pressures, and thus stresses, in the 23
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems compressor, maintains a minimum pressure drop across the fuel nozzles, and, when used in a com-
bined cycle application, maintains high exhaust temperatures at low loads.
CSRGV VSVO IGV REF
CSRGV
CSRGVOUT
D/A HIGH SELECT
TSVO
CLOSE HM3-1 HYD. SUPPLY IN
R
P
2
1
OPEN
FH6 OUT –1
90TV-1 A
96TV-1,2
OLT-1 TRIP OIL C1
VH3-1 D
C2 ORIFICES (2)
OD
id0030
Figure 23 Modulating Inlet Guide Vane Control Schematic
Guide Vane Actuation
Operation
The modulated inlet guide vane actuating system is comprised of the following components: servovalve 90TV, LVDT position sensors 96TV–1 and 96TV–2, and, in some instances, solenoid valve 20TV and hydraulic dump valve VH3. Control of 90TV will port hydraulic pressure to operate the variable inlet guide vane actuator. If used, 20TV and VH3 can prevent hydraulic oil pressure from flowing to 90TV. See Figure 23.
During start–up, the inlet guide vanes are held fully closed, a nominal 27 degree angle, from zero to 83.5% corrected speed. Turbine speed is corrected to reflect air conditions at 27° C (80° F); this compensates for changes in air density as ambient conditions change. At ambient temperatures greater than 80° F, corrected speed TNHCOR is less than actual speed TNH; at ambients less than 27° C (80° F), TNHCOR is greater than TNH. After attaining a speed of approximately 83.5%, the guide vanes will
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
24
Fund_Mk_VI
GE Power Systems modulate open at about 6.7 degrees per percent increase in corrected speed. When the guide vanes reach the minimum full speed angle, nominally 54°, they stop opening; this is usually at approximately 91% TNH. By not allowing the guide vanes to close to an angle less than the minimum full speed angle at 100% TNH, a minimum pressure drop is maintained across the fuel nozzles, thereby lessening combustion system resonance. Solenoid valve 20CB is usually opened when the generator breaker is closed; this in turn closes the compressor bleed valves.
IGV ANGLE – DEGREES (CSRGV)
FULL OPEN (MAX ANGLE)
SIMPLE CYCLE (CSKGVSSR)
MINIMUM FULL SPEED ANGLE ROTATING STALL REGION
0
REGION OF NEGATIVE 5TH STAGE EXTRACTION PRESSURE
100 CORRECTED SPEED–% (TNHCOR) 0 FSNL
100
LOAD–% EXHAUST TEMPERATURE
BASE LOAD id0037
Figure 24 Variable Inlet Guide Vane Schedule
PROTECTION SYSTEMS The gas turbine protection system is comprised of a number of sub–systems, several of which operate during each normal start–up and shutdown. The other systems and components function strictly during emergency and abnormal operating conditions. The most common kind of failure on a gas turbine is the failure of a sensor or sensor wiring; the protection systems are set up to detect and alarm such a failure. If the condition is serious enough to disable the protection completely, the turbine will be tripped.
During a normal shutdown, as the exhaust temperature decreases the IGVs move to the minimum full speed angle; as the turbine decelerates from 100% TNH, the inlet guide vanes are modulated to the fully closed position. When the generator breaker opens, the compressor bleed valves will be opened.
Protective systems respond to the simple trip signals such as pressure switches used for low lube oil pressure, high gas compressor discharge pressure, or similar indications. They also respond to more complex parameters such as overspeed, overtemperature, high vibration, combustion monitor, and loss of flame. To do this, some of these protection systems and their components operate through the master control and protection circuit in the SPEEDTRONIC control system, while other totally mechanical systems operate directly on the components of the turbine. In each case there are two essentially independent paths for stopping fuel flow, making use of both the fuel control valve (FCV) and the fuel stop valve (FSV). Each protective system is designed independent of the control system to avoid the possi-
In the event of a turbine trip, the compressor bleed valves are opened and the inlet guide vanes go to the fully closed position. The inlet guide vanes remain fully closed as the turbine continues to coast down. For underspeed operation, if TNHCOR decreases below approximately 91%, the inlet guide vanes modulate closed at 6.7 degrees per percent decrease in corrected speed. In most cases, if the actual speed decreases below 95% TNH, the generator breaker will open and the turbine speed setpoint will be reset to 100.3%. The IGVs will then go to the minimum full speed angle. See Figure 24. Fund_Mk_VI
STARTUP PROGRAM
FULL CLOSED (MIN ANGLE)
As the unit is loaded and exhaust temperature increases, the inlet guide vanes will go to the full open position when the exhaust temperature reaches one of two points, depending on the operation mode selected. For simple cycle operation, the IGVs move to the full open position at a pre–selected exhaust temperature, usually 371° C (700° F). For combined cycle operation, the IGVs begin to move to the full open position as exhaust temperature approaches the temperature control reference temperature; normally, the IGVs begin to open when exhaust temperature is within 17° C (30° F) of the temperature control reference.
COMBINED CYCLE (TTRX)
25
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems bility of a control system failure disabling the protective devices. See Figure 25.
PRIMARY OVERSPEED
MASTER PROTECTION CIRCUIT
GCV SERVOVALVE
GAS FUEL CONTROL VALVE
SRV SERVOVALVE
GAS FUEL SPEED RATIO/ STOP VALVE
OVERTEMP
VIBRATION
COMBUSTION MONITOR RELAY VOTING MODULE
LOSS of FLAME
SECONDARY OVERSPEED
MASTER PROTECTION CIRCUIT
20FG
BYPASS VALVE SERVOVALVE
RELAY VOTING MODULE
20FL
FUEL PUMP
LIQUID FUEL STOP VALVE id0036V
Figure 25 Protective Systems Schematic
Trip Oil
Inlet Orifice
A hydraulic trip system called Trip Oil is the primary protection interface between the turbine control and protection system and the components on the turbine which admit, or shut–off, fuel. The system contains devices which are electrically operated by SPEEDTRONIC control signals as well as some totally mechanical devices.
An orifice is located in the line running from the bearing header supply to the trip oil system. This orifice is sized to limit the flow of oil from the lube oil system into the trip oil system. It must ensure adequate capacity for all tripping devices, yet prevent reduction of lube oil flow to the gas turbine and other equipment when the trip system is in the tripped state. Dump Valve
Besides the tripping functions, trip oil also provides a hydraulic signal to the fuel stop valves for normal start–up and shutdown sequences. On gas turbines equipped for dual fuel (gas and oil) operation the system is used to selectively isolate the fuel system not required.
Each individual fuel branch in the trip oil system has a solenoid dump valve (20FL for liquid, 20FG for gas). This device is a solenoid–operated spring–return spool valve which will relieve trip oil pressure only in the branch that it controls. These valves are normally energized–to–run, deenergized–to–trip. This philosophy protects the turbine during all nor-
Significant components of the Hydraulic Trip Circuit are described below. FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
26
Fund_Mk_VI
GE Power Systems mal situations as well as that time when loss of dc power occurs.
PROTECTIVE SIGNALS
MASTER PROTECTION L4 CIRCUITS
LIQUID FUEL LIQUID FUEL STOP VALVE 20FG
20FL
ORIFICE AND CHECK VALVE NETWORK 63HL
INLET ORIFICE GAS FUEL SPEED RATIO/ STOP VALVE
GAS FUEL
63HG
WIRING PIPING
GAS FUEL DUMP RELAY VALVE OH
id0056
Figure 26 Trip Oil Schematic – Dual Fuel
Check Valve & Orifice Network
dividual fuel stop valve may be selectively closed by dumping the flow of trip oil going to it. Solenoid valve 20FL can cause the trip valve on the liquid fuel stop valve to go to the trip state, which permits closure of the liquid fuel stop valve by its spring return mechanism. Solenoid valve 20FG can cause the trip valve on the gas fuel speed ratio/stop valve to go to the trip state, permitting its spring–returned closure. The orifice in the check valve and orifice network permits independent dumping of each fuel branch of the trip oil system without affecting the other branch. Tripping all devices other than the individual dump valves will result in dumping the total trip oil system, which will shut the unit down.
At the inlet of each individual fuel branch is a check valve and orifice network which limits flow out of that branch. This network limits flow into each branch, thus allowing individual fuel control without total system pressure decay. However, when one of the trip devices located in the main artery of the system, e.g., the overspeed trip, is actuated, the check valve will open and result in decay of all trip pressures. Pressure Switches Each individual fuel branch contains pressure switches (63HL–1,–2,–3 for liquid, 63HG–1,–2,–3 for gas) which will ensure tripping of the turbine if the trip oil pressure becomes too low for reliable operation while operating on that fuel.
During start–up or fuel transfer, the SPEEDTRONIC control system will close the appropriate dump valve to activate the desired fuel system(s). Both dump valves will be closed only during fuel transfer or mixed fuel operation.
Operation The dump valves are de–energized on a “2–out– of–3 voted” trip signal from the relay module. This helps prevent trips caused by faulty sensors or the failure of one controller.
The tripping devices which cause unit shutdown or selective fuel system shutdown do so by dumping the low pressure trip oil (OLT). See Figure 26. An inFund_Mk_VI
27
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems The signal to the fuel system servovalves will also be a “close” command should a trip occur. This is done by clamping FSR to zero. Should one controller fail, the FSR from that controller will be zero. The output of the other two controllers is sufficient to continue to control the servovalve.
HIGH PRESSURE OVERSPEED TRIP HP SPEED
TNH
TRIP SETPOINT TNKHOS TNKHOST
By pushing the Emergency Trip Button, 5E P/B, the P28 vdc power supply is cut off to the relays controlling solenoid valves 20FL and 20FG, thus de–energizing the dump valves.
A A>B B
L12H SET AND LATCH
TO MASTER PROTECTION AND ALARM MESSAGE
TEST
LH3HOST
TEST PERMISSIVE
L86MR1
MASTER RESET
RESET
SAMPLING RATE = 0.25 SEC id0060
Figure 27 Electronic Overspeed Trip
Overtemperature Protection
Overspeed Protection
The overtemperature system protects the gas turbine against possible damage caused by overfiring. It is a backup system, operating only after the failure of the temperature control system.
The SPEEDTRONIC Mark VI overspeed system is designed to protect the gas turbine against possible damage caused by overspeeding the turbine rotor. Under normal operation, the speed of the rotor is controlled by speed control. The overspeed system would not be called on except after the failure of other systems.
TTKOT1
EXH TEMP
The overspeed protection system consists of a primary and secondary electronic overspeed system. The primary electronic overspeed protection system resides in the controllers. The secondary electronic overspeed protection system resides in the controllers (in ). Both systems consist of magnetic pickups to sense turbine speed, speed detection software, and associated logic circuits and are set to trip the unit at 110% rated speed.
TRIP
TTRX TRIP MARGIN TTKOT2 ALARM MARGIN TTKOT3 CPD/FSR id0053
Figure 29 Overtemperature Protection
Electronic Overspeed Protection System
Under normal operating conditions, the exhaust temperature control system acts to control fuel flow when the firing temperature limit is reached. In certain failure modes however, exhaust temperature and fuel flow can exceed control limits. Under such circumstances the overtemperature protection system provides an overtemperature alarm about 14° C (25° F) above the temperature control reference. To avoid further temperature increase, it starts unloading the gas turbine. If the temperature should increase further to a point about 22° C (40° F) above the temperature control reference, the gas turbine is tripped. For the actual alarm and trip overtempera-
The electronic overspeed protection function is performed in both and as shown in Figure 27. The turbine speed signal (TNH) derived from the magnetic pickup sensors (77NH–1,–2, and –3) is compared to an overspeed setpoint (TNKHOS). When TNH exceeds the setpoint, the overspeed trip signal (L12H) is transmitted to the master protective circuit to trip the turbine and the “OVERSPEED TRIP” message will be displayed on the . This trip will latch and must be reset by the master reset signal L86MR. FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
28
Fund_Mk_VI
GE Power Systems ture setpoints refer to the Control Specifications. See Figure 29.
will be tripped through the master protection circuit. The trip function will be latched in and the master reset signal L86MR1 must be true to reset and unlatch the trip.
Overtemperature trip and alarm setpoints are determined from the temperature control setpoints derived by the Exhaust Temperature Control software. See Figure 30.
Flame Detection and Protection System The SPEEDTRONIC Mark VI flame detectors perform two functions, one in the sequencing system and the other in the protective system. During a normal start–up the flame detectors indicate when a flame has been established in the combustion chambers and allow the start–up sequence to continue. Most units have four flame detectors, some have two, and a very few have eight. Generally speaking, if half of the flame detectors indicate flame and half (or less) indicate no–flame, there will be an alarm but the unit will continue to run. If more than half indicate loss–of–flame, the unit will trip on “LOSS OF FLAME.” This avoids possible accumulation of an explosive mixture in the turbine and any exhaust heat recovery equipment which may be installed. The flame detector system used with the SPEEDTRONIC Mark VI system detects flame by sensing ultraviolet (UV) radiation. Such radiation results from the combustion of hydrocarbon fuels and is more reliably detected than visible light, which varies in color and intensity.
OVERTEMPERATURE TRIP AND ALARM TTXM
A ALARM
TTKOT3
TTRXB
L30TXA
A>B
ALARM
B
TO ALARM MESSAGE AND SPEED SETPOINT LOWER
A A>B B
TTKOT2
OR A TRIP ISOTHERMAL
TTKOT1
A>B B
L86MR1
SET AND LATCH
L86TXT TRIP
TO MASTER PROTECTION AND ALARM MESSAGE
RESET SAMPLING RATE: 0.25 SEC.
id0055
Figure 30 Overtemperature Trip and Alarm
Overtemperature Protection Software Overtemperature Alarm (L30TXA) The representative value of the exhaust temperature thermocouples (TTXM) is compared with alarm and trip temperature setpoints. The “EXHAUST TEMPERATURE HIGH” alarm message will be displayed when the exhaust temperature (TTXM) exceeds the temperature control reference (TTRXB) plus the alarm margin (TTKOT3) programmed as a Control Constant in the software. The alarm will automatically reset if the temperature decreases below the setpoint.
The flame sensor is a copper cathode detector designed to detect the presence of ultraviolet radiation. The SPEEDTRONIC control will furnish +24Vdc to drive the ultraviolet detector tube. In the presence of ultraviolet radiation, the gas in the detector tube ionizes and conducts current. The strength of the current feedback (4 – 20 mA) to the panel is a proportional indication of the strength of the ultraviolet radiation present. If the feedback current exceeds a threshold value the SPEEDTRONIC generates a logic signal to indicate ”FLAME DETECTED” by the sensor.
Overtemperature Trip (L86TXT) An overtemperature trip will occur if the exhaust temperature (TTXM) exceeds the temperature control reference (TTRXB) plus the trip margin (TTKOT2), or if it exceeds the isothermal trip setpoint (TTKOT1). The overtemperature trip will latch, the “EXHAUST OVERTEMPERATURE TRIP” message will be displayed, and the turbine Fund_Mk_VI
The flame detector system is similar to other protective systems, in that it is self–monitoring. For example, when the gas turbine is below L14HM all channels must indicate “NO FLAME.” If this condition is not met, the condition is annunciated as a 29
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems “FLAME DETECTOR TROUBLE” alarm and the turbine cannot be started. After firing speed has been reached and fuel introduced to the machine, if at least half the flame detectors see flame the starting sequence is allowed to proceed. A failure of one detector will be annunciated as “FLAME DETECTOR TROUBLE” when complete sequence is reached
and the turbine will continue to run. More than half the flame detectors must indicate “NO FLAME” in order to trip the turbine. Note that a short–circuited or open–circuited detector tube will result in a “NO FLAME” signal.
SPEEDTRONIC Mk VI Flame Detection Turbine Protection Logic
28FD UV Scanner 28FD UV Scanner 28FD UV Scanner
Analog I/O
Flame Detection Logic
Display
TBAI VAIC
28FD UV Scanner
Turbine Control Logic
NOTE: Excitation for the sensors and signal processing is performed by SPEEDTRONIC Mk VI circuits
Figure 31 SPEEDTRONIC Mk VI Flame Detection
ido115
Vibration Protection
ceeded, the vibration protection system trips the turbine and annunciates to indicate the cause of the trip.
The vibration protection system of a gas turbine unit is composed of several independent vibration channels. Each channel detects excessive vibration by means of a seismic pickup mounted on a bearing housing or similar location of the gas turbine and the driven load. If a predetermined vibration level is ex-
Each channel includes one vibration pickup (velocity type) and a SPEEDTRONIC Mark VI amplifier circuit. The vibration detectors generate a relatively low voltage by the relative motion of a permanent magnet suspended in a coil and therefore no excitation is necessary. A twisted–pair shielded cable is
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
30
Fund_Mk_VI
GE Power Systems used to connect the detector to the analog input/output module.
Combustion Monitoring
The pickup signal from the analog I/O module is inputted to the computer software where it is compared with the alarm and trip levels programmed as Control Constants. See Figure 32. When the vibration amplitude reaches the programmed trip set point, the channel will trigger a trip signal, the circuit will latch, and a “HIGH VIBRATION TRIP” message will be displayed. Removal of the latched trip condition can be accomplished only by depressing the master reset button (L86MR1) when vibration is not excessive.
The primary function of the combustion monitor is to reduce the likelihood of extensive damage to the gas turbine if the combustion system deteriorates. The monitor does this by examining the exhaust temperature thermocouples and compressor discharge temperature thermocouples. From changes that may occur in the pattern of the thermocouple readings, warning and protective signals are generated by the combustion monitor software to alarm and/or trip the gas turbine. This means of detecting abnormalities in the combustion system is effective only when there is incomplete mixing as the gases pass through the turbine; an uneven turbine inlet pattern will cause an uneven exhaust pattern. The uneven inlet pattern could be caused by loss of fuel or flame in a combustor, a rupture in a transition piece, or some other combustion malfunction.
L39TEST 39V OR A AB ALARM
ALARM L39VA
VA
B
A A>B TRIP
VT
AND
TRIP L39VT
SET AND LATCH
The usefulness and reliability of the combustion monitor depends on the condition of the exhaust thermocouples. It is important that each of the thermocouples is in good working condition.
TRIP
B RESET
Combustion Monitoring Software
AUTO OR MANUAL RESET L86AMR
id0057
The controllers contain a series of programs written to perform the monitoring tasks (See Combustion Monitoring Schematic Figure 33). The main monitor program is written to analyze the thermocouple readings and make appropriate decisions. Several different algorithms have been developed for this depending on the turbine model series and the type of thermocouples used. The significant program constants used with each algorithm are specified in the Control Specification for each unit.
Figure 32 Vibration Protection
When the “VIBRATION TRANSDUCER FAULT” message is displayed and machine operation is not interrupted, either an open or shorted condition may be the cause. This message indicates that maintenance or replacement action is required. With the display, it is possible to monitor vibration levels of each channel while the turbine is running without interrupting operation.
Fund_Mk_VI
31
FUNDAMENTALS OF SPEEDTRONIC MARK VI CONTROL SYSTEM
GE Power Systems COMBUSTION MONITOR ALGORITHM
CTDA MAX
TTKSPL1
MIN
TTKSPL2
MEDIAN SELECT CALCULATE ALLOWABLE SPREAD
TTXM
MAX
TTKSPL5
MIN
TTKSPL7
MEDIAN SELECT
TTXSPL
A
L60SP1
CONSTANTS
A>B B
TTXD2
A
CALCULATE ACTUAL SPREADS
A>B
L60SP2
B A A
