CONTROL & INSTRUMENT INDEX
SYSTEMS UNDER C&I DEPARTMENT
DISTRIBUTED CONTROL SYSTEM (DCS)
SYMPHONY HARMONY INFI 90 SYSTEM
COMPOSER™ SYSTEM
EMERGENCY TRIP SYSTEM (ETS)
FURNACE SAFEGUARD SUPERVISORY SYSTEM (FSSS)
LOCAL IGNITION CONTROL SYSTEM
UPS GENERAL DESCRIPTION
MULTI FLAME DETECTOR CONTROL UNIT & FLAME
SCANNER
DEH SYSTEM
HART SYSTEM
MACHINE MONITORING SYSTEM (MMS)
TURBINE SUPERVISORY INSTRUMENTATION (TSI)
HPLP BYPASS
CCTV SYSTEM
RUNBACK
MIS SYSTEM (PGIM)
ENTERPRISE ASSET MAINTENANCE (MAXIMO)
GPS SYSTEM
CMS
Systems Under C&I department, SgTPP
IPH SYSTEMS
C&I department is entrusted for maintaining System Automation at all areas of Power Plant except CHP. The areas under their scope is as following:
1. Distributed Control System (Symphony Harmony 50 System, Make-ABB) with its panels, Controllers, Modules, power supply, network & HMI
2. Operating Interface Software (Power Generation Portal, Make-ABB) maintenance, Sequence of Events generation.
3. Operating Interface station (OIS), Engineering Work Station (EWS) & DCS communication with computer management.
4. Logic & Interlock protection software (Composer 4.3 software, Make-ABB) maintenance and development if required.
5. Digital Electro Hydraulic System (DEH, Make-ABB) for turbine governing system
6. Furnace Safeguard Supervisory System PLC (FSSS, Make-ABB) with Master Fuel Trip System (MFT)
7. 90~70 Series Genius PLC for Emergency Turbine Trip System (ETS, Make-GEIP)
8. 3500 Turbine Supervisory Instrumentation (TSI, Make- Bentley Nevada)
9. 90~30 Series Genius PLC for Turning Gear Automatic Control System (Make-GEIP)
10. Different kind of field transmitters for measuring Pressure, temperature, flow,
level, vibration, displacement & gauges like Pressure, temperature, level and different switches for alarm generation and enabling interlocks.
11. Different kind of analytical instruments like Oxygen, CO, dust analyzers, SOX,
NOX, Na, Si, and Conductivity etc. for hydrogen purity, humidity.
12. Boiler tube leakage detection System (Make-Eastern Boiler Co.) & acoustic tube
leakage detector sensors
13. SMART Secondary air Damper Control (SADC) system, Make- CCI KK
consisting 60Nos SAD with local control box
14. SMART Burner Tilting System consisting 8Nos Tilt with local control box 15. Different pneumatic final control elements used in Mill, pyrite system, single &
double acting control valves for different areas.
16. Different electrical actuators for PA fan, FD fan, ID fans.
17. Steam Water Analytical System (SWAS) with Verasamax PLC, Make-GEIP 18. Condensate Polishing System (CPU) Contrologix PLC, Make-Rockwell
Automation
19. Air Pre-heater gap detection system with SLC500 PLC, Make-Rockwell
Automation
20. Air Pre-heater Hot spot detection system with SLC500 PLC, Make-Rockwell
Automation
21. AROS Make 80KVA Dual Uninterruptible Power Supply (UPS) and Ni-Cd
22. Boiler Oil Burner System consisting LFO & HFO Burner System
23. UVISOR 600 IR Multi-flame detector Flame scanner system with Flame explorer
software
24. TZIDC ABB Make SMART positioner for SADC, Burner Tilt 25. DVC 2000 & 6010 SMART Positioners for Control Valves 26. Auxiliary Boiler instrumentation and control system. 27. Flame TV for boiler flame monitoring
28. Closed Circuit TV (CCTV) server and cameras for 55 locations distributed all
over the plant.
29. Online Condenser tube cleaning system (OLTC). 30. Condenser tube leakage system.
31. HPLP Bypass system (Make-CCI) control system and hydraulic controllers. 32. Highway Addressable Remote Transducer (HART) panel with Cornerstone
diagnostic software to enable transmitter calibration from control room.
33. Machine Monitoring System(MMS) for monitoring vibration of different fans and
pumps.
34. Large Video Screen(LVS) in Control room to display plant important data and
soft annunciation. OPH SYSTEMS
35. All Ash Slurry sump level switch, Pressure switch and gauges in Ash Handling
Plant. SILO#1, 2, 3 level transmitters and NUVA feeder(dry ash system) solenoid valves and cylinders.
36. All pressure, flow, level and temperature gauges, switches and transmitters in
Intake pump house, DMP, PTP and Regeneration Building and N-pit.
37. All Conductivity, pH, Si and Na Analyser in DMP and Regeneration Building for
water, acid and caustic quality measurement.
38. All pneumatic solenoid valve operated on-off valves for different ion exchange
vessels (ACF, SAC, WBA, SBA, MB).
39. All pneumatic control valves for degasser water tank recirculation line. 40. All pressure, temperature & level transmitters, level switches, pressure and
temperature gauges for FOPH.
41. All vibration monitoring systems in intake and raw water pump house. 42. Chlorine gas leakage detection systems in RW Chlorination and CW
Chlorination plants.
43. All pressure transmitters, switches and gauges in CW Chlorination plant. 44. All pressure switches and gauges in Fire fighting pump house.
45. All H2 gas leakage detection systems in H2 gas cylinder room.
46. All level switches and indicators, pressure gauges in waste water treatment
DISTRIBUTED CONTROL SYSTEM(DCS)
Adopting the computer, communications and screen display techniques, carry out the data acquisition, control and protection functions etc. for production process. It is a multi-computer monitoring system based on communication and data share techniques, which possesses the following features, distributed functions,
concentrated display, data, share, high reliability. It can be distributed by the hardware arrangement according to the concrete circumstances.
DCS comprises of following functional segments :
1. Distributed Control System (Symphony Harmony INFI 90 System, Make-ABB) with its panels, Controllers, Modules, power supply, network & HMI
2. Operating Interface station (OIS), Engineering Work Station (EWS) & DCS communication by CNET with computer management.
3. Operating Interface Software (Power Generation Portal, Make-ABB) maintenance, Sequence of Events generation.
4. Logic & Interlock protection software (Composer 4.3 software, Make-ABB) maintenance and development if required.
SOME DEFINITION AND ABBREVIATION ● Distributed control System, namely DCS ● Date Acquisition System, namely DAS ● Modulation Control System, namely MCS ● Coordinated Control System, namely CCS ● Automatic Generation Control, namely AGC ● Sequence Control System, namely SCS
● Furnace Safeguard Supervisory System, namely FSSS ● Master Fuel Trip, namely MFT
● Digital Electro- Hydraulic Control, namely DEH
● Automatic turbine startup or shutdown control system, namely ATC ● Over- speed Protection Control, namely OPC
● Uninterrupted Power Supply namely UPS.
● Supervisory information system of the plant 1evel, namely SIS ● Turbine supervisory instruments, namely TSI
● The field bus control system, namely FCS
Following technical terms, definition and abbreviation is applicable to this standard
Adopting the computer, communications and screen display techniques, carry out the data acquisition, control and protection functions etc. for production process. It is a multi-computer monitoring system based on communication and data share techniques, which possesses the following features, distributed functions, concentrated display, data, share, high reliability. It can be distributed by the hardware arrangement according to the concrete circumstances.
2 Date Acquisition System, namely DAS
DAS is a supervision system, which is adopted digital computer system to detect the operating parameters, states for technique system and process, record, display and alarm to detecting results, calculate and analyze the operating conditions, provide operating instruction.
3 Modulation Control System, namely MCS
MCS is a system that carries out the boiler, the turbine and the auxiliary system parameter automatic control. In this system, it includes the parameters automatic control and deviations alarming. For the former the, its outputs is a continuous function of inputs. It can be called the closed loop control system CCS in outward document.
4 Coordinated Control System, namely CCS
UCC is a control system, which controls the boiler and the turbine as a whole, corresponds boiler and turbine to work through control loop under the automatic mode, sends the demand to boiler and turbine automatic control system in order to adapt the variation of load.
5 Automatic Generation Control, namely AGC
AGC is an automatic control system that controls the power according to the power grid load demand.
6 Sequence Control System, namely SCS
SCS is an automatic control system that controls a certain techniques system or main auxiliary equipment according to a certain disciplinarian (input signal condition sequence, action sequence or time sequence).
7 Furnace Safeguard Supervisory System, namely FSSS
FSSS is an automatic control system for boiler ignition and oil gun action program to prevent the furnace explosion (outside explosion or inside explosion) caused by boiler extinguishing, overpressure etc. The FSSS includes the Burner Control System (BCS) and the Furnace Safety System, (FSS)
8 Master Fuel Trip, namely MFT
MFT is a control measures that operates by operator or operates by the automatic protection signal to cut off all fuels for boiler.
9 Digital Electro- Hydraulic Control, namely DEH
computer, amplifier designed by hydraulic pressure principle and hydraulic pressure servo mechanism.
10 Automatic turbine startup or shutdown control system, namely ATC
ATC is an automatic control system that controls the turbine to complete the startup, synchronization procedure according to the thermal stress or other parameters of turbine.
11 Over- speed Protection Control, namely OPC
OPC is a control function that can prevent overspeed. There are two ways to realize this function, acceleration limit or double positions control. The former can generates an override instruction to close down the high-pressure, mid-pressure regulating valve if turbine in overspeed operation. If the acceleration equals zero, the OPC maintain the normal speed for turbine. The later can close the high-pressure, mid-pressure regulating valve if the speed equals 103% of rated speed.
12 Uninterrupted Power Supply namely UPS.
13 Supervisory information system of the plant 1evel, namely SIS
SIS provides the real time information and processed information, real time monitoring and management service for plant level personnel, failure judgements for dispatch center. It also supports the power unit level information process.
14 Turbine supervisory instruments, namely TSI
TSI represents the instruments used for supervising state (speed, vibration, expansion, displacement etc.)
15 The field bus control system, namely FCS
FCS is a distributed control system that based on field bus techniques. It connects the field measurement, control devices, into a network system according to public and normative protocols to realize the data transmission.
Symphony Harmony INFI 90 System
Harmony Rack Controllers
The Harmony Rack Controllers are high-performance, high capacity process controllers. They are designed to interface with Harmony block I/O in the Symphony Enterprise Management and Control System. The Harmony rack controllers are fully compatible in functionality, communications, and packaging. The Harmony rack controllers collect process I/O, perform control algorithms and output control signals to process level devices. They also import and export process data from and to other controllers or other system nodes, and accept control commands from operators and computers connected to the network. The controllers communicate on the Control way with other rack controllers. They communicate with other system nodes on the control network (C net) via Harmony rack communication modules.
Description
The Harmony rack controllers refer to a series of three controllers differentiated by their configuration memory capacity, execution speed and I/O support. The Harmony Bridge Controller (BRC-300) can support block and rack I/O simultaneously. The Harmony Multifunction Processors (IMMFP11 and IMMFP12) support only rack I/O. Each controller occupies a single slot in the module mounting unit. It consists of a single-board module that plugs into the module mounting unit. In the case of the
Harmony Bridge Controller, a Process Bus Adapter card is connected at the rear of the module to provide cable connections to the Harmony I/O subsystem and termination unit. As is standard, the module mounting unit provides built-in connections for rack modules. The Harmony rack controllers use a powerful 32-bit processor. On-board nonvolatile storage is provided for the control algorithms and user configurations. LEDs on the module front-plate display
error messages and diagnostic data. One red/green LED displays module operating status.
Harmony Rack Input / Output
The Harmony Rack Input / Output (I/O) system utilizes a wide variety of input, output, and signal conditioning modules to interface process signals to the Symphony Enterprise Management and Control System. Module types, ranging
from standard analog and digital I/O to specialty I/O such as turbine control, field bus, and sequence of events, can be combined to provide a comprehensive set of functionality to meet all market and industrial requirements.
The main components of Harmony rack I/O are I/O modules, termination units, and the I/O expander bus. The Harmony controllers and rack I/O modules communicate over I/O expander bus. Together a controller and its I/O modules form a subsystem within the Symphony system. The controller performs the actual control functions; the I/O modules process any inputs from and outputs to field devices for the controller.
The termination units provide field wiring termination for I/O modules. The controller can communicate with up to 64 I/O modules connected to the I/O expander bus. The rack I/O module types include:
Analog input (ASI, FEC). Analog output (ASO). Digital input (DSI, DSM). Digital output (DSO).
Specialized input/output (FCS, HSS, SED).
IMHSS03 Hydraulic Servo
The IMHSS03 Hydraulic Servo module is a valve position control module. It provides an interface through which a Harmony controller can drive a servo valve or I/H converter to provide manual or automatic control of a hydraulic actuator. The controller utilizes function code 55 or 150 (hydraulic servo) to configure and access the module input/output channels. Typical uses for the module are positioning of steam turbine throttle and control valves, gas turbine fuel valves, inlet guide vanes, and nozzle angle. By regulating the current to the servo valve, the IMHSS03 module can initiate a change in actuator position. The hydraulic actuator can then position, for example, a gas turbine fuel valve or a steam governor valve. As the valve opens or closes, it regulates fuel or steam flow to the turbine, thus controlling the turbine speed. A linear variable differential transformer (LVDT) provides actuator position feedback to the hydraulic servo module.
The IMHSS03 module is an intelligent I/O module with an onboard microprocessor, memory, and communication circuitry. In most applications, the IMHSS03 module works with the IMFCS01 Frequency Counter module.
I/O Expander Bus
The I/O expander bus is a high speed, synchronous, parallel bus. It provides a communication path between controllers and I/O modules. The I/O expander bus parallel signal lines are located on the module mounting unit backplane. Inserting a rack-mounted controller and I/O modules into the mounting unit connects them to the expander bus.
I/O Module
An I/O module interfaces and processes field device input and output signals. There are several different I/O module types available. Table 1 lists the available module types and gives a brief description. All I/O modules share the same layout and connection, configuration, and mounting methods. Refer to the Harmony Rack Input
Modular Power System
The Modular Power System III (MPS III) is specifically designed for powering Harmony rack modules and associated field mounted devices. The MPS III can provide 5, +15, and 24 VDC system power as well as 24, 48, and 125 VDC for field powered devices. Special features of the MPS III include: power factor correction, on-line power supply replacement, power and cooling status monitoring, and adaptability to various power input sources.
The MPS III supplies 5 VDC, +15 VDC, -15 VDC, 24 VDC, 48 VDC, and 125 VDC power to Harmony rack components of the Symphony Enterprise Management and Control System. Figure 1 shows MPS III power system architecture.
In Figure 1, the 5, +15 and -15 VDC lines shown entering the system power bus bar are the operating voltages for rack I/O devices. The 24VDC (25.5 VDC actual voltage) line shown entering the system power bus bar is I/O power for field devices. Additionally, the power system can provide various combinations of 24, 48, and 125 VDC field power. The major MPS III components consist of a power entry panel, power chassis, power trays, system fan, and bus monitor.
Bus Monitor
The bus monitor checks status and generates a Power Fail Interrupt (PFI) signal in the event of a 5, +15, or -15 VDC bus failure. The bus monitor is located on the back of the power chassis.
Control NET
Control Network, Cnet, is a high-speed data communication highway between nodes in the Symphony Enterprise Management and Control System. Cnet provides a data path among Harmony control units (HCU), human system interfaces (HSI), and computers. High system reliability and availability are key characteristics of this mission-critical communication network. Reliability is bolstered by redundant hardware and communication media in a way that the backup automatically takes over in the event of a fault in the primary. Extensive use of error checking and message acknowledgment assures accurate communication of critical process data. Cnet uses exception reporting to increase the effective bandwidth of the communication network. This method offers the user the flexibility of managing the flow of process data and ultimately the process. Data is transmitted only when it has changed by an amount which can be user selected, or when a predetermined time-out period is exceeded. The system provides default values for these parameters, but the user can customize them to meet the specific needs of the process under control. Harmony rack communications encompasses various communication interfaces as shown in Figure 1: Cnet-to-Cnet communication, Cnet-to-HCU communication, and Cnet-to-computer communication.
Control Network
Cnet is a unidirectional, high speed serial data network that operates at a 10-megahertz or two 10-megahertz communication rate. It supports a central network with up to 250 system node connections. Multiple satellite networks can link to the central network. Each satellite network supports up to 250 system node connections. Interfacing a maximum number of satellite networks gives a
system capacity of over 62,000 nodes. On the central network, a node can be a bridge to a satellite network, a Harmony control unit, a human system interface, or a computer, each connected through a Cnet communication interface.
On a satellite network, a node can be a bridge to the central network, a Harmony control unit, a human system interface, or a computer.
Harmony Control Unit
The Harmony control unit is the fundamental control node of the Symphony system. It connects to Cnet through a Cnet-to-HCU interface. The HCU cabinet contains the Harmony controllers and input/output devices. The actual process control and management takes place at this level. HCU connection to Cnet enables Harmony controllers to:
1. Communicate field input values and states for process monitoring and control. 2. Communicate configuration parameters that determine the operation of functions such as alarming, trending, and logging on a human system interface.
3. Receive control instructions from a human system interface to adjust process field outputs.
4. Provide feedback to plant personnel of actual output changes.
Human System Interface
A human system interface such as a Signature Series workstation running Maestro or Conductor Series software provides the ability to monitor and control plant operations from a single point. It connects to Cnet through a Cnet-to-computer interface. The number of workstations in a Symphony system varies and depends on the overall control plan and size of a plant. The workstation connection to Cnet gives plant personnel access to dynamic plant-wide process information, and enables monitoring, tuning, and control of an entire plant process from workstation color graphics displays and a pushbutton keyboard.
Computer
A computer can access Cnet for data acquisition, system configuration, and process control. It connects to Cnet through a Cnet-to-computer interface. The computer connection to Cnet enables plant personnel, for example, to develop and maintain control configurations, manage the system database, and create HSI displays remotely using Composer™ engineering tools. There are additional Composer and Performer series tools and applications that can access plant information through a Cnet-to-computer interface.
Cnet-to-HCU Communication Interface
The Harmony control unit interface consists of the INNIS01 Network Interface Module and the INNPM12 or INNPM11 Network Processing Module (Fig. 4). This interface can be used for a node on the central network or on a satellite network (Fig. 1). Through this interface the Harmony control unit has access to Cnet and to Controlway at the same time. Controlway is an internal cabinet communication bus between Harmony rack controllers and the communication interface modules. The HCU interface supports hardware redundancy. Redundancy requires a full set of duplicate modules (two INNIS01 modules and two INNPM12 or INNPM11 modules). The secondary network processing module (INNPM12 or INNPM11) continuously monitors the primary through a direct ribbon cable connection. A failover occurs when the secondary detects a primary module failure. When this happens, the secondary assumes responsibility and the primary is taken offline.
Cnet-to-Computer Communication Interface
The Cnet-to-computer interfaces are the INICI03 and INICI12 interfaces. The INICI03 interface consists of the INNIS01 Network Interface Module, the INICT03A Computer Transfer Module, and the IMMPI01 Multifunction Processor Interface Module. The INICI12 interface consists of the INNIS01 Network Interface Module and the INICT12 Computer Transfer Module
Cnet-to-Cnet Communication Interface
The Cnet-to-Cnet interfaces are the INIIR01 Remote Interface and the INIIL02 Local Interface. Figure 2 shows the remote interface and Figure 3 shows the local interface.
The local interface supports hardware redundancy. Redundancy requires a full set of duplicate modules (four INNIS01 modules and two INIIT03 modules). The secondary INIIT03 module continuously monitors the primary over dedicated Controlway. A
failover occurs when the secondary detects a primary module failure. When this happens, the secondary assumes responsibility and the primary is taken offline.
Cnet-to-Cnet Local Transfer Module
The INIIT03 Local Transfer Module serves as the bridge between two local Cnet communication networks. It holds the node database and is responsible for transferring all messages between networks.
Messages include exception reports, configuration data, control data, and system status. This module directly communicates with the INNIS01 module of the central network and of the satellite network simultaneously. The INIIT03 module is a single printed circuit board that occupies one slot in the module mounting unit. The circuit board contains microprocessor based communication circuitry that enables it to directly communicate with its two INNIS01 modules and to interface to Controlway.
Harmony Sequence of Events(SOE)
Harmony sequence of events (SOE) provides distributed event monitoring, recording, and reporting capabilities for the Symphony Enterprise Management and Control System. An SOE event is a transition of a digital signal from either on to off or from off to on. A series of SOE modules collect and time-stamp these digital transition events which are then made available to the system. Figure 1 shows the distributed sequence of events system architecture.
An SOE module consists of a single printed circuit board that occupies one slot in a module
mounting unit (MMU). In general, jumpers and switches on the printed circuit board and jumpers and dispshunts on the termination unit configure the module and its I/O channels. A cable connects the SOE module to its termination unit. The physical connection points for field wiring are on the termination unit.
Server Node
The INSOE01 Server Node consists of the INNIS01 Network Interface module, the INSEM01 Sequence of Events Master module, and the INTKM01 Time Keeper Master module.
INSEM01
The INSEM01 Sequence of Events Master module communicates with the INNIS01 Network
Interface module and the INTKM01 Time Keeper Master module. The INNIS01 module is the
front end for all Cnet (control network) communication interfaces and is the intelligent link
between a node and Cnet. The INSEM01 module communicates directly with the
INNIS01 module.
The INSEM01 module is responsible for managing the distributed sequence of events system,
which includes managing:
1,500 points coming from the SOE I/O modules in up to 1,000 Harmony
control units (HCU).
256 complex triggers with 16 operands each.
3,000 simple triggers.
The INSEM01 module monitors Harmony control units for data on an exception report basis, collects and sorts data it acquires, and provides SOE data to human system interfaces for report
presentation after some predefined trigger condition occurs. Digital state transitions are collected
at the HCU level by IMSED01 and INSET01 modules, then forwarded to the INSEM01 module.
The INSEM01 module records the information and sorts it according to time in an internal database. When a trigger condition occurs, the human system interface is notified and data transfer occurs.
INTKM01
The INTKM01 Time Keeper Master module provides time information to the INSEM01 module
and to the rest of the distributed SOE system through the time synchronization link. The
INTKM01 module connects to an external receiver using IRIG-B time code link. The module transmits absolute time to the rest of the system using the RS-485 time synchronization link.
The INTKM01 module cable connects to an NTST01 termination unit. In this case,
the termination unit provides the connection point for the external receiver signals and also the time synchronization link.
IMSET01
The IMSET01 Sequence of Events Timing module processes up to 16 digital field inputs, and
receives and decodes the time synchronization link information sent by the INTKM01 module for a Harmony controller. The controller utilizes function code 241 (DSOE data interface) to interface SOE data from the IMSET01 module to the INSEM01 module, and function code 242 (SOE digital event interface) to configure and access the IMSET01 module input channels. Each channel is optically isolated, and can be individually programmed for 24 VDC, 48 VDC, 125 VDC, and 120 VAC input.
The module communicates with its Harmony controller over I/O expander bus. Only one
IMSET01 module can operate on an I/O expander bus segment. The module cable connects to
NTST01 and NTDI01 termination units. The NTST01 unit provides for time synchronization link termination. The NTDI01 unit provides for field wiring termination.
IMSED01
The IMSED01 Sequence of Events Digital Input module is similar to the IMSET01 module except that it only processes up to 16 digital field inputs for the Harmony controller. It does not process time synchronization link information. The controller utilizes function code 242 (SOE digital event interface) to configure and access the IMSED01 module input channels. Up to 63 IMSED01 modules can operate on an I/O expander bus segment along with one IMSET01 module. The NTDI01 termination unit provides for field wiring termination.
Composer™ System
Composer provides a comprehensive set of engineering and maintenance tools for the Symphony Enterprise Management and Control System. Composer is designed to operate on the Microsoft® Windows NT® 4.0 (service pack four or later) platform. The working environment provided by Composer simplifies the configuration and maintenance of Symphony systems. The base product contains all the functionality necessary to create and maintain control system configurations. Applications provide users with the ability to graphically develop
control system strategies, develop and maintain global configuration databases, and manage system libraries of reusable software components.
Composer is designed to be compatible with INFI 90 OPEN system configurations and is capable of importing existing WinTools configurations. Once imported, these configurations can be fully integrated into Composer and utilize all its features.
Composer Applications
The base Composer product contains all the functionality necessary to develop and maintain Symphony
control system configurations. There are two primary applications: explorer and automation architect.
Explorer
The primary application of Composer is the explorer. Explorer presents the Symphony system architecture and provides an intuitive means for organizing, navigating and locating system configuration information. Explorer presents a user with two main windows: system architecture and the object exchange.
System Window
The system architecture window functions similar to Microsoft’s file explorer. The left pane of the window displays a hierarchical representation of the Symphony system. When a system object is selected, the right pane displays a detailed view for the selected object.
The system window supports two views: the document view (Fig. 1)and the data browser view (Fig. 2). When the system window is in the document view, it will show the configuration documents that are associated with the system object that the user has selected. Configuration documents support long file names and can include control logic documents, human system interface displays, or documents created by other applications such as CAD packages or spreadsheets.
Figure 2. System Architecture - Data Browser View
The ability to associate any documents with the system architecture is an important feature. This allows any information, such as P&IDs, cabinet arrangement drawings or field wiring drawings, to be managed by the configuration server and therefore accessed by Composer client applications. All that is required to edit any of these documents is to double click on the document. Composer’s explorer will automatically launch the appropriate application for the document selected.
When the system window is in the data browser view, the right pane of the system architecture window will display tag information associated with the system object the user has selected. All tag information presented, is retrieved from the configuration server database that is managed by the Composer server.
When working in the data browser view, users can view, define, and modify tag data for the whole system. This central repository of data is managed by Composer’s configuration server for all tag data in the entire system. The data for each tag is added to the configuration server database as each tag is defined. This eliminates the need for users to enter the same information more than once. Some notable features of the data browser view are the ability to:
_ Edit tag objects in a datasheet or property page view.
_ Filter the database. Filtering makes configuration easier and faster by eliminating unnecessary
information from view.
_ Import and export tag data.
_ Navigate directly from a tag to its related configuration document.
_ Perform automatic search and replace operations based on complex queries.
Object Exchange
The object exchange (object library) window presents the user with a view of the reusable components
that can be used to create control system configurations (Fig. 3). Objects are organized in folders. Standard system components such as function codes and
standard shapes and symbols are organized under the system folder. Users are able to use these components but since they are part of the standard system objects supported by Composer, users are not permitted to delete these items from the object exchange.
To support reuse, the object exchange provides library management features such as cutting, copying, and pasting of objects between different projects. This makes it easy for systems engineers to share objects among projects.
Automation Architect
The automation architect provides for the visual creation, editing, monitoring, and tuning of control logic. High-level control strategies can be created by dragging and dropping function codes from the object exchange to the control logic document.
Figure 3. Object Exchange
Control strategies are represented graphically by the automation architect. Rather than textually programming strategies, the automation architect represents predefined control strategies as function blocks. By connecting function blocks together (Fig. 4), users are able to specify the signal flow of a control strategy and visually define the control strategy.
Figure 4. Automation Architect
The automation architect stores configuration information in control logic documents. Control logic documents support grouping of multiple logic sheets in a single document. This permits users to group sheets of logic together using process partitions. For example, a single control logic document could be used to define the control strategy for a mix tank. Each control loop or motor control sheet associated with the mix tank could be assigned to the control logic document. Partitioning control logic in this manner is more process object oriented and intuitive to process engineering personnel (Fig. 5).
The monitoring and tuning capabilities (Fig. 6) of the automation architect provide the ability to troubleshoot and maintain an operational system using the same information used to create the system. By using the monitoring functionality, it is possible to obtain dynamic operating values from the Symphony system. These values are automatically presented on the same control logic documents that were used to configure the module. Composer’s tuning functionality allows the change of logic parameters as permitted by the controller. The control logic document in the Composer application and in the module are dynamically updated when tuning changes are made so that the documentation for the system accurately reflects the current configuration of the controller.
Figure 6. Monitoring and Tuning Capabilities Control Logic Templates
Two of the primary goals of Composer are to reduce the cost of implementing control strategies and improve the quality of Control strategy software. To realize these goals, Composer supports a new type of document called a Control Logic Template.Control Logic Templates (Fig 7.) define reusable standard control
strategies that are typically used to develop a process automation system, and can be thought of as blueprints that define the structure of a control strategy. They are maintained by the object exchange and can be used to quickly define control logic documents.
The Control Logic Template Linking functionality allows users to define logic that is controlled by the template or can be modified within a logic document. Any subsequent changes made to a template can then be propagated to logic documents. When a template updates its documents it will preserve logic additions that the user has made to the document. This template management functionality provides efficient maintenance and utilization of reusable standard control logic.
EMERGENCY TRIP SYSTEM (ETS)
Sagardighi Thermal Power Project (2 × 300MW) uses PLC based Emergency Trip System (ETS) to ensure fast turbine tripping in case of some specified abnormal conditions occur in the main plant. The PLC is a (90-70) series of GE Fanuc .It takes different data continuously from many field instruments acting as trip device, processed signals from main control system (in SgTPP main control system is DCS manufactured by M/s. ABB Ltd.), Digital Electro-hydraulic system which govern opening/closing of turbine main stop valves & control valves, Turbine Supervisory Instrumentation that monitors healthiness of turbine and Instrumentation & Control power cabinet which supplies power to the control cabinet of DCS and ETS as well. Each unit of the plant contains separate ETS panel to process. The decision taken by ETS PLC is through Triple Modular Redundant (TMR) which sends trip signals to tripping device attached to turbine main stop valve and turbine control valve by voting 2 out of 3 processed signals. TMR avoids any chance of tripping due to wrong signal coming out from one of any 3 inputs.
INPUT/OUTPUT OF ETS: There are two terminal blocks at the back panel of ETS,
D1 and D2. All the inputs from various systems and field terminate at D1 and all the processed output signal goes out from ETS via D2. The output signals serves two purposes, i) goes to tripping devices and ii) others go to DCS for viewing different alarms like PLC failure, power failure etc. For all the tripping signals there is individual display at Power Generation Portal (Front end graphic software used for main plant operation). All the inputs to the ETS are made into three separate inputs by using diode and put into three separate Input modules. The Input modules are 06 nos. and driven by 24V DC. All the Input modules are IC660TBD024M and are sink type in nature. Each Input module has 32 channels so as to handle 32 inputs at the same time. There are 08 nos. of output modules used in each ETS. They are also of 24V DC type. Four of them are of sink type (IC660TBD024M) and others are source (IC660EBD025V) type. Two sink type output modules & two source type output modules combine to make 32 nos. of output data and rests make another 32 nos. of output data. Each unit is called a `H` type formation of output and combined digital output energies corresponding output relays.
CPU, BUS & BUS CONTROLLERS: ETS system has three individual PLC units.
Each PLC is having separate power supply units, one CPU (CPM790) and Three Bus Controllers (BEM791). As each input to the ETS system is made into three and is fed to three PLCs so there are three buses for whole communication. Each CPU takes all the three inputs from all the three buses. To achieve this kind of arrangement Each CPU requires three Bus Controllers. So, each bus passes through three bus controllers of different PLC, two input modules and three/two output modules. There is one 150Ω resistance used at each termination of three individual busses. Diagram below shows how architecture has been done between bus controllers of different PLC, 6nos. of DI & 8nos. of DO.
5 6 4
Bus-1 Bus-1
PLC A PLC B PLC C DI DI
DO DO DO
3 1 2
Bus-2 Bus-2
PLC A PLC B PLC C DI DI DO DO DO
7 8
150Ω 150Ω resistor
Bus-3 Bus-3
PLC A PLC B PLC C
DI DI DO DO
B us C ont rol ler 1 B us C ont rol ler 1 B us C ont rol ler 1 B us C ont rol ler 2 B us C ont rol ler 2 B us C ont rol ler 2 B us C ont rol ler 3 B us C ont rol ler 3 Bus Cont rol ler 3
HOW TMR & DUAL OUTPUT WORKS:
As discussed earlier every single input is made triple using a diode and fed to single PLC via bus and bus controllers and each bus passes through two input modules handling 1-32 nos. and 33-64 nos. of data. Each PLC CPU is configured with different addresses but same programmable logic is loaded into every PLC. The addresses given in the CPUs are also reflected to bus controllers also. So through bus controller arrangement every PLC knows what happens to the other PLCs. If one digital input changes its state the Triple Modular Redundant will vote out any possibility of getting state change to its corresponding output channel.
The output modules are of `H` type combination. Each `H` consists of two source type output modules and two sink type output modules. First `H` can handle 1-32 nos. of output and second `H` can handle 33-64 nos. of output. PLCs can generate dual output source and dual sink corresponding to each output relay which energizes actuator associated to the electro-hydraulic governor to make the turbine valves quick close.
REASONS FOR TURBINE TRIP BY ETS
:
The emergency trip system (ETS) of steam turbine is able to start automatically the closing loop while trouble occurring with turbine, tripping occurring with generator and tripping occurring with main fuel of boiler, thus to fast close the steam inlet valves (main stop valves and control valves). The ETS is composed of mechanical-hydraulic and electrical-hydraulic parts. That means the trouble can be detected in mechanical mode and electrical mode. But the closing of steam inlet valves are controlled by the hydraulic control and protection system finally.Mechanical-hydraulic emergency tripping:
The emergency governor is a mechanical detector for overspeed trouble. In case the speed of turbine reaches n≥3300rpm, a stop ring will be flies out by the action of centrifugal force to actuate the emergency tripping device. The emergency tripping device changes the moving direction of the trip valve in tripping isolation valve group to drain the HP control oil. After the HP control oil is drained, the overspeed limiting control oil is also drained though the check valve. As a result the control oil pressure in dump valves for servomotors of steam inlet valves disappears and the dump valves are open. Then the pressure oil in both upper and lower chambers of servomotors is connected to the drain port through the opened dump valves to fast close the steam inlet valves. After full closing the main stop valves the limiting switch signal will be sent out to the check valves through electric control loop.Electric-hydraulic emergency tripping: This is an electric mode to detect the
trouble occurring with turbine, the tripping occurring with generator and the tripping occurring with main fuel of boiler and also to send out the electric tripping signal to the mechanical tripping electric magnet 3YV at the same time.
As soon as the electric tripping signal is sent to the mechanical tripping electric magnet 3YV, the latter will be energized to actuate the emergency tripping device through linkage mechanism. The following process will be performed as same as described in Mechanical-hydraulic emergency tripping system.
Electric tripping signals:
The electric tripping signals of ETS for the steam turbine are as follows:1.
Overspeed Trip:
In case the speed of turbine rises to 3300 rpm and above, the overspeed relays in overspeed monitoring channels of ETS are actuated and the tripping signal is sent out after processing by the ETS in 2 out of 3 logic through the output contact.2.
Low Lube Oil Pressure Trip:
In case the oil pressure in lube line P≤0.0392MPa (which is the setting value for pressure switch), three pressure switches PSA4~PSA6 in lube oil low pressure tripping device will be reset and three normally-closed(NC) contacts will send out the tripping signal after processing by the ETS in 2 out of 3 logic.3.
Low Control Oil Pressure Trip:
In case the oil pressure in fire-resistant oil line P≤7.8MPa, three pressure switches in resistant oil manifold supplied by the DEH manufacturer will be reset and three normal-open(NO) contacts will send out the tripping signal after processing by the ETS in 2 out of 3 logic. 4.Condenser Low Vacuum Trip:
In case the pressure in condenserP≥19.7kPa, three vacuum switches in condenser low vacuum tripping device are actuated and three normal-open(NO) contacts will send out the tripping signal after processing by the ETS in 2 out of 3 logic.
5.
Axial Position High Trip:
In case the shaft displacement related to thrust bearing increases (≥ 1.2mm or ≤ -1.65mm), the contact of the axial displacement emergency relay in dual-channel axial displacement monitor will send out the tripping signal after processing by the ETS.6.
Main Fuel Trip:
The steam turbine will suffer tripping by trouble with main fuel of boiler, and the signal will be supplied by the Furnace Safeguard Supervisory system (FSSS).7.
Generator Failure Trip:
The steam turbine will suffer tripping by trouble with generator, and the signal will be supplied by the generator protection system.8.
Shaft Vibration High Trip:
The TSI (Turbine Supervisory Instrumentation) will send out the shaft vibration in X axis at any of #1~#6 bearings is too high (≥ 0.25mm) or the shaft vibration in Y axis at any of #1~#6 bearings is too high (≥ 0.25mm). Above mentioned combination logic has been conducted in the TSI and a contact signal is sent out by the TSI to the ETS for turbine tripping.9.
EHG Failure Trip:
This is the turbine tripping signal supplied by the DEH (Digital Electro-hydraulic System) and contains the turbine overspeed monitored by DEH, DEH speed signal trouble and etc. It is used to output the shut-down contact signal for turbine tripping.10.
Differential Expansion High Trip:
The TSI (Turbine Supervisory Instrumentation) will send out the HP/IP differential expansion trip signal if it is ≥ 7μm or ≤ -4μm or LP differential expansion ≥15μm. Above mentioned combination logic has been conducted in the TSI and a contact signal is sent out by the TSI to the ETS for turbine tripping.11.
Remote Manual Trip:
There is one manual push button in Central Control Room. If any case somebody presses it sends one tripping signal to ETS and ETS makes the turbine trip.12.
Generator Cooling Water Loss Trip:
In case the cooling water flow for generator ≤ 35 T/H, three Differential Pressure switches (DP set at ≤ 29.4kPa) meant for generator cooling water flow low trip are actuated and three normal-close contacts will send out the tripping signal after processing by the ETS in 2 out of 3 logic.13.
Exhaust Temperature High Trip:
In case the HP exhaust temperature ≥420˚C main plant control system will send trip signal by itself using the help of three temperature detector to ETS where it will be activated by 2 out of 3 logic.FURNACE SAFEGUARD SUPERVISORY SYSTEM
The Triguard SC300E is a high integrity safety system designed especially for use in processes with high demands on the availability, reliability and fault-tolerance of the control system; emergency shutdown systems, interlock systems, burner control, turbine control, fire and gas detection and protection systems.
The Triguard SC300E safety controller is designed with Triple Modular Redundant (TMR) hardware system. This hardware architecture is combined with Software Implemented Fault Tolerance (SIFT) to achieve extremely high operational availability and function on demand performance.
The three key aspects of Triguard SC300E, that permit system availabilities in excess of 99.999% (about 1 hour’s downtime in 11 years) to be realized, are: • Triple Modular Redundant architecture - TMR
• Software Implemented Fault Tolerance - SIFT (with HIFT output voter) • On line hot repair facility
Architecture
Theory of operation
At the input modules, field signals are filtered and then split, via isolating circuitry, into three identical signal processing paths. Each path is controlled by a
microcontroller that coordinates signal path processing, testing and signal status reporting to its respective processor, via one of the I/O communications buses. Once each processor has a copy of the input state it votes on that data against the input states presented by the other two processors. The voted result is then used in the application logic. Once the application has been processed, the results of the application logic are again compared with the other two processors. These voted results are then written to the output cards by the processors. The output modules share the same microcontroller architecture as the input cards, a single result is presented to the field by passing the three processor signals through a hardware 2oo3 voting circuit.
Processor modules
The SC300E processors have been designed around Intel microprocessors. Key features of the processor modules are:
• Intel 32 bit microprocessor
• Support for up to 1Mb of battery backed static RAM for application logic storage. Error detection and
correction circuitry is used to monitor all data accessed from the RAM. Onboard lithium batteries
provide a backup supply to the RAM for up to 6 months in the event of system power failure.
• Up to 2 Mb of EPROM programmed with Triguard SC300E’s real time operating system. EPROM can
• Buffered I/O communications bus via a special 96 way DIN41612 connector permitting the live
insertion of a processor module.
• Real time calendar clock circuitry used for data logging to a resolution of 10 ms. The size of a
processor’s sequence of events log is typically 5000 events.
• Two 8 Mbps, read-only, serial communications links used by a processor to read I/O and diagnostic
information from its two processor neighbours.
• Front panel mounted RS232 serial communications port used for engineering diagnostic purposes.
• Watchdog circuitry and front panel mounted control switches and indicators.
Common interface
All I/O modules in the Triguard SC300E share a common system interface as depicted byFigure 1-4.
LOCAL IGNITION CONTROL SYSTEM
The local ignition control system is designed by Eastern Boiler Control Co., Ltd specifically for INDIAN SAGARDIGHI 2×300MW power plant.
The boiler designed by Dong Fang Boiler Group Co., Ltd specifically for INDIAN SAGARDIGHI 2×300MW power plant includes:
a. Four (4) Elevations of tangential fired oil compartments, which one include: one (1) light oil gun and one (1) heavy oil gun.
b. Four (4) Elevations of tangential fired coal compartments.
Each oil burner is equipped with a Class 3 Special igniter, as defined by NFPA. This is a high energy spark type igniter for direct ignition of the atomized oil burner during oil burner light off.
First, the light oil gun will be lit off by igniter with the commands from operator, then the heavy oil gun will be lit off by the light oil gun with the commands from operator.
The igniter is also brought into service when the oil atomizer is shutdown and purged (scavenged) to remove oil from the atomizer, the oil being lit by the igniter as it is ejected from the atomizer by the purge (scavenged) steam. These typical functions will be completed in FSSS (or BMS) logic.
In remote operation mode, the local ignition control system, accepted the command from FSSS (or BMS) which is a part of DCS, send drive signals to local devices of oil burner.
In local operation mode, the local ignition control system, accepted the commands from operator, send drive signals to local devices of oil burner.
2 System function
The local ignition control system consists of sixteen (16) local control cabinets and sixteen sets of local devices for oil burner.
2.1 Local devices of a oil burner For each oil burner, includes:
◆ Heavy oil gun insert/retract actuator drove by instrument air
With a single solenoid valve and insert/retracted limit switches (DPDT) ◆ Light oil gun insert/retract actuator drove by instrument air
With a single solenoid valve and insert/retracted limit switches (DPDT) ◆ Igniter insert/retract actuator drove by instrument air
With a dual solenoid valve and insert/retracted limit switches (DPDT) ◆ High Energy Igniter (HEI)
◆ Light oil shut-off valve
With a dual solid valve & pneumatic actuator & opened/closed limit switches (DPDT) ◆ Light oil purge valve
(DPDT)
◆ Light oil atomization valve
With a dual solid valve & pneumatic actuator & opened/closed limit switches (DPDT) ◆ Heavy oil shut-off valve
With a dual solid valve & pneumatic actuator & opened/closed limit switches (DPDT) ◆ Heavy oil purge valve
With a single solenoid valve & pneumatic actuator & opened/closed limit switches (DPDT)
◆ Heavy oil atomization valve
With a dual solid valve & pneumatic actuator & opened/closed limit switches (DPDT)
2.2 The signals from the ignition control system to DCS:
◆ Light oil valve opened ◆ Light oil valve closed
◆ Light oil atomization valve opened ◆ Light oil atomization valve closed ◆ Light oil purge valve opened ◆ Light oil purge valve closed ◆ Heavy oil valve opened ◆ Heavy oil valve closed
◆ Heavy oil atomization valve opened ◆ Heavy oil atomization valve closed ◆ Heavy oil purge valve opened ◆ Heavy oil purge valve closed ◆ Igniter insert
◆ Igniter retracted ◆ Light Oil gun insert ◆ Light Oil gun retracted ◆ Heavy Oil gun insert ◆ Heavy Oil gun retracted ◆ Local operation requirement ◆ HEI sparking
2.3 The signals from DCS to the ignition control system:
◆ Local operation permission
◆ Open command to Light oil valve ◆ Close command to Light oil valve
◆ Open command to Light oil atomization valve ◆ Close command to Light oil atomization valve ◆ Open command Light oil purge valve
◆ Close command to Light oil purge valve ◆ Open command Heavy oil valve opened ◆ Close command to Heavy oil valve closed
◆ Open command Heavy oil atomization valve opened ◆ Close command to Heavy oil atomization valve closed
◆ Open command Heavy oil purge valve opened ◆ Close command to Heavy oil purge valve closed ◆ Insert/ retract command to Igniter
◆ Insert/ retract command to Light Oil gun ◆ Insert/ retract command to Heavy Oil gun ◆ Energize HEI transformer
◆ Flame on
3.2 Igniter and oil gun insert/retract actuator
The heavy oil gun insert/retract actuator is controlled by a solenoid 5/2 valve. Once operated the “insert” valve will remain in its operated position after the pulse has been removed and until the retract solenoid is operated.
The light oil gun insert/retract actuator is controlled by a solenoid 5/2 valve. Once operated the “insert” valve will remain in its operated position after the pulse has been removed and until the retract solenoid is operated.
The HEI igniter insert/retract mechanism is controlled by a single acting solenoid 3/2 valve which is energized to insert the igniter pod.
In the oil corner start or stop sequence, neither heavy oil gun or light oil gun need to be insertd or retracted. When advancing command which will be sent to the solenoid 5/2 valve, the oil gun is insertd via the insert/retract actuator drove solenoid 5/2 valve, the oil gun is retracted via the insert/retract mechanism drove by instrument air.
Before energizing the HEI transformer, the igniter pod must to be insertd. When advancing command which will be sent to a solenoid 3/2 valve, the igniter is insertd via the insert/retract actuator drove by instrument air. When the advancing command is missing, the igniter will be retracted to the original position.
3.3 High energy igniter (HEI)
The HEI is used to ignite oil gun in power plant station. It includes:
● HEI transformer ● Igniter pod
● Special cable assembly between HEI transformer and igniter pod (about six 6 meter long0
The igniter pod moves with the igniter insert/retract actuator. Its length depends on the light oil gun requirements. Before sparking in the start or stop sequence, the igniter pod need inserted in the atomizing area of light oil gun. After the sparking, the igniter pod must be retracted from the flame area as a protection against heat overload.
HEI transformer accepts the energizing signal. A high tension capacitor in the HEI transformer is charged up with energy and then released via a special cable assembly to the igniter pod. The resultant arc discharge converts the energy into heat which ignites the fuel.
3.4 Oil corner shut-off valve. Atomization valve & Purge valve
Both light oil shut-off valve and heavy oil shut-off valve drove by instrument air, which we supplied, is controlled by solenoid 5/2 valve. When opening command is sent to the solenoid valve, the valve is opened via the pneumatic actuator. When closing command is sent to the solenoid valve, the valve is closed via the pneumatic actuator.
Both light oil atomization valve and heavy oil atomization valve drove by instrument air, which we supplied, is controlled by solenoid 5/2 valve. When opening command is sent to the solenoid valve, the valve is opened via the pneumatic actuator. When closing command is sent to the solenoid valve, the valve is closed via the pneumatic actuator.
Both the light oil purge valve and heavy oil purge valve is controlled by single solenoid coil (solenoid 3/2 valve). When opening command is sent to the solenoid valve, the purge valve is opened via the pneumatic actuator. When missing the opening command, it is closed automatically.
Main performance parameter of heavy oil shut-off valve or light oil shut-off valve as below:
● Control voltage:240VAC 50Hz
● Instrument air pressure:0.4~0.8 MPa ● Medium temperature: ＜250℃
● Atomization/purge steam temperature: 220~250℃ ● Medium pressure: ＜3.2MPa
Main performance parameter of heavy oil atomization valve or light oil purge valve as below:
● Control voltage:240VAC 50Hz
● Instrument air pressure:0.4~0.8 MPa ● Medium temperature: ＜250℃
● Atomization/purge steam temperature: 220~250℃ ● Medium pressure: 0.78~1.27 MPa
Main performance parameter of heavy oil purge valve or light oil purge valve as below:
● Control voltage:240VAC 50Hz
● Instrument air pressure:0.4~0.8 MPa ● Medium temperature: ＜250℃
● Atomization/purge steam temperature: 220~250℃ ● Medium pressure: 0.78~1.27 MPa
UPS GENERAL DESCRIPTION
UPS（Uninterruptible Power System） supplies reliable and interference-resistant AC power for computer control, SCADA, DCS, important protection, measuring meter and solenoid valve etc.
UPS system composition in power house
1 Stabilizer panel
2 Isolation transformer panel 3 #1UPS Main panel
4 #2UPS Main panel 5 Distribution feeder panel
UPS equipment：
1. 100% Static inverter 2. 100% Static switch 3. Manual bypass switch
4. 100% UPS System battery bank
5. 100% high-frequency switch module charger 6. Step-down transformer with associated Switchgear 7. voltage stabilizer and standby power switch
8. battery panel
9. UPS AC feeder panel
UPS System description
1. The capacity of the power house UPS system is 2X80KVA for each set. The input voltage of UPS is AC 415V ±10%, 50HZ, the output of the UPS is AC 240V, 50HZ. The UPS is normally supplied by a 415V emergency PMCC circuit. When the 415V emergency PMCC fails, the UPS will be supplied by its DC 1.2V, 100Ah battery bank. Total no of batteries are 272 per UPS set. When both static inverters of UPS fail, the supply of UPS will be automatically transferred to auto bypass.
2. Two inverters are in operation on normal condition, each carries 50% UPS load. On failure of any inverter, its load gets automatically transferred to the other inverter through static transfer switch. If one inverter is out of service for any reason, then the second inverter will be working with 100% UPS load. On failure of this inverter，the auto bypass A.C. source will supply 100% UPS load automatically through static transfer switch.
UPS Technical Data
AROS 80KVA Major Technical Data：
Operating Condition 80KVA
Operating Temperature -5/50℃ Storage Temperature -20/70℃ Relative Humidity 5-95%
Total Efficiency >96% （ECO-MODE operation >98） Average MTBF >350,000 hours
Noise 65dBA
Dimension（W×D×H）MM 800*740*1400
Weight KG 520
Rectifier Input Data
Input Voltage 415V/AC±20% Input Frequency 50Hz/60Hz±10% Input Power Factor >0.95
Inverter Electrical Data
Output Voltage 240V
Output Voltage Fluctuation Range ±1% Output Voltage’s Spontaneous
Response Feature
±3%（load 0-100％ 10ms resume） Output Voltage Distortion
--100% Non Linear Load
<1% <2% Output Frequency 50 Frequency Adjustable Range ±0.001 Conversion Efficiency 96%
Output Wave Form Positive Sine Wave
Overload 110％ load 5 hours；125％load 15mins.； 150％load 60secs.
Crest Factor 5:1
Inverter’s Short Circuit Resistance 5.0
Static Bypass Data
Overload Capacity 2000%，100ms
Efficiency 99%
Real Time Transfer -from mains to inverter -from inverter to mains
0 sec. 0 sec.
ALARM MESSAGES
A list is given below of the alarm messages displayed on the first line of the display panel, the alarm number in brackets shows the priority level.
5.1 DISTURBANCES ON BYPASS LINE
or harmonic distortions type, while voltage and frequency are correct. CAUTION. In this case the inverter is not synchronised with the bypass line, hence if the bypass is forced with the switch SWMB or the remote controls or panel there could be wrong switching between voltages in counterphase.
5.2 BY-PASS MANUAL, SWMB - ON or cable defect
Manual BY-PASS SWMB Switch inserted and therefore return to normal operation is prevented. Load is fed by the input of the BY-PASS line and therefore isn't secured by the continuity unit. “ cable defect" only for UPS in parallel version, logic has revealed an error in signals exchanged between the UPSs connected in parallel, and has therefore switched the entire system to BY-PASS.
5.3 BYPASS VOLT. FAIL or SWBY, FSCR OFF
Alarm is present if:
- bypass line input voltage is wrong,
- bypass line turn-on switch SWBY is open,
- SCR fuse of the bypass line is open or burnt out following output short circuit.
5.4 MAIN LINE VOLTAGE FAIL or SWIN OFF
Input voltage is wrong and battery is discharging. The alarm appears if:
- input voltage or frequency are without range , - SWIN power switch is open,
- the rectifier does not recognize the voltage due to internal anomaly;
5.5 PREALARM, LOW VOLTAGE ON BATTERY
The alarm is present if:
- the battery voltage is lower than calculated to supply approximately 5 minutes duration or the residual ;
- autonomy time is lower than the time set for the pre alarm.
5.6 BATTERY DISCHARGED OR SWB OPEN
The logic of the UPS has carried out A BATTERY TEST, during presence of mains feeding, the voltage of the battery was lower than the estimated value (see menu 3,2 BATTERY TEST).
5.7 LOW VOLT. SUPPLY or OVERLOAD [W]
This alarm is present if one of the following conditions is verified:
- voltage of feeding in input is insufficient to feed load, (see general characteristics); - load of output, in active power W, is higher than the nominal value .
5.8 OUTPUT OVERLOAD
Indicates that the power absorbed by the load at the output is greater than allowed rated power, hence the indicated value expressed in %VA exceeds 100%. The same alarm is activated also when the peak absorbed current of the load exceeds the maximum admitted. When this alarm is on it is necessary to reduce the load, otherwise the system automatically goes on bypass within a time period inversely
proportional to the amount of the overload.
5.9 BY-PASS FOR VA OUTPUT < AUTO_OFF VALUE
This alarm is present when power in %VA, absorbed by the load is lower than the set value of" AUTO-OFF".The value of %VA for AUTO-OFF is set to 0 in the factory (therefore this alarm condition can't happen).
UPS , Stabiliser panel, AC Distribution panel
Multi Flame Detector Control Unit & Flame scanner
UVISOR MFD is an advanced flame detector control unit designed for utility and industrial multi-burner furnaces to detect and discriminate the operating burner flame. UVISOR MFD behaves as a true “Two-Systems-in-One”, processing simultaneously the flame signals carried by two scanner heads regardless the sensor spectral range (Ultraviolet or Infrared) or the electrical signal type (amplitude/frequency modulated signal or pulse rate signal).It can achieve a stable flame-on status and a reliable discrimination at various load rates thanks to a proven algorithm, which analyses the flame’s flicker spectrum and tunes consequently the basic parameters of the amplifier. The UVISOR MFD provides the “Individual channel maintenance power-off” utility thus to offer a cost effective application options where simultaneous and independent control for burner and pilot flame or two burners flame scanners are required.
UVISOR MFD process simultaneously flame signals from two scanners on two separate channels. Each channel can be configured to use two different techniques to detect the flame. Based on the detector types, these techniques are:
• Flicker frequency receiver • Pulse counter receiver
