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ABB Power Technologies Customer NameOur Ref. 3AST 000 557 Rev 01 Your Ref.

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Network Manager Distribution Management

Table of Contents

1. Distribution Management Systems (DMS) – Introduction....................................2

2. Integrated DMS Concept...................................................................................2

Network Manager/Distribution from ...............................................................5

3. System Overview...............................................................................................8

4. Functional Overview........................................................................................12

5. Control Room Operations Management........................................................145.1 Circuit Operating Diagrams.................................................................14

5.1.1 Operating Diagram Organization...........................................155.1.2 Operation Diagram Representation.......................................15

5.2 Circuit Tracing and Coloring................................................................165.3 Device Location...................................................................................175.4 Interlocking and Automatic Interlock Checks.......................................175.5 Switch Order/Switching Job Management...........................................185.6 Tagging................................................................................................185.7 Safety Documents...............................................................................195.8 Temporary Network Changes (Jumpers).............................................19

6. Distribution Network Analysis.......................................................................216.1 Load Calibration...................................................................................216.2 Distribution /Operator Power Flow- Balanced......................................226.3 Distribution/Operator Load Flow - Unbalanced...................................236.4 Ground Fault and Short Circuit Management......................................246.5 Fault Location, Isolation and System Restoration...............................25

7. Service Information System and Work Order Clearance.............................277.1 Service Information System.................................................................277.2 Work Order Clearance.........................................................................28

8. Trouble Call based Outage Management......................................................298.1 Trouble Call Management...................................................................298.2 Outage Analysis...................................................................................308.3 Crew and Resource Management.......................................................318.4 Outage Status Monitoring and Reporting............................................31

9. Data Engineering.............................................................................................339.1 External master database (GIS/NIS import)........................................359.2 Internal master database (DE400).......................................................37

3AST001662, 2001-12-20.We reserve all rights in this document and in the information contained therein. Reproduction, use or disclosure to third parties without express authority is strictly forbidden. © ABB Utilities; 2001.


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1. Distribution Management Systems (DMS) – Introduction

A DMS is the key system within the overall mosaic of real-time and support functions that are now becoming common place within utilities with distribution networks and required for efficient operation. Substation (SA) and Feeder Automation (FA) when combined with traditional SCADA provide the real-time elements whereas Enterprise IT systems (EITS) such as Geographic Information System (GIS), Work Management (WMS) and Customer Information /Relationship Management systems (CIS/CRM) provide the necessary information on assets, personnel and customers (consumers).

Utilities are implementing DMS s to deliver efficiencies to the distribution network business. The justification varies form utility to utility and from country to country depending on the business environment. Typical general reasons and savings given by companies are:

Reduction in Operation and Maintenance Costs (crew time savings, other manpower savings, improved control room processes, report generation etc.)

Network Capacity Expansion Deferral (deferral of new substation and feeder capacity)

Improvement in network efficiency for power delivery (reduction in losses, improved voltage regulation and load control)

Improved reliability and quality (generally reduced restoration times (SAIDI)

Improved Asset Loading and Network Data for Planning information (correct loading data and information on the network performance)

These benefits and savings are directly related to the level of remote control (automation), DMS functions implemented and the scope for improvement within the existing power distribution network. The scope for improvement is dependent on network structure, design policies, the operating condition of the network and the regulatory environment.

Although DMSs have been evolving over the past 20 years with the implementation of SCADA adapted for distribution networks, Trouble Call based Outage Management Systems and applications running on GIS platforms, all as independent applications, there is now a clear indication for a truly integrated approach.

The differentiator between an Energy Management Systems for Transmission networks and a DMS is the ability to accommodate both real-time and manual control of an electric network with many elements as required by distribution systems.

2. Integrated DMS ConceptA DMS can be formulated as comprising four main modules which, when implemented, form a tightly integrated system with common command structure and seamless data transfers. These are the four key control modules.

Control Room Operations Management (CROM)

SCADA

Advanced Applications (ADVAPPS)

Outage Management -Trouble Call Management (TCM)



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All of which have to be supported by other Enterprise IT systems through a Data Engineering function that provides one point of data entry from these systems

The overall concept is illustrated in Figure 1 below.

Figure 1, Main modules of an integrated DMS

Control Room Operations ManagementThe Control Room Operations Management function is created to encompass the need for one view of the operations process that is conducted in the control room on a daily basis. It represents the user interface or Human Machine Interface (HMI). This function provides the operator with his view on the network - however he wishes to visualize it - geographically, schematically, in either a world map or paged format. It also provides the command structure for controlling the network (SCADA and manually operated devices), maintaining the operating diagram(s) with operator notes and tags, performing temporary network changes, importing permanent changes and invoking any other application function that has been implemented as part of the DMS. Further all tabular output such as alarms; outage management windows, crew management and switching order preparation are managed through the Control Room Operations Management module. In summary Control Room Operations Management provides the following:

Control Room Graphics System (CRGS) for network diagram display. Interface to SCADA (in fully integrated systems traditional SCADA is effectively

expanded to provide the CROM function).3AST001662, 2001-12-20.We reserve all rights in this document and in the information contained therein. Reproduction, use or disclosure to third parties without express authority is strictly forbidden. © ABB Utilities; 2001.

CISCustomer Information

System

WMSWork Management

System

NISNetwork Information

SystemAs-Built System,GIS

Corporate Enterprise IT Systems & Functions

SupervisoryControlAndDataAcquisition

(SCADA)

Control Room Functions

(TCM)

Data Engineering

Real-Time System Events

Demand TimeSystem EventsResponse Time

(ADVAPPS)

AdvancedApplications (3)

(4)

(Trouble Call)

ManagementOutage

ControlRoom

Management(CROM)

(2)

(1)

Operations


System

WMSWork Management

System




System


System

WMSWork Management

System

WMSWork Management

System





Corporate Enterprise IT Systems & Functions

SupervisoryControlAndDataAcquisition

(SCADA)

Control Room Functions

(TCM)

Data Engineering

Real-Time System Events

Demand TimeSystem EventsResponse Time

(ADVAPPS)


(ADVAPPS)


(4)(4)

(Trouble Call)

ManagementOutage

(Trouble Call)

ManagementOutage

ControlRoom

Management(CROM)

(2)

(1)

Operations


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Switching Order Preparation and Management. Access to Advanced Applications (ADVAPPS) including Trouble Call (TCMS) or

Outage Management (OM). Interface to Data Engineering Application for DMS data modifications and input from

enterprise IT systems (EIT).

SCADAThis module provides all the traditional real-time functions such as, data acquisition, control, alarming and alarm management, historical archiving (IS&R), trend analysis etc.

Advance Applications (ADVAPPS) Advance Applications should be viewed as operator decision support tools that allow calculations to be made on the network to access loading conditions and the viability of making switching changes. They also provide a system approach to the optimal control of VARs, voltage regulation, and loss minimization. Intelligent applications are also used for fault location, isolation and restoration in which remedial switching arrangements are proposed automatically. They run in real-time on the “as operated” network state within the DMS. The application must execute in real-time yet have study capability for operational planning

Outage Management – Trouble Call ManagementOutage management is an important function since its purpose is to facilitate returning a faulted system to full supply as fast as possible while minimizing the number of customers affected. The Trouble Call Management approach has traditionally been the main method of achieving this with limited input from SCADA. This approach is changing with increased SCADA penetration encompassing SA and FA, which provide faster information on fault location and also notification to the operators. An integration of ADVAPPS and TCM is now possible to further improve the outage management capabilities yet maintain the need to notify customers of events. Hence in figure 1 above the outage management module is shown to overlap the CROM and ADVAPPS modules too infer this integration.

Data Engineering (DE)The DE module is a key function for populating and maintaining the database within the real-time control room system. The module should have sufficient features to either accept data from an external source, facilitate database creation as a standalone function or a combination of both. The latter requirement is usual since even though EIT systems such as GIS hold considerable network data, additional data to describe the real-time data acquisition system and the organization of displays has to be added. Import of network data form a GIS is beneficial provided that the GIS has a full Network Information System (NIS) implemented that provides a decipherable connectivity and attribute model for input to the DMS.

Any incremental update to the network or data acquisition system must be made through the DE module where it is a requirement for a DMS that incremental changes can be made to the run-time system on-line without the need to fail-over (the method traditionally used for most transmission EMSs).

To allow interfaces to be made between the DMS and other EIT applications open standard APIs are now considered a necessity even though certain other data modeling standards are incomplete.

Redundancy



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All modern DMS architectures require redundancy having hot fail-over without loss of data. The redundancy feature should extend to all mission-critical DMS control room functions and emergency or backup control centers.

Distribution Network Business ProcessesThe successful implementation of a corporate Distribution Management System, DMS, must provide support to all business units in the utility. As visualized in Figure 2, the network management related activities of planning, operation and control are highly interdependent with the financial, commercial and support service functions, since information and operation guide-lines are provided by these business functions. This figure is only conceptual identifying the major corporate functions and information flows.

To protect the invested capital and to minimize the duplication of data and functions, the DMS must also be able to take full advantage of these related corporate information systems.

Control

Support ServiceFinancial

Planning

Operations

Commercial

• Strategy• Personnel

• System Expansion & Design• Normalization (Standards)

• Quality of Service• Human & Material Resource Mgmt.

• SCADA/EMS/DMS• Load Management• Autm. Meter Reading• Crews

• Customer Information System• Billing & Accounting

• AM/FM/GIS• Work Order• Inventory• Engineering

Plans Conditions

ObjectivesConsumer &

Load InfoAsset

Information

Figure 2 – The Distribution Management Context

.

The necessity of information technology as an effective business tool in re-engineering the business has been identified by the utilities as they strive for efficiencies. These efficiencies can only be exploited if all functions required managing the network business, changing from isolated islands of information to a coordinated and integrated information system.

Open computer architectures and the standardization of operating systems, networked graphic interfaces and communication protocols now allow the realization of integrated and coordinated corporate business tools.

Network Manager/Distribution from Network Manager SCADADMS follows the DMS concept described in the previous sections and provides powerful support for operation of distribution networks. The DMS is integrated in ABB’s Network Manager environment.



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The Network Manager exhibits the following salient features

A fully integrated Distribution Management System with comprehensive and powerful functionality for distribution system operation based on extensive Control Room Operations Management functions.

Offers a homogeneous and user friendly Human Machine Interface for the whole spectrum of distribution management applications.

Provides a unified graphical data engineering environment for data take-on and data maintenance, facilitating a single point of entry for both graphical representations and object data.

High performance and robust Advanced Applications with a continuous multi voltage network model.

Rule based dynamic network coloring and tracing feature with global and local settings

Integration capabilities with Geographical Information System (AM/FM/GIS) databases.

Provides smooth migration paths from distribution SCADA to complete Distribution Management Systems.

Dynamic Authority Control Assignment Full dual redundancy with hot standby and backup/emergency control room

function Cyber security enabled following developing global standards Wed User interface for view access (IS500). The flexibility of Network Manager DMS allows the appropriate modules and sub modules to be selected to configure an implementation that will meet not only the utilities control room practices, operations procedures and business processes but also the economic goals of the enterprise. NM DMS has successfully been delivered and in operation at a number of site of which two are notable for their particular implementation

The ABB experience in delivering a variety of solutions using the appropriate Network Manger modularity to meet specific requirements is proven through many projects. The significant ones in operation or under contract are mentioned below for reference:

Hidroelectrica del Cantabrico in Spain (with integrated Trouble Call based Outage Management);

E.on ( formerly Sydkraft) in Sweden (with integrated Trouble Call based Outage Management);

Essent and Interelektra in Holland and Belgium, respectively; and

Hong-Kong’s China Light and Power.

ESCOM in South Africa (5 control rooms) – under contract

Zheijiang Provincial Electricity, China

Reliance Energy Delhi, India (under contract)

Reliance Energy Mumbai, India (under contract)

Patna Electric – PESU, India (under contract)

The E.on (Sydkraft) reference is of particular relevance due to the fact that this utility has in operation the latest version of the integrated Network Manager SCADA/DMS/Trouble Call based Outage Management System (TCOMS) and Facilplus based data engineering and Network Information (NIS).System



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Similarly integrated Network Manager SCADA/DMS/OMS solutions are currently under deployment at Eskom Distribution in the Republic of South Africa (5 systems) and for the Zheijiang Provincial Electricity Company at the cities of Hangzhou and Ningbo in China. In these cases the systems are integrated with non-ABB network information systems supplied by Smallworld but under a total turn key project delivered by ABB for GIS and DMS implementation.

The DMS implementation at China Light and Power has in been operation for over five years presently with a target to be controlling 6,000RTUs by the end of 2005 with an expansion target of at least 12,000 controlled RTUs. The real-time data change facility within Network Manager has allowed this continual expansion to be accomplished where the additions of remotely controlled distribution substation approaches ten a day without system fail over.

In India Network Manager SCADA/DMS has been selected by Reliance Energy for their networks in Delhi and Mumbai, the latter replacing an existing Siemens system. The SCADA functionality has passed FAT in an accelerated schedule of 6 months and now the DMS data intensive task is on going. Network Manager has also been selected by the Patna Electric Utility for their city network.



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3. System OverviewThe Network Manager/Distribution concept is modular made up of a number of independent yet integrated functions running on top of a base platform. This modularity allows for flexible configuration of the DMS, adding modules as and when required.

Hence, the Network Manager facilitates a gradual growth from a base system through phased implementation as the distribution network operating requirements expand or change.

The Network Manager base platform provides the real-time environment with message passing and database management required by the application modules. The platform is a powerful environment for the implementation and execution of applications, and allows data to be distributed across a number of sites.

The platform services are common to the whole family of Network Manager products; thus integrated control of transmission and distribution systems is possible from one base platform.

Network Manager forms the control room system of a corporate-wide DMS.

Network Manager/Distribution ArchitectureNetwork Manager is a fully integrated system with tight coupling between the real-time and display functions. This meets the performance requirements of distribution systems with multiple voltage levels and thus e.g. Dynamic Network Coloring (DNC) and control actions at any level propagate between the various voltage levels. Integration with the EMS hierarchy is also achieved with this architecture (Figure 3).

Figure 3 Typical Network Manager System showing distribution of processes and applications


RTUs

LAN Switches

WAN

Routers

SCADA/DMS

Servers

SIS/OMS Operator Local(9 stations)

Other users (2 stations)

Alarm Logger

Operator Stations

DTS DE Web

ProtocolTranslator

Plotter

Engineering (5 stations)

RTUs

LAN Switches

WAN

Routers

SCADA/DMS

Servers

SIS/OMS Operator Local(9 stations)

Other users (2 stations)

Alarm Logger

Operator Stations

DTS DE Web

ProtocolTranslator

Plotter

Engineering (5 stations)


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The minimum system comprises the basic Control Room Operations Management (CROM) functions. CROM includes all the basic functions required by operators to manage the daily tasks in the control room for both remotely controlled and manually operated network devices. The full-graphics Human Machine Interface (HMI) provides the operator with a common method look–and–feel invoking all CROM functions (Figure 4).

Figure 4 Sample Displays form the Network Manager WS500 HMI

The Network Manager functionality is supported by following application modules:

Control Room Operations Management Distribution Network Analysis Work Order Management (SIS) Outage Management (Trouble Call and Advanced Application based) Support and Maintenance toolsIntegration with external systemsThe Network Manager can be integrated with other external systems and the following interfaces can be provided. Network Manager includes a powerful set of Application Programming Interfaces (APIs) to implement these interfaces. Since all external systems are different special studies on how to design the interfaces have to be conducted in each individual case.

Horizontal IntegrationGIS/CIS

The Geographical Information Systems (GIS), Automated Mapping/Facilities Management (AM/FM) are the foundation for network information (Network Information System (NIS)) maintain the "as-built" asset and facilities data and are used as the primary network extension planning and documentation tool. Network Manager supports incremental and total import of data from GIS, AM/FM and NIS systems. This means that the data defined at the planning stage can be used by Network Manager and no double input of data is necessary. This procedure is normally called GIS Import.

The Customer Information System (CIS)/ Customer Relationship Management (CRM) containing all customer records and billing information, personnel systems and work management applications for construction management.

Work Management Systems (WMS) and Computerized Maintenance Management Systems (CMMS) are also being deployed by utilities to optimize maintenance strategies and procedures through efficient crew scheduling and maintenance planning. Use of mobile resources is part of this function and must be coordinated in the management of information flow.


HTML Web Document

Imported GIS

Worldmap

Traditional Display

Document

ActiveX Document


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Distribution Planning

The Network Manager can operate with any distribution planning environment that the utility has or intends to implement, using a customized interface where required. This allows for integrated long term planning of the network expansion and upgrades to be conducted using as the base the same network connectivity mode. Planning ahead for future network expansion results in a more efficient, manageable network, and also leads to more precise capital expenditure.

Vertical IntegrationDemand Side Management

Through the Control Room Management function access to Demand Side Management systems can be provided. These systems provide functions for peak load forecasting and the formulation and execution of load management strategies. With remote intelligent metering, readings can be performed as frequently as required, making flexible tariff switching and dynamic pricing possible. In addition, remote ground fault detection and remote load voltage readings can be used both for load modeling, planning and fault analysis purposes.

Substation Control and Protection

The capability to interface to ABB's or other vendor’s substation control and protection systems allows remote operation and setting of digital relays and protection equipment. It also helps in fault location by allowing the remote reading and presentation of results from fault recorders and protection equipment. Please refer to the SCADA section for further information.

APIs for IntegrationNetwork Manager maintains a set of APIs that allow the above interface to be created during projects once the data models and interface transactions have been defined.



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Figure 5 Graphical depiction of Network Manager APIs



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4. Functional OverviewThe Network Manager/Distribution is a state of the art software system for distribution network operation and planning that can be used in a number of ways of which the following are examples.

Detailed Information on Distribution Network StatusNetwork Manager continually provides a detailed graphical current image of the distribution system through a system operating diagram display picture. The operator can navigate around the diagram(s) to display more detailed information such as:

Status: Current state of switching, equipment, outages, restoration and on-going maintenance.

Operating data: Voltages, flows, and equipment loading shown in the operating diagrams. Operating data are based on both measured data and data calculated using Distribution Network Analysis functions.

Warning: Notification of severe operating or service problems, repair assignments. Temporary: Current operating conditions and operator notes (tags)The information is based on data from SCADA and Distribution Network Analysis applications.

Control Room DisplaysNetwork Manager provides the distribution dispatcher with a "mirror" of the distribution system's current status and expected future performance. A model of the distribution system is maintained with precise details on switching, dynamic topology, equipment settings and outages.

The dispatcher can choose to have the system to display this information according to his choice of operating diagram format, usually either as a geographically oriented distribution map or a one-line schematic diagram representation specific to the utility.

If a severe problem develops, the system brings it to the operator's attention by summarizing the problem in a message window and highlighting the affected equipment. Information displayed can be switched back and forth between diagram picture formats. Maps and diagrams can be instantly zoomed in and out, or panned over the system for a more detailed look at problem areas. Trouble areas, temporary measures, safety tags and more are summarized and highlighted.

The dispatcher can visualize trouble areas not only based on outages confirmed SCADA report, based on a crew’s action such as a manual switch operation, or by the crew’s field report, but also areas, where outages are “inferred” based on analysis of trouble calls. The system also makes information about the outages and affected trouble areas available to the Customer Service Representatives in the call center.

The operator can use Network Manager to prioritize the outages, choose the crews for the outages, track them through the restoration process and have information about the work status of the crews.

Control Room ProceduresOperating personnel have over the years developed procedures within the control room that have proven acceptable and ensured safe operation. Introduction of any new computerized system must respect the important procedures if it is to be accepted without significant disruption of personnel. It must thus be possible to imitate the majority of the



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control room procedures undertaken by the operating personnel in a utility. This is possible within the command structures of Network Manager’s on-line assistance to the operators when carrying out control commands. Use of standardized working procedures is facilitated.

When command structures are used for actions like coordination of manual switching operations performed by line crews, embedded safety procedures have to be followed before subsequent actions can be taken. The software automatically checks for grounding rods, mandatory and safety warning tags on the equipment being switched.

Executions of pre-defined and pre-tested sequential switching plans improve the speed and implementation of the plans. All event logging and reporting is automated and linked with the command structure of the Control Room Management module.

Network Manager provides a function for definitions of switching plans, which include tools for preparation, review and approval of switching plans and provides also further functions, which offer the operational staff an efficient and powerful tool, making it possible to administer, create, simulate and approve switching plans for work on the network in a swift and intuitive way via support of complex Switch Order Management workflow and distribution of information between different parts of a utility.



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5. Control Room Operations ManagementNetwork Manager control room operations management provides the operator with a view on the distribution network operation through open system standards and full graphics human machine facilities.

The Platform, SCADA and Human Machine Interface functionality is the basis for the DMS control room operations management:

Database and Message Passing Data Acquisition Remote Control Manual Entry Alarm and Event Handling Historical Data Processing

Specifically some SCADA and the Human Machine Interface functions are provided to meet the special needs in the DMS context:

Circuit Operating Diagram Circuit Tracing and Coloring Device Location Interlocking Switching Job Management Tagging Safety Documents Abnormal Switch Status Handling Temporary Network Changes

Other control room operations management functions are provided through other Network Manager components:

Distribution Network Analysis Work Order Management Outage Management Support and Maintenance tools

5.1 Circuit Operating Diagrams

Utilities have evolved their own particular operating diagrams for the control room to satisfy individual needs. Thus a variety of display picture organizations and representations exist within the industry. This is particularly evident for medium voltage systems where the number of network elements is large and the geographic coverage immense unlike higher voltage transmission networks which traditionally have followed only one common schematic representation.



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5.1.1 Operating Diagram Organization

The picture organization has been designed to accommodate most commonly used operating diagram organizations and representations for distribution networks that can also be linked to the transmission network operating diagrams.

The following describes, as an illustration, the commonly used display picture representations and their organization.

There are two basic methods of organizing operating or control diagram pictures

Top-down (page or sheet pictures) in which the entire network at the detailed operating level is arranged in a set of pages or operating islands. The structure of the actual distribution network (rings with limited inter-ties) is such that it is possible to set up these islands, since minimal interconnection exists with adjacent islands. Typically the islands have a maximum of five primary substations and interconnecting feeders. Navigation within each page is relatively simple using pan and zoom features since the majority of the diagram is easily visible on a typical control console monitor. Access to operating level diagrams is through a hierarchy of overview diagrams, starting from an overview of the service area from which a set of district diagrams can be accessed. From these the actual operating level diagrams are retrieved. Hence, the term "top down" for describing the organization of the pictures. The number of layers depends on their optimal organization and representation of the distribution network.

Bottom-up (world coordinate system - world map) uses as the basis for organization of the electric network a continuous display picture of the entire service area with sufficient detail for operation. Navigation is accomplished by virtually continuous pan and zoom features with extensive declutter capability. The overview diagram is obtained from the most simplified version of the basic system operating diagram. Therefore the designation "bottom-up". Other location routines facilitate the fast look-up and display of known elements in the world coordinate space. This representation is used by utilities with highly interconnected medium voltage networks or extensive rural systems where representation of distance is important. Also, the use of the same representation as in the GIS is considered critical.

Network Manager supports both these methods.

5.1.2 Operation Diagram Representation

In addition to the way operating diagrams are organized there are a number of typical representations being used by power distribution utilities.

Schematic. These diagrams are single-line representations of the network showing primary substation bus bar arrangements, feeder connections, distribution substations with switches and loads, and other line devices such as capacitors, regulators and fuses. They do not represent distance but aim to show an even density of information. The single-line diagrams are usually known as orthogonal since the lines are drawn only horizontally and vertically. This representation is used by both top-down and bottom-up organization of control room display pictures



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Geographic. A true geographic map of the network is used to control operation. Although providing accurate distance information and commonly used for rural networks, the congestion in dense areas of the network requires access to schematic pictures of primary substations and switching points. These are usually arranged on a page basis accessed from the geographic diagram. This representation refers only to the feeder layout and does not infer that background cadastral data is part of the representation

Geo-schematic. This representation is a combination of the first two. The general geographic layout is maintained, but in dense areas the network is stretched and in sparse areas the feeders are shortened.

Background Maps. Management of the manually operated medium voltage and low voltage networks requires more geographical orientation and information in order to effect network restoration, develop practical switching plans and supervise repair crews. Repair crews often need direction and then refer to geographical background maps. Access to detailed background maps of the "as-built" system with cadastral data is becoming a requirement in today’s DMS. It can be provided as picture loaded into Network Manager or by window access directly into a GIS.

The flexibility provided by the Human Machine Interface enables different representations to be selected independently or simultaneously as a set of linked pictures with all operating diagrams having the following features:

Not all circuit devices have to be represented in a diagram allowing the operator to work with simplified schematic and geographic representations.

The same object can be shown in several diagrams. Different symbols may be used in each of the diagram types. Each diagram may be displayed independently at different zoom and declutter levels. The organization of zoom and declutter levels can be independent for each diagram

type. Complete flexibility in the hierarchical linking of pictures. Toggling between representations.

5.2 Circuit Tracing and Coloring

Network components can be automatically colored using the Dynamic Network Coloring (DNC). Dynamic Network Coloring is a topology function that is based on the current status and connectivity and it displays lines, buses, etc. in appropriate colors. The result is presented by coloring of world map overview pictures and station single line diagrams. Dynamic Network Coloring has following features:

It reflects real-time events and status changes as they happen. It distinguishes network components with a common property (voltage, type, etc.) It provides the operator with the facility to analyze the conditions of any part of the

DMS network database.



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The following two modes of operation are provided.

Global Dynamic Network Coloring involving the entire network Local Tracing function provided to individual operatorsThe Dynamic Network Coloring function is also used for presenting the result of the Ground Fault Localization, the Short Circuit Localization and the Fault Localization, Isolation and System Restoration functions.

Tracing function services answer specific questions about the actual network connectivity and the power flow conditions:

Connected Source Tracing traces all sources connected to a selected element and colors all the valid paths.

Interconnection tracing traces all elements connecting two given elements and colors all paths between the elements.

Load Tracing traces all loads connected to a selected element and colors all the valid paths leading from the selected element to the consumers.

Main Source Tracing traces all sources connected to a selected element and colors the shortest path to the source with the highest defined apparent power and which is feeding that element.

Profile Tracing is a combination of connectivity and flow tracing. It gives the operator a possibility to display calculated values corresponding to points along a selected path in the power system, on an XY plot. This function is only available if the Operator Load Flow of the Distribution Network Analysis package is included in the scope.

5.3 Device Location

The Locate function enables the operator to quickly locate network components within the current operating diagram or globally through any alarm or event list or a dedicated dialogue.

The network components to be located can be selected from a list of objects, either on a global basis or after being sorted according to component type. Selection using the object ID text string with wild cards is supported. The network components to be located can be selected from status list, event list or alarm list.

When an object is selected, the current picture will be oriented around the selected object. If the current zoom and declutter level hides the selected object, the first visible level will be used. In principle all dynamic picture objects can be selected for device location. When an object exists in more than one picture a list of the pictures is given for selection.

The locate function also operates on both permanent and temporary objects (line cuts and jumpers).

5.4 Interlocking and Automatic Interlock Checks

The Interlock function prevents prohibited commands and manual entries of inappropriate status. The user can define an interlock condition, or a sequence of conditions, to be checked each time a control command is given or a new status of an indication is manually entered. Control requests that do not meet these conditions will normally be rejected, but can be by-passed in emergency and test situations if they are defined accordingly. Interlock conditions are logical and specified using the Network Manager Programming Language, e.g. checking that a certain device is open or a power line is de-energized.



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The system already includes some predefined interlock conditions that are based on topology and does not need a special programming. These are so called Automatic Interlock Checks and include:

Connecting grounded and energized devices Connecting two network groups or closing network loops Opening critical path, where a load will be de-energizedAlso the setting of a tag can be interlocked against another tag. The following tags on a device will also be considered for switching jobs and manual data entries:

Do not operate (check ONLY for local object) Do not close (check ONLY for local object) Do not open (check ONLY for local object) Ground (check also applicable for network group) Do not isolate (check also applicable for network group) Do not energize (check also applicable for network group)

5.5 Switch Order/Switching Job Management

Switching job management helps the operator prepare and have approved all switching actions on the distribution network, which in many utilities must conform to strict policies established for supply continuity and safety of field crews. Switching jobs are used to conduct and record all distribution network switching operations. In particular these are required to isolate safely an area of the network where work is planned or initiated. They also record the switching actions required to recover an area of the network after a fault.

Switching Job Management is realized using the general Job Management tool.

Job Management includes functions for preparation, review and approval of job specifications, recording of job instructions and carrying out remote plant operations using the SCADA control functions. The jobs specifications can be tested in the study database.

The work of producing and administrating switch jobs (work orders) is extensive, since outage and work requests originate from different parts of a utility (different departments or zones), where the requests can handle various types of work, ranging from maintenance of network parts to tree trimming and construction work.

The Network Manager Service Information System and Work Order Clearance functions (see section 9 for further description) enhance the functionality of Job Management tool, and offer the operational staff an efficient and powerful tool, making it possible to administer, create, simulate and approve work orders for work on the network in a swift and intuitive way via support of complex Work Order Clearance workflow and distribution of information between different parts of a utility.

5.6 Tagging

Tagging supports definition, handling and presentation of a number of tag types. The function includes multiple device tags with different priority. The tag status is displayed in operating diagrams as well as in dedicated lists. The significance of the different tag types is entirely defined by the customer.

Tagging is conveniently combined with Job Management, Interlocking and Safety Documents to enhance the operation and security of the power system, for instance, by blocking hazardous control actions.



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5.7 Safety Documents

The Safety Documents is a function, which enhances the security when performing control and maintenance actions in the power system. Using the Safety Document function, it is possible to specify

Checks of the status of power system objects to be performed before the attempted actions in the power system are commenced.

Blocking of hazardous control actions during the course of the attempted actions in the power system.

5.8 Temporary Network Changes (Jumpers)

The Temporary Network Changes function enables the user make temporary additions or deletions to the network as well as changes of state to circuit operating devices. This function is required to maintain an accurate state of the manually controlled portion of the distribution network as line crews report back changes made in the field. This function is provided through the creation and removal of temporary network elements.

The following types of changes are supported:

Connect two existing lines by adding a temporary line. Cut a line Add a temporary grounding device on an already existing line.The creation of any of the above temporary changes will be reflected in the distribution network model and in the coloring of the representations of the distribution operating layer diagrams.



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Figure 6 – Grounding-rod, line cut and temporary line applied to the real-time system



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6. Distribution Network AnalysisThe Distribution Network Analysis applications provide the operator with functions for:

real-time analysis of actual status of the distribution network balanced and unbalanced study of possible operating situations in order to facilitate the selection of control

actions and network operation

6.1 Load Calibration

Load in a distribution network unlike a transmission network is not generally measured at the load point thus a method to estimate all loads in the network taking into account all available data has to be devised to calibrate the loads according to measured values in other parts of the network. The Load Calibration application calculates individual feeder loads (real and reactive power) for use by the Operator Load Flow application for balanced and unbalanced networks.

The Load Calibration is performed separately for the balanced and unbalanced network part. Both network parts could be overlapping. Normally the transformer between HV- and MV network are considered in both calculations.

The Load Calibration component performs this function by distributing load measured at points (Metering Points) along the feeder.

The Load Calibration is divided into three steps. The first step is a "static load calibration". Input for this calculation is the static information, like load profiles, number of supplied customers and season. The results are "static" values for the active and reactive power consumption. The second step is a "topological load calibration". This function uses the results of the static load calibration for the power consumption, the latest measurement values and the current topology of the network to determine "dynamic" values for the active and reactive power consumption. For balanced networks these values are used as "pseudo measurements" together with the real measurements as input for a state estimation (third step). For unbalanced networks these values are used as load values together with the real measurements of loads and injections as input for an unbalanced load flow calculation. Additional iterations are performed by alternating unbalanced topological load calibration and unbalanced load flow calculation for the unbalanced network part.



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Figure 7 - Overview Load Calibration

The load calibration is applicable for radial and meshed networks. In practice, there are no restrictions in network topology, or network size.

In study mode the operator can choose any date and time to achieve the right load characteristics.

The load calibrations can be executed in three modes:

cyclic where the interval time is online adjustable, event driven in case of status changes in the network topology, manual by operator request.Every hour a complete unbalanced and balanced load calibration is executed, whereas in the meantime only the topological calibration and the state estimation respectively unbalanced load flow are executed.

6.2 Distribution /Operator Power Flow- Balanced

The purpose of the LF function is to provide the complete steady-state solution for a power system network for specified network conditions either in real-time or in study mode.

In real time mode the LF function refines the output from the load calibration function by taking the voltage dependency of the load into account.



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In study mode the LF function can be used to study possible operating situations in order to facilitate the selection of control actions and network operation. In particular it enables the operator to examine the voltage distribution (magnitudes and angles) and the resulting quantities such as branch flows, injections, currents and losses corresponding to a set of operating conditions. All calculated values are limit checked and limit violations are flagged.

Additional capabilities are provided to allow the operator to model and simulate the various controls and constraints in a more realistic way. These features include:

Network Groups - For a disconnected network the load flow problem is solved for all network groups, for which there is both generation and load within the group.

Voltage Control by Generator Voltage Control by TCUL Transformer Manual Voltage Control by Shunt Devices Voltage Dependent Load Processing Limit Checking - The resulting values of the LF calculations are limit checked.By using these features the operator can obtain a feasible solution for his load flow.

The LF function in study mode is operator-oriented allowing the operator to initialize his study either from the actual on-line system conditions, or from any one of the previously stored cases. Before executing LF calculations the operator has the possibility to modify these conditions (global or individual changes).

6.3 Distribution/Operator Load Flow - Unbalanced

The purpose of the ULF function is to provide the complete steady-state solution for a unbalanced power system network for specified network conditions either in real-time or in study mode.

In real time mode the ULF function refines the output from the unbalanced load calibration function by taking the voltage dependency of the load into account.

In study mode the ULF function can be used to study possible operating situations in order to facilitate the selection of control actions and network operation. In particular it enables the operator to examine the voltage distribution (magnitudes and angles) and the resulting quantities such as branch flows, injections, currents and losses corresponding to a set of operating conditions. All calculated values are limit checked and limit violations are flagged.

In order to consider unbalanced networks following interconnections are supported by this calculation:

Three-phase lines

Two-phase lines

Three-phase transformers (wye-delta, delta-delta, delta-wye)

Single-phase transformers

Three-phase generators

Three-phase loads (balanced and unbalanced)

Phase-phase loads



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Single-phase loads (connected to ground)

Jumpers

Line cut for three-phase, two-phase and single-phase lines

Cut of a single phase

Temporary lines (three-phase, single-phase and single phase between two different phases)

The function uses the iterative current injection method (gauss iterative method).

Additional capabilities are provided to allow the operator to model and simulate the various controls and constraints in a more realistic way. These features include:

Network Groups - For a disconnected network the load flow problem is solved for all network groups, for which there is both generation and load within the group.

Voltage Control by Generator Voltage Control by TCUL Transformer Manual Voltage Control by Shunt Devices Voltage Dependent Load Processing Limit Checking - The resulting values of the LF calculations are limit checked.By using these features the operator can obtain a feasible solution for his load flow.

The ULF function in study mode is operator-oriented allowing the operator to initialize his study either from the actual on-line system conditions, or from any one of the previously stored cases. Before executing LF calculations the operator has the possibility to modify these conditions (global or individual changes).

6.4 Ground Fault and Short Circuit Management

The Ground Fault Localization and Short Circuit Localization functions help the operator to deal with Ground faults and short circuits swiftly and safely. The region with the fault is identified and presented on the display. Thus the operator knows where the Ground fault or the short circuit is located and can act to eliminate the failure. With that the power system network is prevented from more damage and the interruption times, without supply of energy, are shorter for the consumer.

The protection system detects failures in the power system network. Ground fault and short circuit relays are kinds of protection relays. These relays indicate that a Ground fault or a short circuit has appeared; they do not mark the place of the short circuit or the Ground fault in the network, however.

Both Ground Fault Localization and Short Circuit Localization functions do not have to build up a separate topology as they utilize the same structures for the topology as the Dynamic Network Coloring function and therefore very fast response is achieved.

Ground Fault Location and Isolation (Localization) (only available if FLISR is not included)

For Ground Fault Localization, the Sequence-of-events function is required.

Short Circuit Location and Isolation (Localization) details (only available if FLISR is not included)



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The Short Circuit Localization follows the topology and checks for every line whether a short circuit current has flown over the line. The line after the last short circuit indication is the line with the fault.

If there is more than one faulty line (fault location), e.g. a short circuit in a mesh, only one message appears in the event list.

The Short Circuit Localization starts automatically if a breaker trip indication arrives.

The operator can see the line with the short circuit in the online displays. The line with the short circuit obtains a dedicated color and/or dedicated line-style (e.g. red flashing) on the display. The message in the event-list describes in a short form the results of the Short Circuit Localization. It includes the information about on which line the short circuit is located. The event list also includes a message if it is not possible to locate the short circuit. This can happen if the short circuit is in a mesh.

6.5 Fault Location, Isolation and System Restoration

The FLISR-function helps the operator during system disturbance by filtering the incoming system messages and supplying him with diagnosis information and recommendations for remedial actions.

The short circuit localization part of the FLISR-function helps the operator to deal with a short circuit swiftly and safely. The faulty region is narrowed down as much as possible so that the operator can take action to eliminate the failure.

The isolation and restoration part of the FLISR-function gives the operator a set of recommendations for remedial actions to help the operator to re-establish the power supply for as many customers as possible without wasting time.

The FLISR-function is designed as a background function doing its work with a minimum of operator interventions.

Figure 8 contains a block diagram, which shows the relationship between the different parts of the FLISR function.



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Figure 8 - Block diagram with relationship between the different parts of the FLISR function and other Network Manager components for combined Advanced Application and Trouble Call based Outage Management (see section 9).



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7. Service Information System and Work Order ClearanceIn the network many activities are carried-out for which outage and work requests are issued by different parts of a utility (different departments or zones). These requests include various types of work, ranging from maintenance of network parts to tree trimming and construction work as well as work required to recover an area of the network after a fault.

The Job Management tool already discussed provides operator with basic functions for preparation, review and approval of job specifications, recording of job instructions and carrying out remote plant operations using the SCADA control functions.

Since the work of producing and administrating switch jobs (work orders) is extensive, Network Manager includes further functions, which enhance the functionality of Job Management. These are Service Information System and Work Order Clearance functions, which offer the operational staff an efficient and powerful tool, making it possible to administer, create, simulate and approve work orders for work on the network in a swift and intuitive way via support of complex Work Order Clearance workflow and distribution of information between different parts of a utility.

7.1 Service Information System

The Service Information System is the main tool for recording and storing information relevant for operations within a utility. It comprises of the Service Diary, Message Generator and the Work Order Clearance. Service Information System information is stored using an Oracle database; the Network Manager solution Utility Data Warehousing (UDW) is the preferred choice for long time storage. Data can easily be accessed from external systems or exported using standard ODBC drivers or likewise.

Service Information System supports multiple connection, i.e. operators from different consoles can use the Service Information System simultaneously.

Service DiarySIS main application is the Service Diary, a tool used for displaying historical as well as ongoing and planned activities.

Operators can create new event records into the SD by using specific Excel based forms. All event records have a reference to an object.

It covers both automatic and manual recording of activities, where automatic recording is based on designated events in the SCADA system. The events are defined using the Data Engineering tool DE400.

The Service Diary is also used as the gateway to the Work Order Clearance system and the Message Generator in the network pictures.

Message GeneratorThe Message Generator is a tool for recording, storing and distribution of general and specific information, where both SCADA object connected and object independent information can be used.

The object independent part supports recording of general information in free text format. Such recording is usually information that needs to be available among operators, irrespective of the site.



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The message generator also supports alarming, integrated with the SCADA alarm list, and tagging of objects associated with a message. The Tagging function is used for this purpose and indicates an existing Message Generator message for an object in one-line displays.

Each record is treated independently, and stored with traceable information of where, when, and by whom it was created or last changed.

7.2 Work Order Clearance

The objectives of the Work Order Clearance tool are to facilitate the extensive work of producing and administrating switch orders. It offers the operational staff an efficient and powerful tool for creation, simulation and approval of switch orders for work on the network in a swift and intuitive way. Work Order Clearance supports the workflow in following steps:

1. Outage and Work RequestsOutage and work requests originate from different parts of a utility (different departments or zones), where the requests can handle various types of work. These outage and work requests can be issued using a separate system or can be a common Microsoft Word type of document. Network Manager Service Information System is used for distribution of outage and work requests.

2. Planning and CoordinationThe centralized or decentralized planning department(s) receives the outage and work requests. An external planning tool is usually used, where planning and coordination of work is done. After planning and coordination of outage and work requests, a work order request is issued using Network Manager Service Information System. This request contains necessary information, in the message itself or by attaching a document, to create a work order.

3. Work Order CreationA person with the correct authority receives the work order request and creates a work order using the Network Manager Work Order Clearance tool.The operator creates switching steps in the work order and adds text concerning measures around the switching work itself and information of administrative character. The work order has a separate text field used as input to the customer notification process and can have documents attached, e.g. a schematic diagrams.

4. Work Order Simulation, Approval, and DistributionA work order can be simulated. As the operator simulates the switching, the actions taken can be viewed in network diagrams. After successful simulation, the operator can approve the work order, which must be done before it can be executed. After approving, the work order is distributed to the persons concerned. Permits and Safety Documents are included.

5. Work Order Execution and ArchivingTo execute a work order the operator selects one operation step at a time and explicitly requests its execution. Simultaneously he can see, in the schematic, which objects are affected. For non-SCADA objects the execution only means that the database is updated to the new state. This is valid for both the HV and the MV network. The Outage Management function is informed about each step executed in the switch order, so that any outages caused are marked as planned. Work orders can be archived and old work orders can easily be retrieved and used as a base for new work orders.



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8. Trouble Call based Outage ManagementThe Network Manager Trouble Call based Outage Management is used to manage the distribution network outage and restoration process. It is tightly integrated to the DMS/SCADA network model that ensures the outage engine operation is fully synchronized with all real-time network changes whether SCADA or operator initiated. This feature is particularly important for systems with high penetration of FA. It helps a utility rapidly process trouble input, analyze outage causes, predict probable outages, efficiently dispatch field crews to reduce restoration time and provide information to the customer service representatives in the call center, all in order to improve customer satisfaction and safeguard workers and the public.

The Outage Management consists of three principal subsystems:

Trouble Call Management - manages incoming trouble calls, and consolidates outage information so the operator can inform customers about restoration etc

Outage Engine - supports outages and restoration activities including emergency switching, trouble crew management, and outage reporting. Based on the analysis of incoming trouble calls, it presents probable outages in the form of alarms and graphical indicators

Crew and Resource Management - tracks field crews and their associated work including crew types, assigned personnel, vehicle types, equipment and task times

8.1 Trouble Call Management

Trouble Call EntryCalls received from customers, non-customers (passers-by), and power monitoring units are registered. The utility users can use the Trouble Call Entry Form module to enter the calls, or use the utility’s existing Customer Information System (CIS) to enter them. In the latter method, the calls come to Network Manager via the Call Center through an Application Program Interface (API). These calls can also come through an auto-attendant telephone system or interactive voice response unit (VRU).

The calls and outages are presented to the operators in a full-graphics environment, so they can visualize the trouble areas on an operating diagram of the distribution network.

Feedback to CustomersThe trouble call and outage information entered is available to operators through the Trouble Call Entry Form module, and the Customer Service Representatives (CSR) in the call center, through the Call Center API. If the same customer calls again, the CSR will know that he or she has called before and will pass on the most up-to-date information on outage status and cause. If the customer calls for the first time but is in a known outage area, the outage can be indicated to the CSR with the status information for communication to the customer.

Network Manager provides the option to send outage information with any status updates to the VRU, which would then play the appropriate messages to customers calling to report an outage or obtain an update. The system can also send to the VRU, a list of customers to call back to verify service restoration and if the customers choose, to inform them of changes to the estimated time of restoration.

Customer Service Calls Application



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The Customer Service application offers Customer Service Representatives (CSRs) a convenient method to enter or review Trouble Calls and Service Call Requests. Even for those calls, entered using an external call entry system, or by a Voice Response Unit (VRU), the call information is available to Customer Service Calls Application. This application supports calls from both customers and non-customers and allows users to quickly enter, update or view the information related to customer telephone calls. Customers may be identified by name, address, or account number and detailed account information can be presented.

Call entry processes supports the outage related Trouble Reports and service work orders related Service Call Requests.

8.2 Outage Analysis

Network Manager uses an Outage Engine to analyze trouble reports and network connectivity changes to create and maintain an up-to-date list of the out-of-service transformers.

The Outage Engine processes line/device status and groups trouble reports that can be associated with the upstream piece of open equipment. The grouping of trouble reports is based on the current connectivity of the distribution circuit model, which accounts for: current switch status, temporary line cuts and jumpers, reported device status (e.g. SCADA controlled/monitored devices) and outages.

There are two possible states of an outage that are maintained by the Outage Engine: a probable or “inferred” outage and a “verified” outage (confirmed by the crew’s field report, SCADA report, or based on a crew’s action such as a manual switch operation).

When a verified outage device is restored to its closed status, the Outage Engine changes the status of all associated trouble reports (based on the current topology of the circuit) to “resolved”. Restored transformers are moved to a historical table of out-of-service transformers.

The Outages Engine maintains an up-to-date count of the number of out-of-service transformers connected to the open device (the outage) and determines the number of customers associated with this outage and the total amount of kVA of distribution transformer capacity disconnected. This information is automatically calculated for all verified and inferred outages.

Inferred OutagesThe Outage Engine analyzes trouble calls which are not associated with a known or verified outage and groups them into probable or “inferred” outages. During each run of the analysis, the Outage Engine reads all new trouble calls and all trouble calls previously grouped into probable outages (which are not yet assigned to verified outages). From this set of trouble calls, the Outage Engine traces the network to determine a new set of probable outage location. The Outage Engine creates new probable outages, moves previously inferred outages, and deletes previously inferred outages so there is an “inferred outage” at each location in the new set of probable locations.

Series Sequential Outage AnalysisThe Series Sequential Outage Analysis (SSQ) provides for the identification of multiple outages on a single circuit. SSQ is able to capture each outage that occurs on a circuit thus allowing for the system and the operator to recognize that one or more outages may affect a group of customers. Proper identification of these conditions is critical to generate



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efficient repair plans, including assessing partial restoration options. In addition, the use of SSQ can have a positive and immediate impact on the system reliability indices, while reducing the workload of the operators.

Grouping of CallsNetwork Manager periodically groups the calls into inferred outages and presents the inferred outages to the operator in the form of outage repair orders. The analysis period, typically once every 30 seconds, is configurable. If two hundred calls are likely caused by the same equipment outage, the operator will see only one outage ticket rather than 200. The inference from calls to outages is done automatically by analyzing the pattern of the calls along the network connectivity model as described above.

Calls that are not rolled up to an equipment outage are assumed to be individual customer service calls.

8.3 Crew and Resource Management

The operator assigns crews to each outage and tracks them through the restoration process. They can use Network Manager to prioritize the outages, choose the crews for the outages, and track the assignments and work status of the crews. They can also schedule resources and track the costs of repairs.

List of available crews within a specified geographic radius with their backlog and status are provided. This informs the operator of any crews that are already assigned to the same circuit.

Network Manager logs crew assignments for reporting purposes, including dispatch time, crew acceptance or rejection (and reason for rejection), en-route time, time of arrival, and time of completing the assignment or re-assignment.

Network Manager can also interface with a work management, field automation or mobile dispatch system so the operator will not have to enter the information manually.

Based on information received from field crews (e.g., via radio), the operator updates with regard to repair status, cause of outage, and the type of equipment failure if any. The status may include crew dispatched, crew arrived, cause located, repair done, etc., and the estimated time of arrival and repair.

Employee and Resource Creation and Crew AssemblyOperators may assign work to existing crews, call-out a crew on-call, or build a crew based on available resources (i.e. vehicles and personnel). Foreign crews can also be created and managed.

8.4 Outage Status Monitoring and Reporting

Calculation of Affected AreasNetwork Manager gets the network statuses from the operator’s data entry or from SCADA and field automation as described in the previous sections. The statuses include open and closed state of switching devices, fuse cutouts, etc., as well as temporary line changes, such as jumpers and line cuts (open bridge or double dead-end). Based on the new statuses, a dynamic, as-operated connectivity model is maintained, and the area affected by the status change is calculated. The affected area is presented to the operator graphically and translated into affected customers.



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As customers are restored, Network Manager can generate a call-back list and send it to the CIS and/or VRU. The list contains all customers who have registered calls on the system.

When the number of interrupted customers is reduced to zero, the system automatically declares the outage complete, archives the outage records and clears them from the system. The data will be available for historical reliability reporting as well as ad hoc queries.

Scheduled MaintenanceNetwork changes may also be planned, such as for scheduled equipment maintenance or new construction. Network Manager may help the operator plan outages by simulating switch orders in a case study file. Nevertheless, these scheduled changes are processed, when they are implemented, in the same way it processes other circuit changes. The outages are included in the outage statistics, except that they are categorized as planned or scheduled.

Feedback to CustomersThe trouble call and outage information entered by the operator is available to the customer service representatives in the call center, therefore feedback to customers can be given as described in Trouble Call Management function.

Outage Report GenerationNetwork Manager summarizes the outage status and other information (e.g., the number of calls, the number of affected customers, the number of restored customers, and the number of customers still out of service) for both periodic and on-line situation reports to the utility management. The reports can be company-wide, by district and region, by substation and circuit, by cause and equipment, or for an individual customer. Reliability indices such as SAIFI, SAIDI, CAIFI, and CAIDI can be calculated by area, substation or circuit.



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9. Data EngineeringThe data take-on is a major effort in the implementation of a distribution management system and once implemented the maintenance of the diagrams and data a mandatory task. The ultimate objective of the data engineering function is to create and maintain:

operating diagrams and other navigational display pictures

summary pictures and detailed schematics

a linked database with attribute information for all represented network elements and additional data for the tele-controlled (real-time) devices

links to other applications supported from the DMS.

In the majority of cases, due to the magnitude of data, the distribution network model will have been created as a corporate investment and reside in an external database, most commonly in the Geographic Information System (GIS) or Network Information System (NIS). This database is often termed the “as-built” or “persistent” database. It is the corporate facilities inventory and provides the business with the details of their network assets. In contrast the database resident in the DMS is the “as-operated” database, which reflects the real-time status of the “as-built” system with the possible addition of temporary changes made by the operators. There is a great need for coordinated data entry and maintenance procedures, as well as functions facilitating common use of the available data and information in the daily operation of the systems. Thus the GIS/NIS database can be used as an external master database and user works with maintenance and planning of distribution network and maintains distribution network data in the external database of GIS/NIS system. This database is then used both for initial creation of DMS database as well as for continuous regular update of DMS database in order to reflect changes in the distribution network to DMS system. Network Manager provides extensive facilities for incremental and total import of data from GIS/NIS systems.

Utilities without an existing corporate database suitable for preparing the import format can enter and maintain the data using the suite of data engineering and picture building tools. This approach is further referred to as the use of an internal master database.Network Manager supports also a combination of master databases. For example, data for the distribution part of the network can be entered/maintained with GIS/NIS and high voltage network data can be entered/maintained by the data-engineering tool. Still both types of data can be used in parallel in the same system.

The data engineering and maintenance processThe Network Manager Data Engineering tool (DE400) is an application for data entry of system data. The tool is used for both the process data entry (either manually or through data import from external systems e.g. GIS) and for the process data maintenance. The DE400 is using the relational database Oracle as a maintenance database (MDB) for off-line storage of the process description information. The DE 400 is an integrated graphical tools with deep copy and paste that speed the creation of system displays by allowing templates to be pasted and with only a name change of say a substation “parent” data requirements of all “child” elements even down to the RTU addressing are established. The DE 400 is a multi-user multi site application with rigorous version control capability.



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Figure 9 Typical HMI of the DE400 Date Engineering Tool

The Network Manager system uses Avanti database as a central real-time repository of power system data and Oracle for the optional UDW200 Historian and Outage Management database. When the data processing has been achieved in the maintenance database, the result is transferred to the runtime system. The Picture Editor (PED400) is used for creation and maintenance of picture displays or optimizing the displays created in the DE400 at time of data input.



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Figure 10 - The Data Engineering and Maintenance Process

9.1 External master database (GIS/NIS import)

The GIS/NIS systems provide details of the network assets and depending on the distribution network model implemented within the GIS – the NIS function - can normally export data describing:

Power system objects, e.g. switches, fuses, lines, etc.

Connectivity based on node numbers or names, connecting the objects.

Pictures with dynamic elements, referring to power system objects (note this is a highly customized interface and dependent on two applications).

Data importsThe Network Manager supports import of data (tables) describing power system objects from GIS/NIS systems. In the DE400 such objects are tagged such that GIS/NIS system is regarded as exclusive owner. An imported World map is automatically converted to the PED400 picture display format.

Some GIS/NIS systems can deliver well-organized increments when changing the master database. Others can only deliver total copies of the new database. The GIS import can handle both cases. When a total copy is imported, Network Manager will compare this with the master database and internally produce an increment for further processing. Regardless of how the increment is produced it is assumed that the resulting database will contain a consistent set of data i.e. imported graphics matches the topology. One increment, imported from GIS/NIS, is stored as one Change Set in DE400.

This same procedure can be used to accept incremental updates that must pass through the same validation process. Incremental update can be passed directly to the run time system and if accepted immediately update the database without the need to fail over from the back up server. The DE 400 can also be used to create a “version” to be used for updating at a specific date.



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Data entered via DE400 and PED400Tables imported from GIS can be complemented in DE400 and PED400 with properties like:

Extra picture elements in imported pictures, e.g. SCADA status points

RTU addressing

Functional control data

Tables maintained on the Network Manager side include DMS data such as:

Limit value sets for process values

New transformer types (as defined in Avanti)

Load profiles

The DE400 includes Picture generation function, which based on imported data generates the on-line pictures and thus avoids re-drawing the network diagrams.

Figure 11 – Use of GIS/NIS system as an external master database

Data security in DE400Imported tables are owned by GIS in the sense that only the GIS (and not DE400) is allowed to add and delete rows (objects) in these tables. Whole selected columns (properties) can be protected for updates from DE400 forms. Both the GIS and DE 400 can update some columns. If data is missing in GIS, data can be entered manually via DE 400 tool or automatically added by import.

Verification of the new databaseAfter loading a Change Set into DE400 full consistency and plausibility checking is performed. If the Change Set is disapproved in DE400 data has to be corrected in GIS and re-exported before it can be approved.



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Population of the Process Data BaseAfter verification of the new database in DE400 tool, the new database changes are introduced into the on-line system, where these changes are verified in runtime, approved or rejected with the old status restored (roll-back).

Two different ways of making updates are supported - Complete Update or Incremental Update. In addition, Network Manager offers two principal methods of on-line updates, one without and the other with switchover.

In DMS system where changes of network data could be very frequent, the possibility to minimize the number of switchovers is important. For that purpose the system supports a method to introduce changes directly in the on-line server. This method does not require any switchover, which might cause a disturbance to the on-line operation.

All objects affected by a data engineering change are automatically taken Out-of-service while the update is in progress and set In-service afterwards. Out-of service objects are not used by any online function; however, other objects not affected by the change are fully operational. After loading all on-line functions are informed about modified objects and can initiate all actions needed to bring in the new, changed or deleted objects into their structures.

The new database with modified objects can now be tested in true real-time environment. If the test is accepted the engineering change can be approved. A message is sent to the DE 400 (and possibly further to a GIS/NIS system) for merging the change set to the master database of the engineering environment.

In case of a negative test result, the engineering change may be rejected. In this case all the updates reversed by doing the same steps as when inserting the updates but in reverse order.

9.2 Internal master database (DE400)

The Data Engineering DE400 environment can be chosen as a master database.

The database creation can be done in several ways. The utility may want to import data as a one time exercise from a circuits file of equipment and connectivity or from existing control system to be replaced. The import often has to be supplemented by entry of new data as the scope of the new system in most cases increased. Existing SCADA, EMS and DMS can be imported to the DE400 by a very flexible data-mapping tool. Normally, existing topology definitions lack graphic representation and hence the topology definition is often redone using the graphical tool in DE400 and only the attributes are imported. This simplifies future maintenance of the network topology and ensures good quality of the data. There is a special mode where imported data can be connected to a new graphics topology without re-entering any attribute data.

The data can also be entered manually. Especially in such cases, a well-structured and easy-to-use entry is of utmost importance. The entered data in the network can be directly perceived through graphical symbols and colors. Topological connectivity is specified in a simple and intuitive way by graphically drawing the network. The same graphical definition can be used to generate the on-line pictures to avoid drawing the network diagrams twice.

Very big volumes of data characterize typical power system network models but often identical or similar structures are repeated. ABB has, therefore, put big emphasis on development of tools and procedures to ease mass entry of data. The functions “Deep Copy and Paste” enables the possibility to copy parts of the network, e.g. from a template or an existing station, to another networks place. The “deep copy” will include all attributes



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of the stations, e.g. included calculations, to the new station. The only manual action to include the new station after copy and paste is to give it the correct name and all other identities will automatically be created. Observe that this also includes the graphical characteristics of the objects.

Another, similar tool is the multi-change tool which enables the user to changes one or several parameters for as selection of objects. This is a very efficient tool for changing the behavior for a group of objects.
