Solar Turbine Turbotronic 4 sptt-pg.pdf

TURBOTRONIC 4CONTROL SYSTEM Power Generation CONTROL SYSTEMS Introduction Solar's Turbotronic 4 control system is used for to the programmable controller for computation sequencing, control, and protection of the gas and generation of the required control actions turbine package, and for providing an extensive and indications. range of options for monitoring and plant control. The programmable controller, in conjunction The control system is based on a commer- with the video display unit (VDU), permits a wide cially available programmable controller config- range of features. These include a variety of ad- ured to Solar's requirements. It provides an opti- vanced software and control options, as well as mum combination of control and display features, condition and trend monitoring and supervisory reliability and maintainability, and is configured control. specifically for the control of turbomachinery and The control system provides the operator associated equipment. with necessary information for operation of the The control system described herein is pro- equipment. It also offers a variety of communica- vided for Power Generation products and in- tions options for data exchange with the cus- cludes a number of sensors, transducers, and tomer's supervisory system. monitoring devices. Data are collected and sent i ..................................................................................................................... 22 QUALITY ASSURANCE...................................................................... 7 CONTROL AND PROTECTION...................................................... 4 VIBRATION MONITORING SYSTEM........................... 9 Optional Control and Display Features ...................................... 20 ELECTRICAL SPECIFICATION..........................................................A... All rights reserved................................................. 22 Appendix C: Control System Information ............................................................................................................................................. 3 INTERNAL COMMUNICATION................................... Centaur............................................................................................................................................................................................................... SPTT-PG/802 ii .................................... 1 GENERAL INFORMATION ............................................................................................... 21 HARDWARE CERTIFICATION ..................................... Solar................................................................................................................ Printed in U..................................................................................................... 15 COMMUNICATIONS – TURBINE CONTROL TO SUPERVISORY SYSTEM ........ 15 FIRE DETECTION AND SUPPRESSION SYSTEM ................................................................................................................................................................................................... 4 BACKUP SYSTEM ............................................................. 24 Caterpillar is a registered trademark of Caterpillar Inc................................................... Specifications subject to change without notice................................................................................................................................. 15 FIELD PROGRAMMING ............................................................................................................................................................................................................................................................. 20 RFI/EMI SUSCEPTIBILITY AND EMISSION ................................................... 1 ONSKID CONTROL CONSOLE..................................................... Titan and Turbotronic are trademarks of Solar Turbines Incorporated.................................................... ©2002 Solar Turbines Incorporated.............................. 22 AREA CLASSIFICATION ................................................................................................. 4 POWER SUPPLY SYSTEM .................................................................................................................................................................................................................................................20 Appendix B: Technical Supplement ..... 24 HUMAN MACHINE INTERFACE DESCRIPTIONS ............................................................................................................................................................................................................................................................................................................................................ 2 INPUT/OUTPUT MODULES ............................................... 15 VIDEO DISPLAY OPTIONS ............................................................................................ 15 LANGUAGE.. 24 SYSTEM DESCRIPTIONS.......................................................................................................S........ 6 VOLTAGE REGULATION ...................................... 7 OPERATOR INTERFACE .................................................. 5 GOVERNOR................................................. 20 ENVIRONMENTAL SPECIFICATION.................................... 1 PROGRAMMABLE CONTROLLER .................................................................................................................................. i Standard Hardware ................................................... 22 CONTROL CONSOLE LAYOUT .........................Contents Introduction................................... 24 TURBOTRONIC DEFINITIONS .............................................. 21 HARDWARE INFORMATION ............................................................................................................................................................................................................................................................................................ 18 Appendix A: Hardware ....................... 15 ENGINEERING UNITS......................................................................................................................... 20 PHYSICAL HARDWARE............................................................................................................ 5 GENERATOR CONTROL AND PROTECTION.................................................................................................................................................. and the package sensing and control elements. Typical Package Control System 1 . as de- picted in Figure 2. onskid control console. The control system requires a source of 24- Vdc nominal power. but each control system has the same basic internal components.Standard Hardware GENERAL INFORMATION The Turbotronic 4 control system is a highly integrated programmable controller-based control system with a video display unit (VDU) and operator interface panel (Figure 1). control and monitoring software. The internal computing capability of the control system may vary by product line. ONSKID CONTROL CONSOLE The control system is provided in two onskid. VDU. Figure 1. relay backup system. NEMA 4 boxes. Typical Control Console OPERATOR'S PROGRAMMABLE INTERFACE CONTROLLER CONTROLNET BRIDGE DISPLAY CONTROLNET REDUNDANT MODULE LINK CONTROLNET LINK FLEX I/O COMBINATION MODULES GENERATOR CONTROL MODULE BACKUP RELAY SHUTDOWN TURBINE GENERATOR Figure 2. which is derived from a source of 120-Vdc power supplied by a battery bank with associated battery charger. The turbine control panel and onskid VDU include all necessary switches and indicators for gas turbine operation. The control system is designed to operate in a nonhazardous area. The control system consists of several dis- tinct modules: a programmable controller. input/output (I/O) modules (discrete and analog). operation and printed out. The programmable controller Using an optional programming terminal. Ladder logic format (Figure 3) is quite fa- tional Control and Display Features"). · Analog and status outputs for display and monitoring Figure 3. All components within the control console are The programmable controller is programmed factory interconnected and wired to the sensors in a language called “relay ladder logic” or in and transmitters. and communication. Ladder Logic Diagram 2 . mable controller. a copy of the ladder files may be during start-up. troubleshoot. since it closely emulates the relay logic used PROGRAMMABLE CONTROLLER in the past. but can “function block diagram” programming. In addition to viewing the ladder · Control of turbine and driven equipment logic online. This format can program a · Protection of driven equipment from complex algorithm on one page that would take abnormal operating conditions multiple pages of ladder logic to implement. Labels are in English. the user performs the following functions in conjunction can monitor the program online and troubleshoot with the input and output signal modules: a problem or make modifications when required (see “Programmable Controller Field Program- · Sequencing of gas turbine and auxiliaries ming” option). shutdown Function block diagram programming (Figure 4) allows control algorithms to be pro- · Protection of turbine from abnormal grammed in a graphical format familiar to process operating conditions control engineers. miliar to most operators and engineering personnel. The compact program is easier to read. be provided in various other languages (see "Op. · Response to commands from operator and understand. calculation. It also includes a variety of computa- tional and file transfer commands useful for data The heart of the control system is the program- manipulation. loading. the on a Terminal Base Unit adapter also serves to power the internal logic for as many as eight I/O modules. The adapter serves as a communication hub between each of the attached I/O modules and the programmable controller. the terminal base acts as the terminal strip to which the field devices are wired. Function Block Diagram Programming INPUT/OUTPUT MODULES In order to perform many of its functions. the programmable controller must gather physical data. but also indi. This is accomplished through I/O modules that are provided as discrete (input. when they are connected side to side. allowing data to be transferred from the I/O module to the programmable controller via Con- trolNet 1. The I/O modules are mounted to terminal base units (Figure 5). output. Terminal base units have two primary functions. shutdowns. Figure 5. First. Typical I/O Module Mounted vidual module status and health. Second.Figure 4. or both) or analog (input. or status indications and analog inputs are used for scale- able functions. In addition. Data are transferred to and from the I/O module via an adapter module. providing not only I/O data. 3 . Discrete inputs are typically used for alarms. the bases serve as a backplane.5. or both). output. Analog output mod. transfer to the programmable controller. input/output modules. Temperature modules serve to condition and transfer temperature data The basic control system is equipped with an in- from package resistance temperature detectors dependent relay backup system that serves to (RTD). cated at the console and turbine skid). The discrete input modules can have a The physical layer of ControlNet 1. The ery and to control the post-lube cycle. all discrete outputs are automatically or used in the basic control or display of the con. but are not necessarily dis. base. and relay backup systems. The most significant features of ControlNet Discrete Output Modules. 4 . The analog output module is a four. The frequency in. dc- puts. or more if repeaters are used. The backup control system is a com- Analog Output Modules. monitor. then a set of connecting to. A fault channel output module. Each channel is individually ceives 120-Vdc input from the battery system and configured for current or voltage by choosing converts it into a regulated and filtered 28-Vdc where the input is connected on the terminal power at a maximum of 20 amps. and thermo. ules are used to send an analog signal. times are constant and unaffected by devices If “dry” contacts are required. This during sequencing of the gas turbine. relays or motor contactors. 100-ohm platinum preferred. the relay backup system from 500 mV to 28 Vac peak.5 is a high speed. Deterministic is the solenoid valves.5 are its speed and the fact that it is both de- ules are used to drive output devices such as terministic and repeatable. 1. bination of instantaneous and time delay relays. Speed modules perform high. The ability to reliably predict when data will be deliv- discrete output module is capable of having either ered. Discrete is more than 50 times faster than the widely used signals can be used for alarms. The system re- ferent types of input. and The speed module has two input channels. grammable controller fail “watchdog” timer. to isolate the troller and I/O modules is via ControlNet 1. shutdowns or Data Highway Plus (DH+) and the Remote I/O simply indicators. push buttons. Analog input modules The power supply system supplies power to the accept analog signals and digitize the data for programmable controller. is initiated either by the internal programmable controller “watchdog“ or by failure of the output INTERNAL COMMUNICATION module. Discrete input modules used with both non-Flex I/O and Flex I/O and can receive signals from on/off devices. When activated by of which may accept magnetic pickup signals any of the above faults. lays. This can be quence operation of the post-lube oil system. re. Critical temperature module has eight input channels.5 (Fig- driven equipment by transferring block valves or ure 2). such as level handle communications over distances of up to switches. switched off. and repeatability ensures that transmit 8 or 16 channels of output data per module. the network. the pro- puts can accept frequencies up to 32. Discrete output mod. used to make a connection. determi- circuit breakers to their safe position. initiate emergency shutdown of the turbomachin- couples to the programmable controller. or leaving. The programmable controller fail trol system. serial communications link. either When a failure of the programmable control- repeating one of those supplied by the purchaser ler occurs.Discrete Input Modules. Modules video display unit. voltage converting. The net- interposing relays or a two-amp contact relay work update time for a typical turbomachinery output module may be provided at additional control system is around five milliseconds. and protective equipment normally used at a bus speed of 5. with different channels being used for dif- to-dc isolating power supplies. initiates a safe shutdown of the turbine and driven equipment. with a passive tap module type.0 megabits per second. BACKUP SYSTEM Temperature Modules.5 is quad capacity of up to 16 channels depending on shielded RG-6U coaxial cable. POWER SUPPLY SYSTEM Analog Input Modules. The programmable controller fail relay contacts are used in the relay backup system to Communication between the programmable con- initiate an emergency shutdown. cost. systems. each the fire system relay contacts. input signals monitored by the backup system include the backup power turbine overspeed Speed Modules. and to se- nistic.767 Hz. It can accept either four or eight single-ended in- consists of independent. 1000 m (3300 ft). played. manual emergency stop switches (lo- speed frequency algorithms. relay is re-energized on a fault condition. pressure switches. ControlNet 1. With parallel with a utility source. and driven equipment. Once a shutdown is initiated by the backup of operation. further increase in temperature and. sharing between the units. In the case of a generator generator is typically instrumented with a velocity paralleled with an infinite bus (utility). predetermined factory-set level. trol relay and its associated relays and timers are A solid-state combination generator control restored to their normal position. changes in ambient temperature (engine air inlet The system consists of the turbine speed temperature T1). (kW) on a unit operating in parallel with a large power source. either a warning cuits. stopping. buttons on the turbine control console. the limiter adjusts the load to transducer (magnetic pickup). the speed monitor. remote monitoring. operating in island mode. operation can only be restored manually nous and isochronous to droop is bumpless. 4-to-20 mA signals to be read by the turbine When the generator is not paralleled with the package control system. rather than frequency and/or generator load distribution full site-rated capacity. or operating in load for the current ambient temperature. Di- rect access to the raw vibration signals is avail- T5 Temperature Limiter. then the optional kW con- (when operating in parallel) by controlling turbine troller should be used. This action re-energizes the master con. The gearbox is typi- controlled based on temperature rather than cally instrumented with an accelerometer. The governor is a speed. The system includes provisions for system and its set point can be viewed from the selection of isochronous or speed droop modes VDU. The gas turbine vibration monitoring instru- Turbine engine temperature (T5) is also an mentation consists of a single proximity probe per input to the governor control. and the load at all times. The unit continues to operate at this full site-rated erating in parallel with other units. matically maintaining the unit at full site-rated ture input module. When the pre- load and temperature control system whose determined temperature level is reached. electronic fuel valve. facilitating equal real and reactive load is indicated or a turbine shutdown is initiated. iter takes control of the throttle and prevents any tion of the turbine generator set: for example. by a safety key switch lockout located on the Speed set-point adjustment is by means of speed console front panel when all faults have been increase and speed decrease momentary push cleared. Each generator's load is continuously meas- tion indication and protection for the gas turbine. diagnostics and trending. thus. 5 . auto- turbine T5 temperature thermocouples. the temperature control is set to a higher All data available to the programmable con- temperature to allow momentary operation in ex- troller are also obtainable via serial link for user cess of rated load during on-load transients. Limits the real load able via BNC connectors. the lim- dominant signal depends on the mode of opera. load. Output current to the fuel actuator pro. op. module (CGCM) provides load sharing between multiple units and is specifically designed to in- VIBRATION MONITORING SYSTEM terface with the programmable controller to provide an integrated power generation control solu- The vibration monitoring system provides vibration. maintain a constant T5 temperature. The speed or load inputs. and velocity transducers are tion of the unit to its rated full-load capacity for connected to individual transmitters that provide the current ambient temperature conditions. When turbine tem- bearing or two velocity transducers per engine for perature exceeds rated levels. fuel flow is then the Centaur 40 gas turbine. If the application periodically requires opera- The governor system maintains generator tion at a specific constant load level. utility. such as an electric utility or other GOVERNOR infinite bus system at the maximum unit rating for The "governor system" consists of various hard. programmable controller software files. The system ware and systems integrated together to provide limits the kW load by limiting T5 temperature to a the governor function. ured by the respective CGCM and compared to gearbox. The proximity probes. fuel flow. The T5 temperature limited system is a part of vides the mechanical interface to the electronic the turbine temperature control and indication fuel valve. starting. the tem- transducer per bearing. The transfer from droop to isochro- system. any ambient temperature condition. perature control limits the load-carrying contribu- accelerometers. thus. tempera. Depending on other units on the same bus via interconnect cir- the unacceptable vibration level. Module (CGCM) Figure 7.5 (Figure 7). and Regulator System 6 . the combination generator control module (CGCM) provides more flexibility and accessibility to specific generator control options. voltage control. synchronization. Auto Synchronizing. volt. Typical Generator. the auto synchro. The module senses the three-phase voltage and the three- phase current via PTs and CTs. Upon sending an initiate synchronization discrete signal. reactive power control. Combining several generator control components into one powerful package. Reactive load sharing can be reactive droop or reactive differential (cross-current compensation). The module provides real load-sharing and reactive load sharing.GENERATOR CONTROL AND PROTECTION General. Combination Generator Control nizer brings the generator into frequency. and generator protection functions into one module. Figure 6. Exciter. The CGCM communicates with the programmable controller via high speed ControlNet 1. The CGCM (Fig- ure 6) combines load share. The control system includes an auto synchronizer for the closure of the unit circuit breaker. The module performs synchronization in combination with the programmable controller software program and voltage regulation via the control of the exciter field current. The current regulation mode allows the operator to adjust the field current manually. It is important to note that the FCR is control monitors the load carried by the not the equivalent of an independent manual turbine generator set and adjusts turbine voltage regulator. since it uses some of the same fuel flow to maintain a constant load under circuitry as the automatic voltage regulator. conditions of varying infinite bus frequency. The import control monitors the load that is being imported Automatic Voltage Regulator (AVR) from the utility source and adjusts the tur. KW Control – The kW control system operator a manual voltage regulator. Power factor and tects the turbine against excessive kW kVAR control can be enabled or disabled by the load. Three types of kW load control are available: No Load to Full-Load Accuracy 1. FCR mode. the entire load within the plant. This control is for applications Field Current Regulator (FCR) where it is desired to prevent any power from being exported to the utility. the steam production alleling is possible with other controllers of similar control could modulate the kW control set type. The cross-current compensation method of par- eration application. (kVAR) output or constant power factor (pf) on If the selected value exceeds the turbine the generator set when the unit is operating in capacity.5. infinite bus or other large source. the automatic voltage regulator is ating in parallel with a large source.8-power factor and unit. The voltage droop is adjustable for a constant level within the capacity of the maximum of 10% droop at 0. The error signal for Steady-State Stability the voltage and phase comes from the CGCM. This gives the 2. nominal value is ±10%. Voltage metering accuracy is control allows the import of unlimited ±0. When the generator KW Control (Optional). the voltage regulation varies no more than control system controls the real load (kW) on a unit operating in parallel with a large ±0. This uses the same CT that is used if reac- point. while the cross-current compensation and no droop voltage remaining unit capacity is being exported control are selectable via ControlNet 1. Steady-state voltage regulation is defined as constant frequency and load.2%. In addition. In this mode. tive voltage droop is selected instead of cross- current compensation.5. The resolution of the set amount of minimum load. KW Export Control – The kW export control limits the amount of power that is KVAR/Power Factor Control (Optional) being exported to the utility or large source. Reactive droop. the gen- load on a generator operating in parallel with an erator voltage varies no more than ±0. The turbine T5 limiter system pro. The kW control system provides Reactive voltage droop is possible through the additional operational flexibility by allowing use of a single externally provided current trans- unit kW load level to be set at any desired former (CT). KW Import Control – The kW import At constant frequency and at rate power factor. and phase compliance and sends a signal to VOLTAGE REGULATION close the unit circuit breaker. source such as a utility.1%. to the utility.1%. The voltage adjustment range about the selected bine generator output to maintain a pre. The disabled. operator from the VDU. to modulate steam production in a cogen. then the T5 limiting control pro. For example.age. The communication is via ControlNet 1. CONTROL AND PROTECTION vides protection against excessive kW load while in parallel with an infinite Reactive Voltage Droop source. the kW control set point can be the manipulated variable in Cross-Current Compensation the process control loop. 3. During the controls the real load (kW) on a unit oper. Controls the real kilowatt is operating steady state at any load.25%. The operator can also 7 . The amount of power that is being This feature maintains a constant reactive load exported is limited to a preselected value. The import voltage is 0. parallel with a large source. the unit may be carrying full rated load of the generator. power while maintaining the minimum power. voltage protection has a timed over-excitation trip. Generator Over Voltage. Loss of Sensing. The ac. is lost. A loss of PMG fault is issued rent. the CGCM will · Rotating diode monitor (58) load share with older controls from Solar. such that two · Phase rotation error (47) or more generator sets may equally share load · Over current (51) when running in parallel. the limiter func. VAR. The unit has an over- tion overrides the action of the CGCM AVR. The unit has an un- Under-Excitation Limiting der-voltage monitor adjustable from 60 to 100% of rated voltage. 8 . exceeds rated frequency for a specified amount curacy is ±0. Both the real and the reactive threshold. Also. The compensation is based on the magnitude of the line cur. component of the current are used. within three cycles (50 msec) if PMG power input age. When the generator voltage zation and excessive end-iron heating during falls below 15% of the rated generator voltage.2% of full scale. When field current exceeds the limits. the preset level.select whether to use kVAR control or power · Loss of PMG (27) factor control and set the set points from the · Loss of excitation (40Q) VDU. The reverse power protection · Generator over voltage (59) pickup level is settable from 1 to 50% of rated · Generator under voltage (27) generator power in increments of 1%. The loss of sensing function is supervised by the loss Line Drop Compensation of operating power function and does not become Line drop compensation is a function of generator active until operating power reaches its minimum output current. of time. and responds in less then three cycles. Current Input Signal Over Frequency. a definite time under-frequency nose and respond to the following events: fault is annunciated. · Over frequency (81O) Kilowatt Load Sharing · Under frequency (81U) · Reverse power (32R) The load-sharing circuitry provides the ability to communicate with another CGCM. voltage monitor adjustable from 100 to 140% of or power factor modes and limits the current to rated voltage in 1% increments. The timed over-excitation protects the con- Over-Excitation Limiting troller and generator from long-term field forcing The over-excitation limiter senses field current conditions. settable in 1% increments. This fea- · Loss of sensing (60FL) ture considers real power only. The load sharing between generators of unequal Over-Excitation Voltage. Generator Under Voltage. A loss of excitation protection fault is issued in order to protect against a The voltage regulator sensing uses three-phase reverse VAR condition in the event the excitation signals. a parallel operation. When generator frequency falls below the rated frequency for a specified The protection functions are designed to diag. Loss of PMG. amount of time. Voltage Input Signal Loss of Excitation. When generator frequency The CGCM uses 5-amp nominal inputs. The over-excitation rating is proportional to their rating. such as · Reverse VAR (40) the LSM module or Woodward 2301 governor. Under-excitation limiting (UEL) limits the decrease in excitation to prevent loss of synchroni. · Over-excitation voltage (59F) Reverse Power. loss of voltage sensing annunciation occurs. It is adjustable from 0 to 10% of rated volt. Protection Under Frequency. an over-frequency fault is annunciated. current is lost. This feature is active if excitation is enabled. adjust the gas generator speed. a fault is issued. eral screens organized by systems and functions to allow the operator to easily locate and monitor Turbine Control Panel a given parameter. Onskid Video Display Unit OPERATOR INTERFACE The video display unit is used to present an ex- The control system operator interface has two tensive selection of the turbomachinery operating major components: the turbine control panel and parameters. When possible and en. five trigger logs containing one-second tag samples surrounding the last five shutdowns. When excitation current is lost and the reverse VAR level exceeds the rated · Backup Active value for a definite amount of time. and an hourly log containing snapshot data for the last 12 months. · Emergency Stop (shutdown without abled. · Normal Stop (shutdown with normal no- load cooldown) Over-Current Protection. Some typical gas turbine TT4000S display and monitoring system. a reverse · Stopping VAR fault is annunciated. annunciates alarms. which allows the operator to The turbine control panel (Figure 8) provides the input or modify certain values such as process essential controls to start or stop the turbine. Basler Electric Time Characteristic · Start curve S2. Operation Indication Lights · Starting Reverse VAR.Phase Rotation Error. a phase rotation check is performed prior cooldown) to initiation of breaker closure. reports on the lockable positions) running status of the equipment. The rotating diode monitor is capable of detecting one or more open · Backup System (Active/Reset) or shorted diodes in the rotating field. The TT4000S display and monitoring system uses the Embedded Windows NT operating system and offers the following industry standard features: · Complies with Transmission Control Proto- col and Internet Protocol (TCP/IP) · Supports Object Linking and Embedding for Process Control (OPC) · Supports ActiveX controls · Can be integrated as part of a local area network for sharing of data or remote dis- Figure 8. It also includes a password- protected screen. The display system consists of sev- the video display unit. Data storage consists of an alarm / event log containing the last 5000 events. 99-1595. Operator Interface play communications 9 . and provides a comprehensive set of analysis tools. which controls and indications that appear on the con- performs several key functions to facilitate opera- trol panel include the following: tion of the turbomachinery equipment through a user-friendly interface. to control set points. If a failed diode is detected. · Horn Silence (audible alarm) · Acknowledge (alarms and shutdowns) Rotating Diode Protection. The TT4000S system Operation Switches monitors the turbine and driven equipment pa- · Off/Local/Remote (control selector with rameters. and other op- The onskid VDU makes use of Solar's tional control functions. Over-current protection must be provided with a short inverse time · Speed Control (increase and decrease) characteristic. The screen displays each individual thermocouple temperature. the VDU · Strip Chart shows the various logic and timed sequences · Maintenance Modes involved from initiation of start-up to running con- · VFD Configuration dition. screens. During the package start sequence.Standard Display Screens The display screens listed below are for a typical package and are provided as standard equipment for all turbine packages: · Main Menu · Operation Summary · Engine Temperature · Shaft and Bearing · Lube System · Generator Summary · Bus Summary · Generator Control Modes · Generator Set Points Figure 10. as well as the calculated averages. fuel command · Enclosure status. and lube pump operation. operation mode. the operator the ability to view the selectable view thus. (Figure 9) This screen provides identify the source of the starting problem and. Typical Engine Temperature and driven equipment operating parameters. Engine Temperature Display Screen. shutdown · Alarm Summary status. (Figure 11) This screen displays all the turbine-related temperatures monitored on the unit. This feature is a valuable troubleshooting resource for operations personnel to quickly Menu Screen. Figure 9. Typical Menu Screen Operation Summary Screen. (Figure 10) This screen provides a view of the overall gas turbine Figure 11. fuel selection. Typical Operation Screen · Gas Fuel System · Liquid Fuel System generator data. The Screen screen displays turbine engine temperatures. This screen · Alarm Log also displays the starting and stopping se- · Event Log quences. reach a faster solution. control mode. 10 . set points. Figure 15. (Figure 17) This screen is a summary of the real-time generator screen allows the operator to change set points operating data provided by the control system. The screen displays the bearing temperatures for engine and generator. (Figure 13) This screen displays all pertinent data for the lube oil. Generator Summary Screen. such as pressure. Typical Generator Summary Screen Bus Summary Screen. Typical Shaft and Bearing Screen the control system. (Figure 12) This screen shows a bar graph representation of the vibration levels of the engine and generator as detected by the vibration monitoring system. Typical Lube Oil Screen the control mode desired through the use of pop- up screens. along with crease/Decrease switch. including Circuit Breaker Trip and Auto Sync Initiate control. values are viewed from this screen as well. (Figure 16) This screen allows the operator to view the status of the various generator control modes and to select Figure 13.Shaft and Bearing Screen. along with the manual “backup pump” test function. by means of a pop-up screen or the local In- including operating modes. The set point and actual AC calculated and monitored values. Typical Lube System Screen. Figure 14. Typical Bus Summary Screen Generator Control Screen. temperature. (Figure 15) This screen is a summary of the real-time generator and customer bus operating data system provided by Figure 12. 11 . and the status of the pumps. (Figure 14) This Generator Set-Point Screen. the operator can transfer fuels from this screen. Enclosure Screen. 12 .Figure 16. (Figure 18) This screen displays all of the pertinent data for the gas fuel system. Typical Generator Control Figure 18. flow. Typical Gas Fuel Screen Modes Screen Figure 19. Typical Generator Set-Point Screen Gas Fuel Screen. For a dual fuel system. such as fan. (Figure 19) This screen displays all of the pertinent data for the liquid fuel system. and status of the fuel valves. (Figure 20) This screen displays information related to the enclosure de- Figure 20. For a dual fuel system. such as pressure. actuator. actuator. Liquid Fuel Screen. the operator can transfer fuels from this screen. such as pressure. Enclosure Screen vices. temperature. and gas sensor. Typical Liquid Fuel Screen Figure 17. and status of the fuel valves. flow. the Acknowledge button on the control panel must not be pressed. Figure 23. however. and key sequencing and status signals. Press- ing the Acknowledge button does not eliminate unacknowledged alarms from the controller's alarm buffer. The resolution of the alarm order for be used to audit package operation or to identify this feature is the time of one programmable malfunctions that have occurred and areas of the controller scan. Up to 22 alarms can appear. As the malfunctions are acknowledged. (Figure 21) This screen displays all alarm and shutdown annunciations with a time and date stamp. time-stamped listing of events in the order in which they occurred. Alarms are time stamped in the order in which they are re- ceived from the programmable controller. reading the controller's first out alarm buffer. Note: If the First Out Alarms display is to be used to diagnose a shutdown. alarms and shutdown annunciations. Figure 22. On the display. starting at the first unacknowledged alarm. Typical Alarm Summary Screen ing. As long as the Reset button is not pressed. the unchanged contents of the controller alarm buffer can be viewed as described above. alarms are shown in yellow and shutdowns in red. Typical Discrete Event Log Display Screen 13 . but it changes an alarm index so that the First Out Alarms display cannot access them. These include operator command. Events can be selected by double clicking on the column head- Figure 21. First Out Alarm Screen Discrete Event Log. they stop flashing and are shown in the corresponding colored text until they are cleared from the system and the Reset switch is pressed. It is possible to have multiple events with the same time stamp due to the update rate of the display system. The first four malfunctions detected are displayed at the top of all screens until cleared. (Figure 23) This feature monitors and records the changes in status of all defined discrete (switch or binary) inputs. The controller updates this buffer each scan. Right clicking anywhere on the screen and selecting the Reports menu can easily create reports. (Figure 22) This feature provides a historical record of This screen displays the order in which alarms sequence and status events that changed. It can occurred. Only unacknowledged alarms appear on this screen. Up to 500 events can be stored in the log.Alarms Summary Screen. First Out Alarms Display Screen. Unacknowledged alarms are shown in reverse video. They are displayed as a chronological. These data are obtained by operation that need attention. Parameters are selected by assigning each pen a value. The screen displays in real-time up to 10 variables selected by the operator. (Figure 26) This the particular area of interest. line weights. Each of the plots is scaled for the selected variable and displays the actual numerical value for each variable. Typical VFD Configuration Screen Maintenance Screen. The date range and scaling can be changed by double clicking on the desired pen to bring up the configuration pull-down menu. 14 . Each pen can be assigned different colors. and symbols to make each monitored value easily distinguished from one another. Figure 24. The Figure 25. or seconds. hours. minutes. screen allows the operator to configure the VFD motors and monitor the performance of the motors. (Figure 24) This function emulates a 10-pen strip chart recorder. The "zoom" feature allows the user to zero in on VFD Configuration Screen. The bottom of the strip chart screen displays the corresponding legend for each pen. Typical Strip Chart Screen Figure 26. the values can be analog or binary data available for monitoring. (Figure 25) This screen allows users to perform routine maintenance on the turbine and displays information such as engine hours and engine starts.Strip Chart Function. Typical Maintenance Screen time axis on the strip chart can be configured for each pen by date. Programming Terminal. cal logic and constants accessible. along with software and a programming display purposes: manual to allow for field programming of the control system logic within the control system. The system includes an automatic optical integrity feature. releasing the extinguishing 1. and change mode of operations) One characteristic of the control is that it can be reprogrammed using optional software with criti. or other supervisory system is tecting a fire. bines representative. data acquisition (SCADA). The primary fire detection sys. Analog operating set points (kW control. 2. and a °C PMCIA Type II interface card to allow field pro- Metric bar °C mm gramming of the control system and logic. FIELD PROGRAMMING acknowledge/reset. speed. An open circuit. and voltage) 15 . control con- FIRE DETECTION AND SUPPRESSION sole labels. In receiving this signal. system (DCS). and have the con- fault condition. 3. age is available to be accessed by the supervi- the explosionproof control heads activate the dis. the detectors transmit an Data for Transmission electrical signal via the fire system controller and the fire system supervisory panel to activate the The following information from the turbine pack- fire suppression system. 1.Optional Control and Display Features Other hardware and software options are avail. stop. obtain data. ground mable controller. Discrete control commands (start. control and display fea. Limited secu- able that provide additional flexibility and capabil. 2 Metric kg/cm °C mm LANGUAGE The turbomachinery package labels. Turbotronic 4 control systems can be A fire system supervisory release panel is provided with an interface that allows the super- furnished whose primary purpose is to supervise visory system to communicate with the program- the fire system circuitry. The field programming kit in- Metric (SI) kPa mm cludes software. Type Pressure Temp. Discrete alarms and shutdowns pression system achieves a static air condition and then floods the enclosure with the proper The following information can be sent by the su- concentration of suppressant to extinguish the pervisory system: fire. Communication between the gas turbine control The secondary detection system uses rate. A computer specifically ENGINEERING UNITS configured for programming the programmable controller control logic and sequences is pro- The following engineering units are available for vided. or loss of integrity in the electrical trol capability required. tem uses ultraviolet (UV) detectors. pf. programming manual. The two detec. tions are possible with appropriate software. please contact a Solar Tur- in the enclosure. available. distributed control tion systems act completely independent in de. tures are described in this section. wiring results in a trouble signal. These software. and operator interface screen dis- SYSTEM plays are available in numerous languages. rity to prevent inadvertent programming changes ity to the basic programmable controller control is built in. For A fire detection system is available for installation languages available. If a fire is sensed. system and the user's supervisory control and compensated thermal detectors. but predetermined programming altera- system. Length English psig °F inches Programming Kit. Discrete status values trips that close all vent openings. The fire sup. sory system: charge valves on the primary and extended extinguishing cylinders. Analog instrumentation values agent into the enclosure and pressurizing the 2. kVAR. COMMUNICATIONS – TURBINE CONTROL which provides a continuous check of the optical TO SUPERVISORY SYSTEM surfaces and detector sensitivity. The most common in- of the transmitted data. uses an internal proprietary bus protocol called RS485). RS422. Ethernet TCP/IP. Commu. and “control and information protocol” (CIP). The user's supervisory ticular application. The Allen-Bradley the user’s application: communications software RSLinx provides all the Remote Video Display Unit Auxiliary Video Display Unit with CNet1. See Figure 27 for a typical communica- nication modules allow different communication tion network layout. The specific addressing for the data transfer necessary drivers to communicate with all turbine is provided for each turbine package. Cer. Modbus. The RSLogix controller clude serial communication (RS232. network to help select the optimum interface for DF1.5 Hardwire Interconnect VFD(s) ControlNet 1. Each communication network has certain ad- tain arrays of information inside the controller can vantages and disadvantages that need to be be configured to mimic PLC-5 data tables that considered when selecting a network for a par- support the DF1 protocol.5 (NAP connection) Heat Recovery System Local Programming Terminal (for use during commissioning) Figure 27.” The There are many ways to interface with the gas protocol defines the sequence and organization turbine control system. networks to interface with this internal bus. The communication language used between pro- Supervisory Interface Options grammable controller systems usually follows a set of rules or format called a “protocol. package control networks and network devices (except Modbus) and is required for most appli- Protocol cations. or Modbus protocols.5.5 PCIC Basic Configuration Line Printer Options RS232 Ethernet Modbus Ethernet TCP/IP RS232 SCADA/DCS KFC15 Onskid Control Box ControlNet Module Ethernet Module Modbus Module Backup Relay ControlLogix Shutdown System Flex I/O (Normal Input/Output) Redundant ControlNet 1. ControlNet 1. Below is a description of each system must be programmed to handle the CIP. Typical Communication Network Layout 16 . computer system. the communi. the communication is deterministic. 1219 m (4000 ft) for RS422/RS485 · Maximum number of nodes: unlimited (8 to 24 nodes per hub typical) 17 . The turbine package Ethernet module is usually connected to a local This is an Allen-Bradley developed proprietary hub that is connected to an Ethernet backbone field bus network. devices. (common office computer network technology).2 kbps Supervisory interface (RS232C) with the turbine · Maximum number of nodes: 32 (RS485) via ControlNet is allowed only through a serial link connection module (KFC15) or a separate Typical Application. work can be increased by adding repeaters or RS485). 10BaseFL fiber lines sup- interface modules can be configured for redun- port 2000 m (6560 ft) segments. a central or plant control sys- vices are not compatible with older ControlNet tem. The maximum dis. dant media. Serial link communication allows connectivity of cation is non-deterministic. 115. devices without special communication modules nectivity is well known throughout most industries to communication networks. Ethernet TCP/IP Remote RS232/422/485 Serial Link Data transmission rates are high. quisition system. used to connect the distributed I/O modules to 1219 m (4000 ft) for RS422/RS485 the controller for turbine control. Data transmission rates are for data transfer to a remote supervisory system high. It is used to transfer · Protocol: CIP I/O and register data between Modbus control · Topology: Trunk line/drop line. The via the network access port (RJ-type) located on user provides the Modbus master device. may be a supervisory control system. a data ac- rent ControlNet 1. a remote monitoring system or some other 1. and all over longer distances. Modbus Slave · Physical media: quad shielded RG-6U coaxial cable The Modbus protocol is an open.5 Typical Application. and cabling and con. Onsite. The Modbus Interface op- ControlNet network that is not directly connected tion gives the turbine package control system the to the turbine I/O network.5 networks and network de. which the interface module or Flex I/O adapters. ability to communicate with a Modbus master tance and number of nodes allowed for the net. star with repeaters · Maximum distance (per Rockwell · Physical media: shielded twisted specifications): 1000 m (3280 ft) with conductors 2 nodes. Field pro. device through a serial interface (RS232. VDUs are typically connected directly to this I/O network · Maximum data transmission rate: via PCC or PCIC cards installed in the computer. This is the control network specifications): 15 m (50 ft) for RS232. The turbine package control system and/or by using optical fiber media. RS422.ControlNet 1. Cur. · Physical media: shielded twisted · Physical media: twisted pair (10BaseT) conductors · Protocol: CIP over TCP/IP · Protocol: N/A · Topology: star · Topology: point-to-point (RS232/RS422) · Maximum distance (per Rockwell or multi-drop (RS485) specifications): 100 m (328 ft) to hub · Maximum distance (per Rockwell · Maximum data transmission rate: 10 Mbps specifications): 15 m (50 ft) for RS232. acts as a Modbus slave device using a subset of gramming terminals can connect to the network the RTU version of the Modbus protocol.25 networks or network devices. published and widely implemented protocol. 250 m (820 ft) with 48 nodes · Protocol: Modbus RTU · Maximum data transmission rate: 5 Mbps · Topology: point-to-point (RS232/RS422) · Maximum number of nodes: 48 or multi-drop (RS485) · Maximum distance (per Rockwell Typical Application. The @ 40 ft (RS422/RS485) total ControlNet cable run must be no longer than 762 m (2500 ft). 100 kbps @ 4000 ft/10 Mbps onskid controller through ControlNet 1. The auxiliary auxiliary VDU through Ethernet. The application software sists of an industrial desktop computer equipped on the remote supervisory system must handle with TT4000. leaving send and receive data to and from the ControlNet 610 m (2000 ft) for the auxiliary VDU cable run. 1 month of daily files with The viewing of historical data from the remote data points taken every 2 minutes VDU may be noticeably slower depending upon – 10-Second Log. Cable run lengths for the auxil- · Maximum number of nodes: 32 (RS485) iary VDU vary from project to project depending upon how close the motor control center is to the Typical Application. The auxiliary Auxiliary Video Display Unit VDU option is a prerequisite for the remote VDU The auxiliary video display unit (VDU) consists of option.) · Accommodates Additional Options – Gas turbine performance calculations and display – Printer – Remote VDU · Higher Resolution Screen · More Memory. including RAM and Non-Volatile Storage · Incorporates Visual Basic for Application (VBA) · DVD Reader / CD Writer Figure 28. mounted VDU plus the following enhancements: Distance is limited only by the customer’s network. (The onskid VDU stores 5 triggered files. A gas turbine performance map for the predicted rating of a gas turbine at standard condi- · Larger Trigger Log. interconnect is the responsibility of the customer. The remote VDU has all the fea- either DF1 or CIP communication protocols. The Ethernet VDU has all the features of the standard skid. · Maximum data transmission rate: 20 kbps The auxiliary VDU communicates with the (RS232). tures of the auxiliary VDU with the exception that some of the operational privileges are limited at VIDEO DISPLAY OPTIONS the remote VDU. A remote serial link is pro- gas turbine. Remote Video Display Unit since this device can only handle local messag- ing (communication through other remote net. network via an external Allen-Bradley KFC15 Note: these distances are reduced if high flex communication module (RS232).5. Typically. the cable run without the vided to allow a remote supervisory system to auxiliary VDU is less than 150 m (500 ft). Gas Turbine Performance Map 18 . each containing 6 minutes of 1-second data points. Supervisory cable is used. – 2-Minute Log. lockout shutdowns cannot be reset remotely. Algo- function stores up to 25 triggered files. the speed of the customer-supplied network. The Trigger Log tions is displayed on the VDU (Figure 28). an industrial desktop computer and the TT4000 The remote VDU communicates with the display and monitoring system. For example. The remote video display unit (VDU) option con- works is not allowed). Both the remote VDU and the auxiliary · Additional Historical Data VDU come with an Ethernet port and modem. second intervals for the last 14 days. serial interface through the DH+ network using a remote KF2 interface module is not advised. Data are read at 10. · Reports – On demand. calculated variables. 19 . includes a printer. hot gas path. prints current tion since the data are standardized for the actual values of standard analog variables and operating point and not just optimum. inlet vides for a variety of reports and event logging. A key performance indicator is provided for display by calculating the · Alarm and Shutdown Log – Prints one differential value (actual minus predicted) of the event per line with time and date stamp. to corrective and diagnostic action required.rithms convert site data to standard conditions Printer/Logger Option and the operating point is displayed real time on This option is available with the auxiliary VDU. gas turbine temperature. and software and pro- Digital values for the predicted power. It the map at the intersection of X and Y cursors. digital values. Standard totalized Information gained from this feature can point variables may be printed also. and compressor discharge pressure are Features provided are: also displayed on the screen. such · Print Screen – On demand. The trend of these parameters provides a true indication of performance degrada. prints any as washing the compressor and borescoping the screen that is currently being displayed. cable. fuel flow. air temperature. 4 to 20 mA Low level temperature RTD High level temperature thermocouple Speed signal magnetic pick-up · Output Signals Discrete 24 Vdc. Analog signals. 0. typical 22 gauge for low level shielded wire 12 gauge for most power wire Wire identification. 2 amps max.Appendix A: Hardware PHYSICAL HARDWARE · Programmable Controllers Allen-Bradley ControlLogix · I/O Allen-Bradley Flex Modules · Voltage Regulator Basler Electric/Allen-Bradley Combination Generator Control Module (CGCM) · Onskid Display Allen-Bradley 6181 · Power Supply 120 Vdc to 24 Vdc · Transducers 4 to 20 mA · RTDs Platinum 100 Ohms a = 0.5 amp max. 3 to 10 amps 120 Vac.) All customer connects are to Flex I/O or terminal blocks on DIN rail ELECTRICAL SPECIFICATION · Input Power 120 Vdc · Internal Power 24 Vdc · Input Signals Discrete signals. branded every 152 mm (6 in. 4 to 20 mA · Relay Rating 24 Vdc. Discrete 24 Vdc.12 amps ENVIRONMENTAL SPECIFICATION · Operating Temperature 0 to 60°C · Storage Temperature -40 to 85°F · Relative Humidity 5 to 95% non-condensing · Vibration 1g peak 5 to 20 Hz · Area Classification Nonhazardous RFI/EMI SUSCEPTIBILITY AND EMISSION Similar equipment has been tested to the specification list below and passed the test successfully: · IEC 801-2 Electrostatic Discharge Level 3 · IEC 801-3 Radiated Immunity Level 3 · IEC 801-4 Fast Transient/Burst Level 3 · IEC 801-5 Electrical Surge Immunity Level 3 · IEC 801-6 Conducted Emission Level 3 · CISPR/B Conducted Emission Class A · CISPR/B Radiated Emission Class A 20 . 24 Vdc Analog signals.00385 · Control Enclosure NEMA 4 or NEMA 4X · Backup Controls Backup overspeed box Backup relay shutdown system · Internal Wiring 20 gauge. Model 1794-IE8 Series B · Channels 8 · Signal Rating 4 to 20 mA. such as from RTDs. 2. Used with the 1756 chassis to provide power directly to the chassis backplane: · Model 1756-PB72 · Input Voltage 24 Vdc · Input Power 97 W · Backplane Output Current 1.00 A @ 3. pressure switches.0 A @ 5.50 A @ 1.5 Mbytes of user memory and can be connected in a variety of networks for interconnection with computers. These modules receive input from on/off devices such as level switches.0 Vdc 2. This module drives devices such as solenoid valves and motor contactors.2 Vdc 4. The Allen-Bradley Logix5555 processor has 1. such as current transmitters. ± 10 V. and distributed I/O: General Specifications · Processor for Logix5555 1756-L55M13 · Environmental Conditions – Operational Temperature 0 to 70°C (32 to 158°F) – Storage Temperature -40 to 85°C (-40 to 185°F) – Relative Humidity 5 to 95% (without condensation) · Vibration – Operating 10 to 500 Hz. 0 to 20 mA. others accept low-level signals.Appendix B: Technical Supplement HARDWARE INFORMATION ControlLogix Processor. 0 to 10 V 21 . distributed processing. ControlLogix Power Supply. relays and protective equipment: · Model 1794-IB16 · Channels 16 · Signal 10 to 32 Vdc Discrete Output Module. push buttons.3 Vdc 10.2 to 32 Vdc (24 Vdc nominal) · Integrated Battery Each Logix5555 processor is shipped with a battery installed for memory backup (part number 1756-BA1).80 A @ 24 Vdc Discrete Input Modules.0 g maximum peak acceleration Electrical Specifications · Operating Voltage 19. Current Rating Model Channels Signal Per Channel Per Module 1794-OB16P 16 10 to 32 Vdc 0. Some modules accept signals from high-level output devices.5 8 1794-OB8EP 8 19 to 32 Vdc 2 10 Analog Input Modules. Analog Output Modules. 0 to 20 mA · Output Voltage ± 10 V. During commissioning tests onsite. The unit is operated with its control system. Pre-Test. ± 5 V. any further software changes that are found to be necessary are included in the “as installed” software. Groups A. AREA CLASSIFICATION Nonhazardous. Zone 2. 5 V HARDWARE CERTIFICATION In general. Allen-Bradley components are SA and ATEX certified for Class I. Commissioning.767 Hz max. 1. B. Model 1794-IE8 Series B · Channels 4 · Output Current 4 to 20 mA. These modules are used for drive-positioning devices such as the fuel throttle valve and to provide analog signals to other instrumentation. 22 . Static Test. QUALITY ASSURANCE Complete control systems are put through three test phases at Solar: static test. C. pre-test. CONTROL CONSOLE LAYOUT The basic arrangement for the programmable controller is to have one seven-slot 1756 I/O chassis and power supply similar to the one seen in Figure 29. 4. Division 2. Separate scaling and cold junction compensation is required. The software used for this test is the “as-shipped” software (excluding Titan gas turbines). and final test. Further tests are made during installation and commissioning. The programmable controller module is in the left- most slot and all other applicable modules occupy the six remaining slots. high resolution speed measurements Model 1794-IRT8 · Channels 8 · Inputs Ranges -40 to +100 for thermocouples 0 to 325 mVdc for RTDs 0 to 500 ohm for resistance range · Usage High-speed module used for temperature measurements. · Usage Fast. Final Test. This assembly is mounted on a panel (Figure 30) attached to the back wall of the console. 3. 2. where final package and control tests are made.Model 1794-IJ2 · Channels 2 · Inputs per Channel 2 (frequency and gate) · Frequency 32. 0 to 10 V. The controller is mated with the unit it is shipped with and is used to verify correct skid wiring and certain statically tested functions. Verifies the correct console wiring and software was installed. including the standard options and nonstandard features required for the project. and D. ControlLogix Chassis Configuration Figure 30. Generator Control Panel and Turbine Control Panel Internal Configuration 23 .Figure 29. It provides only limited data storage capability. TT4000. TT4000S. Video Display Unit – a generic term for a Onskid Control System computerized display device. lier systems. It mirrors grammable logic controller (PLC5) used on ear- the functionality of the primary TT4000 system. usually at some distance away in an unclassified area. installed. The control system is mounted in one or more panels attached to the package skid. The central controlling device. and tested on computer hardware supplied by Solar. the package skid. bomachinery area and control room. This hardware must Onskid. system installed in a desktop PC. such as Solar’s TT4000 product. A Windows 2000 based display and Auxiliary Desktop PC monitoring system that is available with the Tur- botronic 4 system. Turbotronic 4 uses the Allen-Bradley Con- TT4000 Remote. The distance between this PC and the primary which is installed in an onskid VDU (A-B 6183) TT4000 system is limited only by the capability of and makes use of the Windows Embedded NT the network. Remote Desktop PC tensive data storage capabilities in addition to A secondary TT4000 display and monitoring display. The TT4000 display and monitoring system installed in a desktop PC. A version of Solar’s TT4000 software. Control Processor. This is necessary to protect the integrity of the system and avoid any Remote. Solar’s fully featured display and moni. It provides display. the TT4000 application software. tion monitoring system. communications. which replaces the pro- installed on a “remote” PC (A-B 6155). including DESCRIPTIONS the control processor. ery package. and the TT4000S display toring system consisting of a desktop PC (A-B system. It provides ex. Packages with onskid controls may only 6155) configured with the Windows 2000 operat. make up the Turbotronic 4 control system. VDU. the vibra- TT4000. This PC must be linked to the primary TT4000 system via a network connection. and the specific project software files. Located on and permanently attached be dedicated to the TT4000 system and no other to the turbomachinery package skid. the I/O modules. Solar Turbines new package and no more than 762 cable m (2500 cable feet) from control system. be installed in a nonhazardous area. Important Note HMI. communications. and basic control capabilities at the 24 . This is the version of TT4000 trolLogix processor. configured. SYSTEM DESCRIPTIONS Remote HMI implies a secondary HMI system in Figure 31 shows the various components that addition to the primary HMI. The panels HUMAN MACHINE INTERFACE contain the key elements of the system. potential interaction with other software. operating system. Human Machine Interface – the generally accepted industry term for display and monitoring TT4000 is provided only as a complete system systems.Appendix C: Control System Information TURBOTRONIC DEFINITIONS package skid. and control capabilities. Located someplace other than the tur. providing re- It is designed for operation in a nonhazardous mote monitoring and control of the turbomachin- area such as a control room. software may be loaded. This PC must be located Turbotronic 4. ing system. Turbotronic 4 Control System Outline 25 . TT4000S ETHERNET CONTROLNET OR OTHER TT4000 TT4000 CONTROL DESKTOP REMOTE PROCESSOR AND I/O Figure 31. CA 92186-5376 U.A.solarturbines.S.O.com Solar Turbines Incorporated P.FOR MORE INFORMATION Telephone: (+1) 619-544-5352 Telefax: (+1) 858-694-6715 Internet: www. SPTT-PG/802 . Box 85376 San Diego.

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