Substation Automation

Transcription

1 Substation Automation Page SICAM PAS Substation Automation System /3 SIPROTEC 4 6MD61 I/O-Box /11 SIPROTEC 4 6MD63 Bay Control Unit /19 SIPROTEC 4 6MD66 High-Voltage Bay Control Unit /21

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3 Substation Automation / SICAM PAS SICAM PAS Substation Automation System Function overview LSP2828.tif System architecture Modular and scalable hardware and software Open system thanks to standards User-friendly due to Windows operating system Real-time data system Flexible, graphical configuration of automation Embedded industry platform LSP2873.tif Fig. /1 SICAM PAS Substation automation system Description SICAM PAS (Power Automation System) meets all the demands made of a distributed substation control system both now and in the future. Amongst many other standardized communication protocols SICAM PAS supports the new standard IEC in the substation for communicating with the bay devices. SICAM PAS is an open system and besides providing standardized data transfer processes, it features user interfaces for the integration of system-specific tasks and offers multiple automation possibilities. SICAM PAS can thus be integrated with ease in existing systems and can be used for system integration too. With modern diagnostics, it optimally supports commissioning and maintenance. SICAM PAS is clearly structured and reliable, thanks to its open, fully documented and tested system. System features Real time changes in the configuration through database access Unrestricted access to information Monitoring and controlling switchgears via Web interface Substation control features, e.g. bay blocking, telecontrol blocking, security authority, time synchronization, Process visualization with SICAM PAS CC Evaluation of measured and metered values with SICAM Valpro Archiving of fault recordings of protection units with SICAM Recpro Testing and diagnostic functions OPC interface for connection to automation world IEC leading technology Protocols SICAM PAS supports the following communication protocols (optionally available): Control center connection IEC , IEC , DNP V3.00 (serial and over IP ), TG8979, CDT Open data exchange OPC server, OPC client IED and substation connection IEC 61850, IEC , IEC , IEC , DNP V3.00 (serial and over IP ), PROFIBUS FMS, PROFIBUS DP, MODBUS, SINAUT LSA-ILSA /3

4 Substation Automation / SICAM PAS Description/Application System overview, application and functionality of SICAM PAS SICAM PAS is an energy automation solution; its system architecture makes it scalable. SICAM PAS is suitable for operating a substation not only from one single station computer (station unit), but also in combination with other SICAM PAS systems or station control units. Communication in this network is based on a powerful Ethernet LAN. SICAM PAS for safe substation automation based on robust hardware components (non-rotating components) and an embedded operating system. With its features and its modular expandability, SICAM PAS covers a broad range of applications and supports distributed system configurations. A distributed SICAM PAS system operates simultaneously on several computers. SICAM PAS can use existing hardware components and communication standards as well as their connections. SICAM PAS controls and registers the process data for all devices of a substation, within the scope of the data transfer protocols supported. SICAM PAS is a communication gateway. This is why only one single data connection to a higher-level system control center is required. SICAM PAS enables integration of a fully graphical process visualization system directly in the substation. SICAM PAS simplifies installation and parameterization of new devices, thanks to its intuitive user interface. SICAM PAS is notable for its online parameter setting features, particularly when the system has to be expanded. There are no generation times, and there is no need for loading into a target system (unless configuration is performed on a separate engineering PC). SICAM PAS features integrated testing and diagnostic functions. Its user-friendliness, its operator control logic, its orientation to the Windows world and its open structure ideally suit users requirements. Fig. /2 Typical SICAM PAS configuration IEDs are connected to the station unit with IEC and various other protocols (IEC , IEC , PROFIBUS FMS and PROFIBUS DP). The station unit communicate with the higher-level system control center by means of IEC SICAM PAS works on PC-compatible hardware with the Microsoft Windows 2000, Windows XP Professional and Windows XP Embedded and Windows 2003 Server operating systems. The advantages of this platform are low hardware and software costs, ease of operation, scalability, flexibility and constantly available support. With the powerful real-time data distribution system, applications can be allocated among several computers, thus boosting performance, connectivity and availability. A system stores and organizes the database (e.g. configuration data, administrative status data, etc.). The device master function for communication with Intelligent Electronic Devices (IEDs) supports a large number of well-established protocols. The SICAM PAS data normalization function allows such conversions as measurement filtering, threshold calculation and linear characteristics. SICAM PAS CC is used for process visualization. Specifically designed for energy automation, it assists in optimization of operations management. It provides a quick introduction to the subject matter and a clearly arranged display of the system s operating states. SICAM PAS CC is based on SIMATIC WinCC, well-known in industrial automation worldwide. To facilitate incident analysis, the fault recordings from protection units are retrieved and archived automatically during operation. This is supported by the IEC and PROFIBUS FMS (SIPROTEC 4) protocols, or the IEC protection units protocol. SICAM Recpro is used for archiving and navigation in the fault recording archive. Fault recordings are visualized with Comtrade View (included with SICAM Recpro). Alternatively, SIGRA 4 can also be used. /4

5 Substation Automation / SICAM PAS Communication Device interfaces and communication protocols In a substation that you configure and operate with SICAM PAS, you can use various types of protection units, IEDs, bay control units, measured-value recorders and telecontrol units from a wide range of manufacturers. SICAM PAS offers a large number of commercially available communication protocols for recording data from various devices and through differing communication channels. Subsequent expansion is easy. Available protocols These communication protocols and device drivers can be obtained as optional additions to the standard scope of SICAM PAS. IEC IEC is the communication standard for interconnecting the devices at the bay and station control levels on the basis of Ethernet. IEC supports the direct exchange of data between IEDs, thus enabling switching interlocks across bays independently of the station control unit, for example. PROFIBUS FMS Most SIPROTEC 4 bay controllers and protection units can be connected to the SICAM PAS station unit with PROFIBUS FMS. Many of the functional aspects standardized in IEC have been anticipated in this communication platform. IEC Protection units, IEDs, bay control units, measured- value recorders and transformer controllers from many manufacturers support the IEC protocol and can therefore be connected directly to SICAM PAS. IEC (master) The IEC protocol is generally used to connect telecontrol units. The balanced and unbalanced traffic modes are supported. Automatic dialing is also supported for the connection of substations with this protocol. SICAM PAS can establish the dial-up connection to the substation either cyclically or as required (e.g. for command output). By contrast, the substation can also establish a connection cyclically or in event-triggered mode. Analog or ISDN modems can be used. A GSM modem can also be used in the substation. Several modems are supported for communication with substations. Even if the standard modem is already in use, other substations remain accessible. IEC (Master) Furthermore, connection of substations is also supported by the TCP/IP-based IEC protocol. PROFIBUS DP PROFIBUS DP is a highly powerful field bus protocol based on the token passing method. For example, it is used for industrial automation and for automating the supply of electricity and gas. PROFIBUS DP serves to interface multifunctional measuring instruments such as SIMEAS P (I, V, P, Q, p.f. (cos ϕ)) or, for example, to connect ET200 components for gathering messages and for simple commands. Messages, for example, can be derived from the signaling contacts of fuse switch-disconnectors. For simple applications that do not need functions like time synchronization and fault recording transfer, etc., SIPROTEC 4 units can also be interfaced via PROFIBUS DP. IEDs and substations can also be connected with DNP V3.00 (serial and over IP ) and MODBUS. ILSA Protocol Communication via the ILSA protocol is a highlight of SICAM PAS system. Existing LSA central devices can be used without changing of configuration on bay level. A future-proof extension with IEC is possible. System control center connections, distributed process connection and process visualization SICAM PAS operates on the basis of Windows 2000, Windows XP Professional and Windows XP Embedded. This means that the extensive support which 2000/XP offers for modern communication protocols is also available with SICAM PAS. SICAM PAS was conceived for easy and fast integration of conventional protocols. Contact Siemens if you have any questions about integration of user-specific protocols. The standardized telecontrol protocols IEC , IEC and DNP V3.00 (which is also used throughout the world) are supported for the purpose of linking up to higher-level system control centers. Asymmetric encryption enables tap-proof DNP V3.00 communication via TCP/IP connection to higher-level control centers. Distributed process connection in the substation is possible thanks to the SICAM PAS Device Interface Processor (DIP). SICAM PAS can also be set up on computers networked with TCP/IP. Here, one computer performs the task of the socalled full server. Up to six other computers can be used as DIPs. With this architecture, the system can be adapted to the topological situation and its performance also boosted. SICAM PAS allows use of the SICAM PAS CC process visualization system for central process control and monitoring. For industrial applications, it is easy to configure an interface to process visualization systems via OPC (object linking and embedding for process control). SICAM PAS can be configured as an OPC server or as an OPC client. The SICAM PAS process variables available with the OPC server can be read and written with OPC clients working either on the same device or on one networked by TCP/IP. This mechanism enables, for example, communication with another process visualization system. The OPC server is included in the basic system. The OPC client can read and write data from other OPC servers. Typical applications are data exchange with another SICAM PAS station unit, and the connection of SIMATIC programmable controllers. The OPC client is available as an optional package. /5

6 Substation Automation / SICAM PAS Automation SICAM Diamond SICAM Diamond can be used to monitor the system interfaces, to indicate switching device states (and up-to-date measured values), and also for further diagnostic purposes. SICAM Diamond features an event list and enables the issue of switching commands. SICAM Diamond allows access to data with a Web browser (Microsoft Internet Explorer), either on the same computer or from a Web client. I addition to this, a fault recording archive created with SICAM Recpro can be accessed via the intranet/internet using SICAM Diamond for visualization, analysis and downloading of the fault recordings. In other words: SICAM PAS permits data access with Web-based programs. Further station control aspects SICAM PAS features bay blocking and telecontrol blocking functions. The telecontrol blocking function can also be configured for specific channels so as to prevent the transfer of information to one particular control center during operation, while transfer continues with other control centers. The bay blocking and telecontrol blocking functions act in both the signaling and the command directions. Channel-specific switching authority also makes it possible to distinguish between local control (SICAM PAS CC) and remote control for the switching direction, but also between control center connections. Circuit-breakers can be controlled in synchronized/unsynchronized mode. Automation tasks can be configured in SICAM PAS with the CFC (Continuous Function Chart), which conforms to IEC In this editor, tasks are configured graphically by wiring function blocks. SICAM PAS comes with an extensive library of CFC function blocks, developed and system-tested specially for energy automation. Applications range from generation of simple group indications through switching interlocks to complex switching sequences. Namely creation of switching sequences are supported by the SFC Editor (Sequential Function Chart). Fig. /3 Typical redundant configuration: The station unit and the HMI server are based on a redundant structure to boost availability Fig. /4 Process visualization with SICAM PAS CC Redundancy The SICAM PAS station unit can be used in a duplicate configuration to further boost the availability of the station control level (see Fig. /3). This duplication is possible with IEDs or substation devices that support simultaneous communication with two masters (PROFIBUS FMS, IEC ) or clients (IEC 61850). A redundant structure is also possible for process visualisation with SICAM PAS CC and fault-record archiving with SICAM Recpro as shown in Fig. /3. Scope of information The amount of information to be processed by SICAM PAS is essentially determined by the following factors: Computer network concept (multiple-computer network or single-station system) Performance data of the hardware used Performance data of the network Size of the database (RDBMS) Rate of change of values With a distributed PAS system using a full server and up to 6 DIPs a maximum of 350 IEDs and 20,000 data points can be supported. SIP061ben.tif /6

7 Substation Automation / SICAM PAS Process Visualization Process visualization with SICAM PAS CC (see also Fig. /4) In the operation of a substation, SICAM PAS is used for configuration purposes and as a powerful data concentrator. SICAM PAS CC serves as the process visualization system. Several independent SICAM PAS CC servers can be connected to one SICAM PAS. Connection of redundant servers is also supported. SICAM PAS CC supports the connection of several SICAM PAS systems. In the signal lists, the original time stamps are logged in ms resolution as they occur in the devices. With every signal, a series of additional data is also presented to provide information about causes (spontaneous, command), event sources (close range, local, remote), etc. Besides process signals, command signals are also logged. IndustrialX-Controls are used to control and monitor switchgear. These switching device objects support four different forms of presentation (IEC, DIN, SINAUT LSA, SICAM) for circuit-breakers and disconnectors. It is also possible to create bitmaps (defined for a specific project) to represent switching devices, and to link them to the objects. For informative visualization, not only nominal and spontaneous flashing are supported, but also the display of various device and communication states (e.g. upto-date/not up-to-date, bay and telecontrol blocking, etc.). Measured values and switching device states that are not continuously updated due to, e.g., device or communication failure or bay blocking, may be updated directly via the operation panel with SICAM PAS CC. In conjunction with the SICAM PAS station unit, the switching devices can be controlled either directly or with select before operate. When visualizing the process by single-line images, topological coloring can be used. The WinCC Add-on SIMATIC Web navigator can be used for control and monitoring via the Internet. SICAM Valpro can be used to evaluate measured and metered values. It not only allows a graphical and a tabular display of archived values, but also enables subsequent evaluation functions such as minima, maxima and averages (on an hourly or daily basis). SICAM Recpro supports automatic retrieval and archiving of fault recordings from protection units connected with IEC , PROFIBUS FMS and IEC SICAM PAS CC is based on SIMATIC WinCC, which has advanced to become both the industrial standard and the market leader in Europe. It has the following impressive features: Configuration Overview of the operator control philosophy and user interface The SICAM PAS user interface is based on customary Windows technology, which enables you to navigate in the familiar Windows environment both when configuring the system and during ongoing operation. The system distinguishes between configuration and operation of a substation. In SICAM PAS, these two tasks are firmly separated by two independent programs. The SICAM PAS UI Configuration program is used to create and edit a project-specific configuration. To enhance clarity, four views are distinguished: Configuration Mapping System topology Device templates A common feature of all views is that they have an Explorer window that shows the system configuration in a clearly arranged tree structure. As in the Windows Explorer, you can open individual levels of this tree structure to work in them. Meanwhile, you can close other levels to improve clarity. Depending on the level you are currently navigating in and the component you have chosen, in the context menu (right mouse button) SICAM PAS offers you precisely those program functions that are currently appropriate. You work through the necessary steps in the data window on the right. Here, you set parameters, select information and define assignments to a user-specific, processoriented system topology. The user interface is uncomplicated and structured according to the task definition, so as to enable intuitive working and to simplify changes. The user interface assists the editing process by displaying parameter descriptions and messages when incorrect parameters are entered. In the tabular views for information assignment and allocation to the system topology, configuration is made easy by extensive sorting and filtering mechanisms, multiple choices and Drag & Drop. Multilingual capability All operation and monitoring functions on-board. These include not only the graphics system for plant displays and the signaling and archiving system for alarms and measured values, but also a reporting and logging system. Further advantages are integrated user administration, along with the granting and checking of access rights for configuration and runtime operations. Easy and efficient configuration Configuration is assisted by dialogs, wizards and extensive libraries. Consistently scalable, even via the Web In conformity with requirements, the bandwidth ranges from simple single-user station through to distributed multi-user systems with redundant servers and multi-site solutions with Web clients. Open standards for easy integration Using any external tools, archived data can be accessed through a series of open interfaces (such as SQL and ODBC) for further editing. Manufacturer-independent communication with lower-level controllers (or with applicationssuchasmsexcel)issupportedwith OPC (OLE for Process Control). Visual Basic for Applications (VBA), VBScript or ANSI-C create an ideal scope for project-specific solutions. Expandable with options and add-ons WinCC/Dat@Monitor serves to display and evaluate current process states and historical data on office PCs, using standard tools such as the Microsoft Internet Explorer or Microsoft Excel WinCC/Web Navigator is an option with SIMATIC WinCC for controlling and monitoring systems over the Internet, a company Intranet or a LAN WinCC/Connectivity Pack The functions of the two OPC servers HDA and A&E, and of the WinCC OLE-DB provider are ensured by the WinCC/Connectivity Pack. FunkServerPro With the aid of FunkServerPro, messages from the WinCC signaling system can be forwarded automatically to radio call receivers. To ensure data consistency and to avoid redundant data input, SICAM PAS UI provides extensive import and export functions for the exchange of configuration data, e.g. with the bay control level and with process visualization. /7

8 Substation Automation / SICAM PAS Test und Diagnosis The SICAM PAS UI Operation program features a series of editing and diagnostics views for monitoring and controlling a substation. In the Operation Manager, you check and control the states of individual data connections. In the SCADA Value Viewer you can see incoming values in a clearly arranged form and perform operator control actions for test purposes. Security can be boosted by applying user administration for the SICAM PAS UI Configuration, UI Operation and Value Viewer programs. User administration supports user-rights contexts with predefined rights and password protection. Fig. /5 SICAM PAS UI Configuration SIP066b-en.tif Configuration System requirements Hardware comprising: Pentium processor III 800 MHz Main memory 512 Mbytes Hard disk capacity 512 Mbytes Graphics card for recommended resolution of 1024 x 768 Color monitor matching the graphics card DVD-ROM drive Keyboard Mouse Parallel printer interface Network adapter for LAN/WAN connection Interface cards for connection of IEDs SIMATIC CP5613/ for connecting units with PROFIBUS DP interfaces e.g. Rocket Port COM Expander for serial connection of units with IEC interfaces, etc. Operating system for SICAM PAS Microsoft Windows 2000 Microsoft Windows 2003 Server Microsoft Windows XP Professional Microsoft Windows XP Embedded. Operating system for visualization with SICAM PAS CC: Microsoft Windows 2000 Microsoft Windows 2003 Server Microsoft Windows XP Professional Fig. /6 SICAM PAS UI Operation Fig. /7 SICAM PAS Value Viewer SIP067b-en.tif SIP068b-en.tif /8

9 Substation Automation / SICAM PAS Selection and ordering data Description Order No. Hardware SICAM PAS station unit 6MD9101 A SICAM PAS station unit V2 based on industrial mobile processor 19" rack system, fanless operation, without moving components. CPU: Yonah M processor, 1.87 GHz 2GBRAM,2x2GBFlash,4externalUSB,2internalUSB, 2xGbitEthernetRJ45,1serialport,statusLEDs. Redundant power supplies, switchover without reboot. Monitored by SNMP, HW Watchdog, Temperature/voltage monitoring, live contact Windows XP Embedded service pack 2 SICAM PAS software pre-installed, without license / dongle SICAM PAS license / dongle (USB-version) must be ordered separately. Power supply Primary power supply 24 60VDC V AC / DC 2 Secondary power supply without A 24 60VDC B V AC / DC C Storage medium / operating system 2 x 2 GB compact flash cards with Windows XP Embedded A 1 Language of operating system and SICAM PAS software German 1 English 2 Function Full server 1 Device interface processor 2 PCI adapter without PCI adapter A with PCI adapter B Guarantee extension 2 years guarantee 0 3 years guarantee 1 Software 1) SICAM PAS Basic system includes: SICAM PAS UI Operation SICAM PAS UI Configuration (depending on the variant ordered) SCADA Value Viewer OPC-Server SNMP Manager SNTP for time synchronization Real-time data distribution system Sybase SQL database The following variants of the basic system are available: "Full Server" (Runtime & Configuration) basic component as a single-user system or as the central component in a distributed system Full Server (Runtime) basic component Full Server (Configuration) basic component Configuration Upgrade for one Full Server (Runtime) Device Interface Processor (DIP) basic component for use as a subordinate component in a distributed PAS system (Runtime & Configuration) Device Interface Processor (DIP; Runtime) basic component 6MD9000- AA00-6AA0 6MD9000- AA10-6AA0 6MD9000- AA20-6AA0 6MD9000- AA23-6AA0 6MD9010- AA00-6AA0 6MD9010- AA10-6AA0 1) Positions 13 and 16 of the software Order No. indicate the version. Version 6.0 is the current version Basic packages available with dongle for parallel printer-interface 0 with dongle for USB-interface 1 /9

10 Substation Automation / SICAM PAS Selection and ordering data Description Order No. Software (continued) The following option packages are available for SICAM PAS Full Server and DIP: for connecting SIPROTEC 4 IEDs IEC (Client) Driver for PROFIBUS FMS for connecting devices (e.g. SIPROTEC 4, SIMEAS P, S7-300, ET 200, etc.) Driver for PROFIBUS DP for connecting IEDs or substations IEC Master IEC Master IEC Master DNP V3.00 Master (serial and over IP ) MODBUS Master SINAUT LSA-ILSA for connection to higher-level control centers IEC Slave IEC Slave DNP V3.00 Slave (serial and over IP ) CDT TG8979 Further option packages Automation SoftPLC (CFC, SFC) OPC Client 6MD9000-0CE00-6AA0 6MD9000-0CB02-6AA0 6MD9000-0CB01-6AA0 6MD9000-0CB00-6AA0 6MD9000-0CD00-6AA0 6MD9000-0CD04-6AA0 6MD9000-0CB07-6AA0 6MD9000-0CB05-6AA0 6MD9000-0CB03-6AA0 6MD9000-0CC00-6AA0 6MD9000-0CC04-6AA0 6MD9000-0CC07-6AA0 6MD9000-0CC08-6AA0 6MD9000-0CC10-6AA0 6MD9000-0BA50-6AA0 6MD9000-0BA40-6AA0 SICAM PAS CC Human Machine Interface Process visualization Runtime Runtime incl. evaluation applications SICAM Valpro, SICAM Recpro Runtime & Configuration Runtime & Configuration incl. evaluation applications SICAM Valpro, SICAM Recpro 128 tags tags tags tags tags 5 6MD550-0AP00-6AA0 6MD550-0BP00-6AA0 6MD551-0AP00-6AA0 6MD551-0BP00-6AA0 User documentation SICAM PAS Overview SICAM PAS Installation Manual SICAM PAS Configuration and Operation SICAM PAS Automation Blocks SICAM PAS CC Human Machine Interface SICAM Recpro Fault Record Processing Unit SICAM Valpro Measured/Metered Value Processing Unit E50417-X8976-C044 E50417-M8976-C045 E50417-P8976-C046 E50417-H8976-C287 E50417-H8976-C284 E50417-H8976-C286 E50417-H8976-C285 /10

11 Substation Automation / 6MD61 SIPROTEC 4 6MD61 IO-Box LSP2795-afp.tif 6MD612 Fig. /8 SIPROTEC 4 6MD61 IO-Box Description The SIPROTEC 4 IO-Box 6MD61 enables in a simple, easy way to enhance the number of binary inputs and outputs in the switchgear. It can be used directly in the bay together with other SIPROTEC4 units and also together with SICAM PAS to serve as a central process connection. The IO-Box is based on the SIPROTEC 6MD63 and 6MD66 series, so it can be easily integrated in systems with other SIPROTEC 4 units. The IO-Box supports a wide range of demand for additional binary inputs (BI) and binary outputs (BO), starting from 20 BI+10 BO and going up to 80 BI+53 BO. All important standard communication protocols are supported. With IEC GOOSE communication, a direct information interchange with other SIPROTEC units is possible. For simplification and cost reduction, the IO-Box is available only without automation (CFC), without keypad and without display. 6MD611 LSP2797.eps Function overview Application Extension of number of inputs and outputs of bay controller Extension of number of inputs and outputs of protection unit Central process connection for SICAM PAS Features Standard SIPROTEC hardware for easy configuration with DIGSI Full EMC compliance like all other SIPROTEC devices Housing can be used for surface mounting or flush mounting (units are always delivered with two mounting rails for surface mounting. These rails can be dismounted for flush mounting) Three types with different amount of inputs and outputs available Monitoring functions Operational measured values (only 6MD612) Energy metering values (only 6MD612) Time metering of operating hours Self supervision of relay Communication interfaces IEC Ethernet IEC protocol PROFIBUS-FMS PROFIBUS-DP Service interface for DIGSI 4 (modem) Front interface for DIGSI4 Time synchronization via IRIG B / DCF77 /11

12 Substation Automation / 6MD61 Application The following figures show the most important applications of the SIPROTEC IO-Box 6MD61. The configuration shown in Fig. /9 allows direct GOOSE communication between the SIPROTEC 4 units (6MD66, 7SJ63) and the IO-Boxes, independent of the substation controller. Of course, this configuration is also possible without substation controller. The IO-Box is used as additional digital inputs and measurements (measurements only with 6MD612), and serves as an additional command output. The communication between IO-Box and the substation controller is established by using the IEC standard protocol. Fig. /10 shows a configuration in which the IO-Box is used as a central process connection in the cubicle of the substation controller. For example, cubicle signaling lamps or a signaling horn are controlled by the command relays of the IO-Box. Fig. /11 shows the communication for substations with no Ethernet protocol used. In this case, all communication lines go directly to the substation controller. If information from the IO-Box is used for switchgear interlocking, the interlocking logic must be part of the substation controller. Fig. /9 Configuration with IO-Box in IEC substation Fig. /10 IO-Box as central input/output for SICAM PAS substation controller Fig. /11 Direct connection of IO-Boxes and protection relays to substation controller via standard protocol /12

13 Substation Automation / 6MD61 Selection and ordering data Description Order No. Order code 6MD61 IO-Box 6MD61 0AA0 20 binary inputs, 6 command relays, 4 (2) power relays, 1 live status contact (similar to 6MD634) in 1/2 19'' housing 1 33binaryinputs,commandrelays,8(4)powerrelays,1livestatus contact, 2x20mA, 3xV, 4xI, (similar to 6MD636) in 1/1 19'' housing 80 binary inputs, 53 command relays, 1 live status contact in 1/1 19'' housing 3 Current transformer: rated current I n no analog measuring 0 1A 1) 1 5A 1) 5 Rated auxiliary voltage (power supply, indication voltage) 24 to 48 V DC, threshold binary input 19 V 2 60 V DC, threshold binary input 19 V 2) V DC, threshold binary input 88 V 2) to 250 V DC, 115 to 230 V AC, threshold binary input 176 V for input No for 6MD613 (C-I/O 4), otherwise threshold 88 V 2) 5 Unit design Surface mounting case, without HMI, mounting in low voltage compartment, screw-type terminals (direct wiring / ring lugs), also usable as flush mounting case F Region-specific default settings/function and language presettings Region DE, 50 Hz, language German (changeable) Region World, 50/60Hz, language English (GB) (changeable) Region USA (ANSI), 60 Hz, language English (US) (changeable) Region FR, language French (changeable) Region World, 50/60Hz, language Spanish (changeable) A B C D E System interface (on rear of unit, port B) no system port 0 IEC protocol, electrical RS232 1 IEC protocol, electrical RS485 2 IEC protocol, optical 820 nm, ST connector 3 PROFIBUS-FMS Slave, electrical RS485 4 PROFIBUS-FMS Slave, fiber, double ring, ST connector 6 PROFIBUS DP Slave, electrical RS485 9 L 0 A PROFIBUS-DP Slave, 820 nm fiber, double ring, ST connectors 9 L 0 B IEC 61850, 100 BaseT (100 Mbit Ethernet electric, double, RJ45 connector) 9 L 0 R IEC 61850, 100 Mbit Ethernet, fiber optic, double, ST connectors 9 L 0 S Function interface (on rear of unit, port C) no function port 0 DIGSI 4, RS232 1 DIGSI 4, RS485 2 DIGSI 4, 820nm fiber, ST connector 3 1) Only for position 6 = 2 2) Thresholds can be changed (jumper) for each binary input between 19 V and 88 V, for 6MD613 BI No also to 176 V. /13

14 Substation Automation / 6MD61 Connection diagram Fig. /12 Connection diagram /

15 Substation Automation / 6MD61 Connection diagram Fig. /13 Connection diagram /15

16 Substation Automation / 6MD61 Connection diagram Fig. / Connection diagram, part 1; continued on the following page /16

17 Substation Automation / 6MD61 Connection diagram Fig. /15 Connection diagram part 2 /17

18 Substation Automation / 6MD61 /18

19 Substation Automation / 6MD63 SIPROTEC 4 6MD63 Bay Control Unit Description The 6MD63 bay control unit is a flexible, easy-to-use control unit. It is optimally tailored for medium-voltage applications but can also be used in high-voltage substations. The 6MD63 bay control unit has the same design (look and feel) as the other protection and combined units of the SIPROTEC 4 relay series. Configuration is also performed in a standardized way with the easy-to-use DIGSI 4 configuration tool. For operation, a large graphic display with a keyboard is available. The important operating actions are performed in a simple and intuitive way, e.g. alarm list display or switchgear control. The operator panel can be mounted separately from the relay, if required. Thus, flexibility with regard to the mounting position of the unit is ensured. Integrated key-operated switches control the switching authority and authorization for switching without interlocking. LSP23-afp.tif Fig. /16 SIPROTEC 4 6MD63 bay control unit Function overview Application Optimized for connection to three-position disconnectors Switchgear interlocking interface Suitable for redundant master station Automation can be configured easily by graphic means with CFC Control functions Number of switching devices only limited by number of available inputs and outputs Position of switching elements is shown on the graphic display Local/remote switching via key switch Command derivation from an indication 4 freely assignable function keys to speed up frequently recurring operator actions Switchgear interlocking isolator/c.-b. Key-operated switching authority Feeder control diagram Measured-value acquisition Signal and command indications P, Q,cosϕ (power factor) and meter-reading calculation Event logging Switching statistics Monitoring functions Operational measured values Energy metering values Time metering of operating hours Slave pointer Self-supervision of relay Communication interfaces System interface IEC Ethernet IEC protocol PROFIBUS-FMS DNP3.0 PROFIBUS-DP MODBUS Service interface for DIGSI 4 (modem)/temperature detection (thermo-box) Front interface for DIGSI 4 Timesynchronizationvia IRIG-B/DCF 77 /19

20 Substation Automation / 6MD63 Selection and ordering data Description Order No. Order code 6MD63 bay control unit with local control 6MD63 AA0 Housing, binary inputs (BI) and outputs (BO), measuring transducer Housing½19,11BI,8BO,1livestatuscontact 1 Housing ½ 19, 24 BI, 11 BO, 4 power relays, 1 live status contact 2 Housing ½ 19, 20 BI, 11 BO, 2 measuring transducer inputs, 4 power relays, 1 live status contact 3 Housing½19,20BI,6BO,4powerrelays,1livestatuscontact 4 1) Housing 1 / 1 19, 37 BI, BO, 8 power relays, 1 live status contact 5 Housing 1 /1 19, 33 BI, BO, 2 measuring transducer inputs, 8 power relays, 1 live status contact 6 Housing ½ 19, 33 BI, 9 BO, 8 power relays, 1 live status contact 7 1) Current transformer I n No analog measured variables 0 1A 2) 1 5A 2) 5 Rated auxiliary voltage (power supply, indication voltage) 24 to 48 V DC, threshold binary input 19 V 3) 2 60 to 125 V DC 4), threshold binary input 19 V 3) to 250 V DC 4), 115 to 230 V AC, threshold binary input 88 V 3) 5 Unit design For panel surface mounting, plug-in terminal, detached operator panel For panel surface mounting, 2-tier terminal, top/bottom For panel surface mounting, screw-type terminal, detached operator panel For panel flush mounting, plug-in terminal (2/3 pin AMP connector) For panel flush mounting, screw-type terminal (direct connection/ring-type cable lugs) For panel surface mounting, screw-type terminal (direct connection / ring-type cable lugs), without HMI For panel surface mounting, plug-in terminal without HMI A B C D E F G Region-specific default settings/function versions and language settings Region DE, 50 Hz, IEC, language: German, changeable Region World, 50/60 Hz, IEC/ANSI, language: English (GB), changeable Region US, 60 Hz, ANSI, language: English (US), changeable Region FR, IEC/ANSI, language: French, changeable Region World, IEC/ANSI, language: Spanish, changeable A B C D E 1) Only for position 7 = 0 2) Rated current can be selected by means of jumpers. 3) The binary input thresholds can be selected in two stages by means of jumpers. 4) Transition between the two auxiliary voltage ranges can be selected by means of jumpers. 5) Not with position 9 = B ; if 9 = B ; please order 6MD6 unit with RS485 port and separate fiber-optic converter. /20 System interface (on rear of unit/port B ) No system port 0 IEC protocol, electrical RS232 1 IEC protocol, electrical RS485 2 IEC protocol, 820 nm fiber optic, ST connector 3 PROFIBUS-FMS Slave, electrical RS485 4 PROFIBUS-FMS Slave, fiber optic, single ring, ST connector 5) 5 PROFIBUS-FMS Slave, fiber optic, double ring, ST connector 5) 6 PROFIBUS-DP Slave, RS485 9 L 0 A PROFIBUS-DP Slave, 820 nm fiber optic, double ring, ST connector 5) 9 L 0 B MODBUS, RS485 9 L 0 D MODBUS, 820 nm fiber optic, ST connector 5) 9 L 0 E DNP 3.0, RS485 9 L 0 G DNP 3.0, 820 nm fiber optic, ST connector 5) 9 L 0 H IEC 61850, 100 Mbit Ethernet, electrical, double, RJ45 connector 9 L 0 R IEC 61850, 100 Mbit Ethernet, optical, double, ST connector 5) 9 L 0 S DIGSI 4/modem interface (on rear of unit/port C) No port on rear side 0 DIGSI 4, electrical RS232 1 DIGSI 4, electrical RS485 2 DIGSI 4, optical 820 nm, ST connector 3 Measuring Basic metering (current, voltage) 0 Slave pointer, mean values, min/max values only for position 7= 1 and 5 2

21 Substation Automation / 6MD66 SIPROTEC 4 6MD66 High-Voltage Bay Control Unit Fig. /17 SIPROTEC 4 6MD66 high-voltage bay control unit Description The 6MD66 high-voltage bay control unit is the control unit for high voltage bays from the SIPROTEC 4 relay series. Because of its integrated functions, it is an optimum, low-cost solution for high-voltage switchbays. The 6MD66 high-voltage bay control unit also has the same design (look and feel) as the other protection and combined units of the SIPROTEC 4 relay series. Configuration is performed in a standardized way with the easy-to-use DIGSI 4 configuration tool. For operation, a large graphic display with a keyboard is available. The important operating actions are performed in a simple and intuitive way, e.g. alarm list display or switchgear control. The operator panel can be mounted separately from the unit, if required. Thus, flexibility with regard to the mounting position of the unit is ensured. Integrated key-operated switches control the switching authority and authorization for switching without interlocking. High-accuracy measurement (± 0.5 %) for voltage, current and calculated values P and Q are another feature of the unit. LSP2187-afp.eps Function overview Application Integrated synchro-check for synchronized closing of the circuit-breaker Automation can be configured easily by graphic means with CFC Flexible, powerful measured-value processing Connection for 4 voltage transformers, 3 current transformers, two 20 ma transducers Volume of signals for high voltage Up to 1 ½-pole circuit-breakers can be operated Up to 11 2-pole switching devices can be operated Up to 65 indication inputs, up to 45 command relays Can be supplied with 3 volumes of signals as 6MD662 (35 indications, 25 commands), 6MD663 (50 indications, 35 commands) or 6MD664 (65 indications, 45 commands); number of measured values is the same Switchgear interlocking Inter-relay communication with other devices of the 6MD66 series, even without a master station interface with higher level control and protection Suitable for redundant master station Display of operational measured values V, I, P, Q, S, f,cosϕ (power factor) (single and three-phase measurement) Limit values for measured values Can be supplied in a standard housing for cubicle mounting or with a separate display for free location of the operator elements 4 freely assignable function keys to speed up frequently recurring operator actions Communication interfaces System interface IEC Ethernet IEC protocol PROFIBUS-FMS/-DP Service interface for DIGSI 4 (modem) Front interface for DIGSI 4 Time synchronization via IRIG B/DCF 77 /21

22 Substation Automation / 6MD66 Functions Communication With regard to communication between components, particular emphasis is placed on the SIPROTEC 4 functions required for energy automation. Every data item is time-stamped at its source, i.e. where it originates. Information is marked according to where it originates from (e.g. if a command originates local or remote ) The feedback to switching processes is allocated to the commands. Communication processes the transfer of large data blocks, e.g. file transfers, independently. For the reliable execution of a command, the relevant signal is first acknowledged in the unit executing the command. A check-back indication is issued after the command has been enabled (i.e. interlocking check, target = actual check) and executed. Fig. /18 Connection diagram of the switching devices (circuit-breaker 2 poles closed, 1 pole open; disconnector/earthing switch 1½ pole) In addition to the communication interfaces on the rear of the unit, which are equipped to suit the customer s requirements, the front includes an RS232 interface for connection of DIGSI. This is used for quick diagnostics as well as for the loading of parameters. DIGSI 4 can read out and represent the entire status of the unit online, thus making diagnostics and documentation more convenient. It is in principle possible to implement other communication protocols upon request. Control The bay control units of the 6MD66 series have command outputs and indication inputs that are particularly suited to the requirements of high-voltage technology. As an example, the 2-pole control of a switching device is illustrated (see Fig. /18). In this example, two poles of the circuit-breaker are closed and 1 pole is open. All other switching devices (disconnectors, earthing switches) are closed and open in 1½-pole control. A maximum of switching devices can be controlled in this manner. A complete 2-pole control of all switching devices (see Fig. /19) is likewise possible. However more contacts are required for this. A maximum of 11 switching devices can be controlled in this manner. Fig. /19 2-pole connection diagram of circuit-breakers and disconnectors A possible method to connect the switching devices to the bay control unit 6MD66 is shown in Fig /20. There it is shown how three switching devices Q0, Q1, and Q2 are connected using 1½ pole control. /22

23 Substation Automation / 6MD66 Functions Using the CFC (Continuous Function Chart) available in all SIPROTEC 4 units, the bay interlock conditions can, among other things, be conveniently configured graphically in the 6MD66 bay control unit. The inter-bay interlock conditions can be checked via the inter-relay communication (see next section) to other 6MD66 devices. With the introduction of IEC communication, the exchange of information for interlocking purposes is also possible via Ethernet. This is handled via the GOOSE message method. Possible partners are all other bay devices or protection devices which support IEC GOOSE message. In the tests prior to command output, the positions of both key-operated switches are also taken into consideration. The upper key-operated switch corresponds to the S5 function (local/remote switch), which is already familiar from the 8TK switchgear interlock system. The lower key-operated switch effects the changeover to noninterlocked command output (S1 function). In the position Interlocking Off the key cannot be withdrawn, with the result that non-operation of the configured interlocks is immediately evident. Fig. /20 Typical connection for 1½-pole control The precise action of the key-operated switch can be set using the parameter switching authority. With the integrated function switchgear interlocking there is no need for an external switchgear interlock device. Furthermore, the following tests are implemented (parameterizable) before the output of a command: Target = Actual, i.e. is the switching device already in the desired position? Double command lockout, i.e. is another command already running? Individual commands, e.g. earthing control can additionally be secured using a code. /23

24 Substation Automation / 6MD66 Functions The bay control unit can, upon closing of the circuit-breaker, check whether the synchronization conditions of both partial networks are met (synchro-check). Thus an additional, external synchronization device is not required. The synchronization conditions can be easily specified using the configuration system DIGSI 4. The unit differentiates between synchronous and asynchronous networks and reacts differently upon connection: In synchronous networks there are minor differences with regard to phase angle and voltage moduli and so the circuit-breaker response time does not need to be taken into consideration. For asynchronous networks however, the differences are larger and the range of the connection window is traversed at a faster rate. Therefore it is wise here to take the circuit-breaker response time into consideration. The command is automatically dated in advance of this time so that the circuit-breaker contacts close at precisely the right time. Fig. /21 illustrates the connection of the voltages. As is evident from Fig. /21, the synchronization conditions are tested for one phase. The important parameters for synchronization are: U min < U < U max (Voltage modulus) Δ < Δ max (Angle difference) Δf < Δf max (Frequency difference) Using the automation functions available in the bay control unit, it is possible to connect various reference voltages depending on the setting of a disconnector. Thus in the case of a double busbar system, the reference voltage of the active busbar can be automatically used for synchronization (see Fig. /22). Alternatively the selection of the reference voltage can also take place via relay switching, if the measurement inputs are already being used for other purposes. Fig. /21 Connection of the measured values for synchronization Fig. /22 Voltage selection for synchronization with duplicate busbar system Fig. /23 Simultaneous connection of measured values according to a two-wattmeter circuit and synchronization /24

25 Substation Automation / 6MD66 Functions Synchronization The bay control unit offers the option of storing various parameter sets (up to eight) for the synchronization function and of selecting one of these for operation. Thus the different properties of several circuitbreakers can be taken into consideration. These are then used at the appropriate time. This is relevant if several circuitbreakers with e.g. different response times are to be served by one bay control unit. The measured values can be connected to the bay control unit in accordance with Fig. /21 (single-phase system) or Fig. /23 (two-wattmeter circuit). The synchronization function can be parameterized via four tabs in DIGSI. Fig. /24 Power System Data, sheet for parameters of the synchronization function LSP2493en.tif Fig. /25 General parameters of the synchronization function Fig. /26 Parameter page for asynchronous networks Fig. /27 Parameter page for asynchronous networks LSP2495en.tif LSP2494en.tif LSP2496en.tif /25

26 Substation Automation / 6MD66 Communication Communication The device is not only able to communicate to the substation control level via standard protocol like IEC 61850, IEC or others. It is also possible to communicate with other bay devices or protection devices. Two possibilities are available. Inter-relay-communication The function inter-relay-communication enables the exchange of information directly between 6MD66 bay controller devices. The communication is realized via Port C of the devices, so it is independent from the substation communication port B. Port C is equipped with a RS485 interface. For communication over longer distances, an external converter to fiber-optic cable can be used. An application example for inter-relaycommunication is shown in Fig. /29. Three 6MD66 devices are used for control of a 1½ circuit-breaker bay. One device is assigned to each of the three circuitbreakers. By this means, the redundancy of the primary equipment is also available on the secondary side. Even if one circuitbreaker fails, both feeders can be supplied. Control over the entire bay is retained, even if one bay control unit fails. The three bay control units use the inter-relay-communication for interchange of switchgear interlocking conditions. So the interlocking is working completely independent from the substation control level. IEC GOOSE With the communication standard IEC 61850, a similar function like interrelay-communication is provided with the GOOSE communication to other IEC devices. Since the standard IEC is used by nearly all SIPROTEC devices and many devices from other suppliers, the number of possible communication partners is large. The applications for IEC GOOSE are quite the same as for inter-relay-communication. The most used application is the interchange of switchgear interlocking information between bay devices. GOOSE uses the IEC substation Ethernet, so no separate communication port is needed. The configuration is shown in Fig. /30. The SIPROTEC devices are connected via optical Ethernet and grouped by voltage levels (110 kv and 20 kv). The devices in the same voltage level can interchange the substation-wide interlocking information. GOOSE uses the substation Ethernet. Fig. /28 Typical application: 1½ circuit-breaker method (disconnector and earthing switch not shown) Fig. /29 Connection matrix of inter-relay communication in DIGSI 4 Fig. /30 Connection for IEC GOOSE communication Like inter-relay-communication, GOOSE also supplies a status information for supervision of the communication. In case of interruption, the respective information is marked as invalid. Therefore, non-affected information still can be used for interlocking, and a maximum functional availability is guaranteed. LSP2227f.tif /26

27 Substation Automation / 6MD66 Functions Measured-value processing is implemented by predefined function modules, which are likewise configured using DIGSI 4. The transducer modules are assigned in the DIGSI 4 assignment matrix to current and voltage channels of the bay control unit. From these input variables, they form various computation variables (see Table /1). Fig. /31 DIGSI 4 Parameter view transducer packages LSP2228f.tif The individual transducer modules can be activated in the functional scope of the unit and will then appear in the DIGSI 4 assignment matrix with the input channels and output variables from Table 1. The output variables can then be assigned to the system interface or represented in the measured value window in the display. Name of the transducer module Max. availability of transducers on the unit (can be set via the functional scope) Required input channels Calculated variables (= output variables) Transducer V x 1 V V, f Transducer I x 1 I I, f Transducer 1 phase x 3 V, I V, I, P, Q, S, ϕ, cos (PF), sin, f Transducer 3 phase x 1 V1, V2, V3, I1, I2, I3 V0, V1, V2, V3, V12, V23, V31, I0, I1, I2, I3, P, Q, S,, cos (PF), sin, f Transducer twowattmeter circuit Table /1 Properties of measured-value processing x 1 V1, V2, I1, I2 V12, V13, I2, I3, P, Q, S,, cos (PF), sin, f Sample presentation of the measured value display. LSP2189f.tif Fig. /32 /27

28 Substation Automation / 6MD66 Functions The connection of the input channels can be chosen without restriction. For the twowattmeter circuit, the interface connection should be selected in accordance with Fig. /33. The two-wattmeter circuit enables the complete calculation of a three-phase system with only two voltage and two current transformers. For internal metering, the unit can calculate an energy metered value from the measured current and voltage values. If an external meter with a metering pulse output is available, the bay control unit can obtain and process metering pulses via an indication input. The metered values can be displayed and passed on to a master unit. A distinction is made between forward, reverse, active and reactive power (± kwh, ± kvarh). With integrated logic, the user can set, via a graphic interface (CFC, Continuous Function Chart), specific functions for the automation of switchgear or substation. Functions are activated via function keys, binary input or via communication interface. Processing of internal indications or measured values is also possible. The switching authorization (control authorization) (interlocked/non-interlocked, corresponds to key-operated S1 in the 8TK interlock system) and the switching authority (local/remote, corresponds to key-operated S5 for 8TK) can be preset for the SIPROTEC 4 bay control unit using key-operated switches. The position of both keys is automatically evaluated by command processing. The key for operation without interlocks cannot be removed when in the position non-interlocked, such that this mode of operation is immediately recognizable (see also page /23, Section Switchgear interlockings ). Every change in the key-operated switch positions is logged. Fig. /33 Two-wattmeter circuit (connection to bay control unit) Chatter blocking Chatter blocking feature evaluates whether, in a configured period of time, the number of status changes of indication input exceeds a specified figure. If exceeded, the indication input is blocked for a certain period, so that the communication line to the master unit will not be overloaded by disturbed inputs. For every binary input, it is possible to set separately whether the chatter blocking should be active or not. The parameters (number of status changes, test time, etc.) can be set once per unit. To avoid the transmission of information to the master unit during works on the bay, a transmission blocking can be activated. Indications can be filtered and delayed. Filtering serves to suppress brief changes in potential at the indication input. The indication is passed on only if the indication voltage is still present after a set period of time. The filter time can be set from 0 to 24 hours in 1 ms steps. It is also possible to set the filter time so that it can, if desired, be retriggered. Furthermore, the hardware filter time can be taken into consideration in the time stamp; i.e. the time stamp of a message that is detected as arriving will be predated by the known, constant hardware filter time. This can be set individually for every message in a 6MD66 bay control unit. /28

29 Substation Automation / 6MD66 Functions Auto-Reclosure (ANSI 79) The 6MD66 is equipped with an auto-reclosure function (AR). The function includes several operating modes: Interaction with an external device for auto-reclosure via binary inputs and binary outputs; also possible with interaction via IEC GOOSE Control of the internal AR function by external protection 3-pole auto-reclosure for all types of faults; different dead times are available depending on the type of the fault 1-pole auto-reclosure for 1-phase faults, no reclosing for multi-phase faults 1-pole auto-reclosure for 1-phase faults and 2-phase faults, no reclosing for multi-phase faults. 1-pole auto-reclosure for 1-phase and 3-pole auto-reclosure for multi-phase faults 1-pole auto-reclosure for 1-phase faults and 2-phase faults and 3-phase autoreclosure for multi-phase faults Multiple-shot auto-reclosure Interaction with the internal synchrocheck Monitoring of the circuit-breaker auxiliary contacts In addition to the above-mentioned operating modes, several other operating principles can be employed by means of the integrated programmable logic (CFC). Integration of auto-reclosure in the feeder protection allows the line-side voltages to be evaluated. A number of voltage-dependent supplementary functions are thus available: DLC By means of dead-line-check (DLC), reclosure is effected only when the line is deenergized (prevention of asynchronous breaker closure) ADT The adaptive dead time (ADT) is employed only if auto-reclosure at the remote station was successful (reduction of stress on equipment). RDT Reduced dead time (RDT) is employed in conjunction with auto-reclosure where no teleprotection method is employed: When faults within the zone extension but external to the protected line of a distance protection are switched off for rapid auto-reclosure (RAR), the RDT function decides on the basis of measurement of the return voltage from the remote station which has not tripped whether or not to reduce the dead time. Breaker failure protection (ANSI 50BF) The 6MD66 incorporates a two-stage circuit-breaker failure protection to detect failures of tripping command execution, for example, due to a defective circuit breaker. The current detection logic is phase-selective and can therefore also be used in single-pole tripping schemes. lf the fault current is not interrupted after a settable time delay has expired, a retrip command or a busbar trip command will be generated. The breaker failure protection can be initiated by external devices via binary input signals or IEC GOOSE messages. LSP2229f.tif Fig. /34 Parameterization of time management The 6MD66 bay control units can, like the other units in the SIPROTEC 4 range, be provided with the current time by a number of different methods: Via the interface to the higher-level system control (PROFIBUS FMS or IEC 61850) Via the external time synchronization interface on the rear of the unit (various protocols such as IRIG B and DCF77 are possible) Via external minute impulse, assigned to a binary input From another bay control unit by means of inter-relay communication Via the internal unit clock. Fig. /34 illustrates the settings that are possible on the DIGSI interface. /29

30 Substation Automation / 6MD66 DIGSI 4 Configuration tool The PC program DIGSI 4 is used for the convenient configuration of all SIPROTEC 4 units. Data exchange with the configuration tool plustools of the energy automation system SICAM is possible, such that the bay level information needs only be entered once. Thus errors that could arise as a result of duplicated entries are excluded. DIGSI 4 offers the user a modern and intuitive Windows interface, with which the units can be set and also read out. The DIGSI 4 configuration matrix allows the user to see the overall view of the unit configuration at a glance (see Part 3, Fig. 3/2). For example, all allocations of the binary inputs, the output relays and the LEDs are shown at a glance. And with one click of the button, connections can be switched. Also the measuring and metering values are contained in this matrix. Fig. /35 CFC plan for interlocking logic (example) Special attention has been paid to commissioning. All binary inputs and outputs can be read and set directly. This can simplify the wire checking process significantly for the user. CFC: Reduced time and planning for programming logic With the help of the CFC (Continuous Function Chart), you can configure interlocks and switching sequences simply by drawing the logic sequences; no special knowledge of software is required. Logical elements, such as AND, OR and time elements, measured limit values, etc. are available. Display editor A convenient display editor is available to design the display on SIPROTEC 4 units (see Part 3, Fig. 3/6). The predefined symbol sets can be expanded to suit the user. Drawing a single-line diagram is extremely simple. Operational measured values (analog values) in the unit can be placed where required. In order to also display the comprehensive plant of the high-voltage switchgear and controlgear, the feeder control display of the 6MD66 bay control unit can have a number of pages. /30 Fig. /36 General configuration view of the bay control unit In this process, several pages of a control display can be configured under one another, and the user can switch between them using the cursor. The number of pages, including the basic display and the feeder control display, should not exceed 10, as otherwise the memory in the unit will be completely occupied. Fig. /36 illustrates the general view of the 6MD66 bay control unit on the DIGSI 4 configuration interface. As is the case with the SIPROTEC 4 protection units, there is an icon called Functional Scope. It enables the configuration of measured-value processing and the synchronization function and the protection functions (auto-reclosure and breaker failure protection).