IEC 61968-3:2017

Application integration at electric utilities - System interfaces for distribution management - Part 3: Interface for network operations

IEC 61968-3:2017 defines a Network Operations function which provides utilities the means to supervise main substation topology (breaker and switch state) and control equipment status. It also provides the means for handling network connectivity and loading conditions. Finally, it makes it possible for utilities to locate customer telephone complaints and supervise the location of field crews. IEC 61968-3 specifies the information content of a set of message payloads that can be used to support many of the business functions related to network operations. Typical uses of the message payloads defined in IEC 61968-3 include data acquisition by external systems, fault isolation, fault restoration, trouble management, maintenance of plant, and the commissioning of plant. This edition includes the following significant technical changes with respect to the previous edition: replacement of certain function names, addition of other function names.

Intégration d'applications pour les services électriques - Interfaces système pour la gestion de la distribution - Partie 3: Interface pour l'exploitation du réseau

L'IEC 61968-3:2017 définit une Fonction d'exploitation du réseau qui donne aux entreprises de distribution les moyens de surveiller la topologie de poste principale (état de disjoncteur et d’organe de coupure) et le statut d'équipement de commande. Elle fournit également les moyens pour gérer l’état de charge et de connectivité du réseau. Enfin, elle rend possible la localisation des plaintes téléphoniques des clients et la surveillance de la localisation des équipes de terrain. L'IEC 61968-3 spécifie le contenu d'informations d'un ensemble de charges utiles de messages qui peuvent être utilisées pour prendre en charge la plupart des fonctions métier liées à l'exploitation du réseau. Les utilisations classiques des charges utiles de messages définies dans l'IEC 61968-3 incluent l'acquisition de données par des systèmes externes, l'isolement du défaut, le traitement des pannes, la gestion des dysfonctionnements, la maintenance des installations et la mise en service des installations. Cette nouvelle édition inclut les modifications techniques majeures suivantes par rapport à l'édition précédente: remplacement des noms de certaines fonctions, ajout d'autres noms de fonctions.

General Information

• Status: Published
• Publication Date: 10-Apr-2017
• ICS: 29.035.20 - Plastics and rubber insulating materials
• ICS: 33.200 - Telecontrol. Telemetering
• Technical Committee: TC 57 - Power systems management and associated information exchange
• Drafting Committee: WG 14 - TC 57/WG 14
• Current Stage: DELPUB - Deleted Publication
• Start Date: 27-Apr-2021
• Completion Date: 29-Jun-2020

Relations

• Revises: IEC 61968-3:2004 - Application integration at electric utilities - System interfaces for distribution management - Part 3: Interface for network operations
• Effective Date: 05-Sep-2023
• Revised: IEC 61968-3:2021 - Application integration at electric utilities - System interfaces for distribution management - Part 3: Interface for network operations
• Effective Date: 05-Sep-2023

Overview

IEC 61968-3:2017 is an international standard published by the International Electrotechnical Commission (IEC) that specifies system interfaces for distribution management in electric utilities, specifically focusing on network operations. This standard defines the Network Operations function which enables electric utilities to effectively supervise main substation topology-including breaker and switch status-and control equipment conditions. It covers management of network connectivity and loading, facilitates locating customer telephone complaints, and oversees the positioning and activities of field crews.

The standard outlines message payload structures that support key business functions in network operations. These functions include data acquisition by external systems, fault isolation, fault restoration, trouble and outage management, plant maintenance, and plant commissioning. This edition (2017) introduces significant updates such as renaming certain functions and adding new functionality to enhance utility operations integration and efficiency.

Key Topics

IEC 61968-3:2017 provides a comprehensive framework focused on the following critical areas:

• Network Operations Functionality
  Facilitates supervising substation topology, breaker and switch states, and real-time equipment status.

• Message Payloads for Business Functions
  Defines structured data formats supporting many aspects of network management, including:

  • OperationsConfiguration (setup of operational parameters)
  • MeasurementsAndControls (monitoring and controlling devices)
  • TemporaryNetworkChanges (tracking short-term network alterations)
  • SwitchingPlan (planned switching activities)
  • OperationalTags (safety and operational tags)
  • TroubleTickets and TroubleOrders (handling faults and incidents)
  • Outage and OutageSchedule payloads (managing service interruptions)
  • Meter readings and EndDeviceEvents (supporting advanced metering infrastructure)

• Reference and Information Models
  Provides an interface reference model and static information models to standardize communication across utility systems.

• Use Cases and Workflows
  Real-world applications such as Fault Location, Isolation and Service Restoration (FLISR), planned maintenance outages, and crew coordination demonstrate practical implementation.

Applications

The IEC 61968-3:2017 standard is essential for utilities aiming to enhance the integration and automation of their network operations. Key applications include:

• Improved Network Reliability and Fault Handling
  Enables rapid fault isolation and restoration through standardized communication between distribution management systems (DMS), SCADA, and field crews.

• Operational Efficiency in Distribution Management
  Supports automation of switching plans and network topology updates, reducing manual effort and improving safety.

• Customer Service and Complaint Resolution
  Helps locate customer complaints related to network issues by linking telephone reports with network topology and crew locations.

• Asset and Crew Management
  Supervises field crews and equipment status, facilitating maintenance scheduling and incident response.

• Advanced Metering and Data Acquisition
  Integrates meter readings and device events, supporting demand response and outage verification.

By implementing IEC 61968-3, utilities modernize their distribution operations with standardized data models, improving interoperability and enabling smarter grid management.

Related Standards

IEC 61968-3 is part of the broader IEC 61968 series, which addresses application integration for electric utilities through standardized system interfaces:

• IEC 61968-1: Framework and general principles for application integration
  Sets the foundation for implementing the IEC 61968 series.

• IEC 61968-4: Interfaces for records and asset management
  Focuses on asset information workflows.

• IEC 61968-9: Interfaces for meter reading and control
  Covers advanced metering infrastructure (AMI) integration.

• IEC 61970 series (CIM - Common Information Model)
  Provides complementary standards for energy management system application protocols.

These standards collectively support seamless interoperability across electric utility systems, enabling end-to-end integration from network operations to customer service and asset management.

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Keywords: IEC 61968-3, electric utilities, distribution management, network operations, system interfaces, message payloads, fault isolation, outage management, switching plan, substation topology, utility integration, DMS, SCADA, operational tags, trouble tickets, IEC standards, application integration, smart grid.

Standards Content (Sample)

IEC 61968-3 ®
Edition 2.0 2017-04
INTERNATIONAL
STANDARD
NORME
INTERNATIONALE
colour
inside
Application integration at electric utilities – System interfaces for distribution
management –
Part 3: Interface for network operations

Intégration d'applications pour les services électriques – Interfaces système
pour la gestion de la distribution –
Partie 3: Interface pour l'exploitation du réseau

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IEC 61968-3 ®
Edition 2.0 2017-04
INTERNATIONAL
STANDARD
NORME
INTERNATIONALE
colour
inside
Application integration at electric utilities – System interfaces for distribution

management –
Part 3: Interface for network operations

Intégration d'applications pour les services électriques – Interfaces système

pour la gestion de la distribution –

Partie 3: Interface pour l'exploitation du réseau

INTERNATIONAL
ELECTROTECHNICAL
COMMISSION
COMMISSION
ELECTROTECHNIQUE
INTERNATIONALE
ICS 33.200 ISBN 978-2-8322-4084-7

– 2 – IEC 61968-3:2017 © IEC 2017
CONTENTS
FOREWORD . 6
INTRODUCTION . 8
1 Scope . 9
2 Normative references . 10
3 Terms, definitions and abbreviated terms . 11
3.1 Terms and definitions . 11
3.2 Abbreviated terms . 11
4 Reference and Information Models . 11
4.1 General approach to network operations . 11
4.2 Reference Model . 12
4.3 Interface Reference Model . 13
4.4 Network operations functions and components . 13
4.5 Static Information Model . 15
4.5.1 General . 15
4.5.2 Classes related to network operations . 15
5 Network operations message payloads . 15
5.1 General . 15
5.2 OperationsConfiguration payload . 16
5.2.1 General . 16
5.2.2 Message payload . 16
5.3 MeasurementsAndControls payload . 17
5.3.1 General . 17
5.3.2 Measurement . 17
5.3.3 Control . 18
5.3.4 Message payload . 18
5.4 TemporaryNetworkChanges payload . 21
5.4.1 General . 21
5.4.2 Message payloads . 22
5.5 SwitchingPlan payload . 27
5.5.1 General . 27
5.5.2 Message payload . 28
5.6 OperationalTags payload . 36
5.6.1 General . 36
5.6.2 Message payload . 37
5.7 TroubleTicket payload. 38
5.8 Incident payload . 39
5.8.1 General . 39
5.8.2 Message payload . 41
5.9 Outage payload . 42
5.9.1 General . 42
5.9.2 Message payload . 44
5.10 Metering message payloads . 45
5.10.1 EndDeviceEvent . 45
5.10.2 MeterReading . 45

5.11 Work message payloads . 46
5.11.1 WorkOrder . 46
5.12 SwitchingOrder . 47
5.12.1 General . 47
5.12.2 Message payload . 48
5.13 TroubleOrder . 49
5.13.1 General . 49
5.13.2 Message payload . 50
5.14 OutageSchedule . 51
5.14.1 General . 51
5.14.2 Message payload . 52
6 Document Conventions . 55
6.1 UML diagrams. 55
6.2 Message payload definitions . 55
6.2.1 General . 55
6.2.2 Mandatory versus Optional . 55
6.3 Synchronous versus Asynchronous Messages . 55
6.4 Message exchanges . 55
Annex A (informative) Use Cases . 56
A.1 General . 56
A.2 FLISR . 56
A.2.1 Overview . 56
A.2.2 FLISR for SCADA-detected outage, SCADA switching . 56
A.2.3 FLISR for trouble call and AMI outage, crew switching . 58
A.3 Planned outage . 62
A.3.1 Planned outage for maintenance – Manual process . 62
A.3.2 Planned outage for maintenance – Crew switching . 63
Annex B (normative) XML Schemas for message payloads . 68
B.1 General . 68
B.2 Incidents message payload . 68
B.3 MeasurementsAndControls message payload. 75
B.4 OperationalTags message payload . 82
B.5 OperationsConfig message payload . 85
B.6 OutagesAndFaults message payload . 87
B.7 OutageSchedules message payload . 96
B.8 SwitchingOrders message payload . 117
B.9 SwitchingPlans message payload . 123
B.10 TemporaryNetworkChanges message payload . 140
B.11 TroubleOrders message payload . 150
Bibliography . 160

Figure 1 – IEC 61968-3 Scope . 10
Figure 2 – IEC 61968-3 Reference Model . 12
Figure 3 – OperationsConfiguration message payload . 16
Figure 4 – MeasurementsAndControls . 17

– 4 – IEC 61968-3:2017 © IEC 2017
Figure 5 – MeasurementsAndControls message payload . 19
Figure 6 – MeasurementsAndControls message payload, AnalogValue detail . 20
Figure 7 – MeasurementsAndControls message payload, Setpoint
(AnalogControl) detail . 21
Figure 8 – Temporary Network Changes . 22
Figure 9 – TemporaryNetworkChanges message payload . 22
Figure 10 – TemporaryNetworkChanges message payload, Clamp detail . 23
Figure 11 – TemporaryNetworkChanges message payload, Cut detail . 24
Figure 12 – TemporaryNetworkChanges message payload, EnergySource
Details . 25
Figure 13 – TemporaryNetworkChanges message payload, Ground details . 26
Figure 14 – TemporaryNetworkChanges message payload, Jumper Details. 27
Figure 15 – Switching Plan . 28
Figure 16 – SwitchingPlans message payload . 29
Figure 17 – SwitchingPlans message payload, SafetyDocument detail . 30
Figure 18 – SwitchingPlan message payload, ClearanceAction detail . 31
Figure 19 – SwitchingPlan message payload, GenericAction detail . 32
Figure 20 – SwitchingPlan message payload, EnergySourceAction detail . 32
Figure 21 – SwitchingPlan message payload, CutAction detail . 33
Figure 22 – SwitchingPlan message payload, GroundAction detail . 34
Figure 23 – SwitchingPlan message payload, JumperAction detail . 34
Figure 24 – SwitchingPlan message payload, SwitchingAction detail . 35
Figure 25 – SwitchingPlan message payload, TagAction detail . 36
Figure 26 – Tags . 37
Figure 27 – OperationalTags message payload . 38
Figure 28 – Trouble Ticket . 39
Figure 29 – Incident . 40
Figure 30 – Incident message payload . 41
Figure 31 – Outage . 42
Figure 32 – OutagesAndFaults message payload . 44
Figure 33 – End Device Event . 45
Figure 34 – Meter Reading. 46
Figure 35 – Work Order . 47
Figure 36 – Switching Order . 48
Figure 37 – SwitchingOrder message payload . 49
Figure 38 – Trouble Order . 50
Figure 39 – TroubleOrder message payload . 51
Figure 40 – Outage Schedule . 52
Figure 41 – OutageSchedule message payload . 53

Figure 42 – OutageSchedule message payload, PlannedOutages detail . 54
Figure A.1 – FLISR for SCADA-Detected Outage, SCADA Switching . 57
Figure A.2 – FLISR for trouble call and AMI outage, crew switching . 60
Figure A.3 – Planned outage for maintenance – Manual process . 63
Figure A.4 – Planned outage for maintenance, crew switching . 65

Table 1 – Business Functions and Abstract Components . 14
Table 2 – Interpretation of Network Operations Business Functions . 15
Table 3 – Classes related to network operations . 15
Table A.1 – Message Flow for FLISR SCADA-Detected Outage, SCADA Switching . 58
Table A.2 – Message flows for FLISR for trouble call and AMI outage, crew switching . 61
Table A.3 – Message flows for planned outage for maintenance, crew switching . 66

– 6 – IEC 61968-3:2017 © IEC 2017
INTERNATIONAL ELECTROTECHNICAL COMMISSION
____________
APPLICATION INTEGRATION AT ELECTRIC UTILITIES –
SYSTEM INTERFACES FOR DISTRIBUTION MANAGEMENT –

Part 3: Interface for network operations

FOREWORD
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International Standard IEC 61968-3 has been prepared by IEC technical committee 57: Power
systems management and associated information exchange.
The text of this standard is based on the following documents:
FDIS Report on voting
57/1810/FDIS 57/1841/RVD
Full information on the voting for the approval of this International Standard can be found in
the report on voting indicated in the above table.
This document has been drafted in accordance with the ISO/IEC Directives, Part 2.
This second edition cancels and replaces the first edition published in 2004. It constitutes a
technical revision.
This edition includes the following significant technical changes with respect to the previous
edition:
a) Replaced Measurement list with Measurement and Controls.
b) Replaced OperationalRestriction with Tag.
c) Replaced OutageRecord with Outage.
d) Replaced SafetyDocument with ClearanceDocument.
e) Replaced SwitchingSchedule with SwitchingOrder.
f) Added SwitchingPlan.
g) Added Temporary Network Change.
h) Added TroubleTicket.
i) Added Incident.
j) Added TroubleOrder.
k) Added use cases and sequence diagrams.
In this standard, the following print types are used:
– tokens: in arial black type
A list of all parts of the IEC 61968 series, under the general title: Application integration at
electric utilities – System interfaces for distribution management can be found on the IEC
website.
The committee has decided that the contents of this document will remain unchanged until the
stability date indicated on the IEC website under "http://webstore.iec.ch" in the data related to
the specific document. At this date, the document will be
• reconfirmed,
• withdrawn,
• replaced by a revised edition, or
• amended.
IMPORTANT – The 'colour inside' logo on the cover page of this publication indicates
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understanding of its contents. Users should therefore print this document using a
colour printer.
– 8 – IEC 61968-3:2017 © IEC 2017
INTRODUCTION
The purpose of this part of IEC 61968 is to define a standard for the integration of network
operations systems with each other and other systems and business functions within the
scope of IEC 61968. The specific details of communication protocols those systems employ
are outside the scope of this part of IEC 61968. Instead, this part of IEC 61968 will recognize
and model the general capabilities that can be potentially provided by network operations
systems. In this way, this part of IEC 61968 will not be impacted by the specification,
development and/or deployment of next generation network operations systems, either
through the use of standards or proprietary means.
The IEC 61968 series of standards is intended to facilitate inter-application integration as
opposed to intra-application integration. Intra-application integration is aimed at programs in
the same application system, usually communicating with each other using middleware that is
embedded in their underlying runtime environment, and tends to be optimised for close, real-
time, synchronous connections and interactive request/reply or conversation communication
models. Therefore, these inter-application interface standards are relevant to loosely coupled
applications with more heterogeneity in languages, operating systems, protocols and
management tools. This series of standards is intended to support applications that need to
exchange data every few seconds, minutes, or hours rather than waiting for a nightly batch
run. This series of standards, which are intended to be implemented with middleware services
that exchange messages among applications, will complement, not replace utility data
warehouses, database gateways, and operational stores.
As used in IEC 61968, a distribution management system (DMS) consists of various
distributed application components for the utility to manage electrical distribution networks.
These capabilities include monitoring and control of equipment for power delivery,
management processes to ensure system reliability, voltage management, demand-side
management, outage management, work management, automated mapping and facilities
management. Standard interfaces are defined for each class of applications identified in the
interface reference model (IRM), which is described in IEC 61968-1.

APPLICATION INTEGRATION AT ELECTRIC UTILITIES –
SYSTEM INTERFACES FOR DISTRIBUTION MANAGEMENT –

Part 3: Interface for network operations

1 Scope
Per the IEC 61968 Interface Reference Model, the Network Operations function defined in this
part of IEC 61968 provides utilities the means to supervise main substation topology (breaker
and switch state) and control equipment status. It also provides the means for handling
network connectivity and loading conditions. Finally, it makes it possible for utilities to locate
customer telephone complaints and supervise the location of field crews.
IEC 61968-3 specifies the information content of a set of message payloads that can be used
to support many of the business functions related to network operations. Typical uses of the
message payloads defined in IEC 61968-3 include data acquisition by external systems, fault
isolation, fault restoration, trouble management, maintenance of plant, and the commissioning
of plant.
The scope diagram shown in Figure 1 illustrates the possibility of implementing IEC 61968-3
functionality as either a single integrated advanced distribution management system or as a
set of separate functions – OMS, DMS and SCADA. Utilities may chose to buy these systems
from different vendors and integrate them using the IEC 61968-3 messages. Alternatively, a
single vendor could provide two or all of these components as a single integrated system. In
the case of more than one system being provided by the same vendor, the vendor may chose
to use either extensions of the IEC 61968-messages or a proprietary integration mechanism
to provide enhanced functionality over and above what is required/supported by the
IEC 61968-3 specification.
An additional part of IEC 61968 will document integration scenarios or use cases, which are
informative examples showing typical ways of using the message payloads defined in this
document as well as message payloads to be defined in other parts of the IEC 61968 series.

– 10 – IEC 61968-3:2017 © IEC 2017

EC
Figure 1 – IEC 61968-3 Scope
2 Normative references
The following documents are referred to in the text in such a way that some or all of their
content constitutes requirements of this document. For dated references, only the edition
cited applies. For undated references, the latest edition of the referenced document (including
any amendments) applies.
IEC 61968-1, Application integration at electric utilities – System interfaces for distribution
management – Part 1: Interface architecture and general recommendations
IEC TS 61968-2, Application integration at electric utilities – System interfaces for distribution
management – Part 2: Glossary
IEC 61968-100, Application integration at electric utilities – System interfaces for distribution
management – Part 100: Implementation profiles
IEC 61970-301, Energy management system application program interface (EMS-API) –
Part 301: Common information model (CIM) base

3 Terms, definitions and abbreviated terms
3.1 Terms and definitions
No terms and definitions are listed in this document.
ISO and IEC maintain terminological databases for use in standardization at the following
addresses:
• IEC Electropedia: available at http://www.electropedia.org/
• ISO Online browsing platform: available at http://www.iso.org/obp
3.2 Abbreviated terms
For the purposes of this document, the abbreviations given in IEC 61968-2 as well as the
following apply.
NOTE Refer to International Electrotechnical Vocabulary, IEC 60050, for general glossary definitions.
FLISR Fault Location, Isolation and Service Restoration
WMS Work Management System
4 Reference and Information Models
4.1 General approach to network operations
Traditionally there have been two types of systems to manage distribution operations:
Distribution Management Systems (DMS) and Outage Management Systems (OMS). Often a
DMS has been delivered as an extension to a SCADA system, but some DMS can be
delivered as a standalone set of distribution applications with no SCADA.
Outage Management Systems are used extensively in many parts of the world (typically with
large service territories and a large amount of primary overhead conductor) to manage their
distribution systems. Such distribution systems are typically configured radially and cover
large distances. For this reason it has been historically expensive to monitor the status of the
distribution system, particularly outside of the substation. In more dense populations the cost
of telemetry and automation is lower, and can be justified on a cost per customer basis.
Thus often the only way that a distribution utility knows that there is a problem with the
system is when a customer calls to report an outage. The utility then collects a set of outage
calls, and from the pattern of calls received, determines the likely location and cause of the
outage. A crew is then sent to the location of the outage to investigate further and affect
repairs.
Distribution management systems have their roots in transmission SCADA systems. As
automation has moved downwards and into distribution substations, there has been an
increasing need to provide functionality for distribution applications. Distribution management
systems originated as either extensions to the existing transmission SCADA, by adding
additional points to cover the feeder breakers, or by adding a standalone distribution SCADA
system. Both types of system usually have RTUs, communication front-ends, alarm systems
and displays.
What characterizes these systems as distribution management systems are the addition of
functions such as the ability to add temporary devices, such as line cuts and jumper lines.
Such temporary devices are uncommon in transmission systems, but are very common in
distribution systems. Since many distribution systems are operated in a radial configuration,
it is often necessary to operate feeder tie switches to reconfigure feeders, either to restore
outages or to adjust to different loading situations. This dictates a need for the ability to
dynamically color lines according to which direction they are being energized from and also

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for the ability to color lines according to whether they are energized or not. In addition, in
certain parts of the world, such systems can be unbalanced, meaning that each electrical
phase is operated independently. Another characteristic of a distribution system is that
change is the norm. New residential construction and routine maintenance means that the
distribution network model changes frequently. It is not uncommon for 10 000 or even 100 000
changes to occur to a distribution system in a single week.
The thing that both the DMS and OMS have in common is the need for an as operated near
real-time network model. Thus this part of IEC 61968 includes the ability to exchange
distribution network models between two such systems and to keep them synchronized.
Increasingly, vendors are beginning to realize that this integration is non-trivial to implement
and maintain, are therefore offering integrated DMS/OMS, and even integrated
DMS/OMS/SCADA systems in order to provide reduced total cost of ownership and consistent
views of the real-time distribution network. The term ADMS (Advanced Distribution
Management System) has been coined to describe such systems.
4.2 Reference Model
Figure 2 serves as reference models and provide examples of the logical components and
data flows related to this International Standard. Clause 3 provides references to terms that
are defined by the CIM.
The diagram in Figure 2 describes the flows between the components in the reference model.
IEC
Figure 2 – IEC 61968-3 Reference Model
The reference architecture reflects five main logical components (potentially realized as
systems or subsystems) related to network operations:
IEC 61968-9, Meter Reading & Control, for associating outage events and meter pings with
operations
IEC 61968-8, Customer Operations for trouble call management associated with outages
IEC 61968-6, Maintenance & Construction for work orders required for trouble and switching
IEC 61968-5, Operational Planning for switching plan generation for both planned and
unplanned work
4.3 Interface Reference Model
It is not the intention of this standard to define the applications and systems that vendors
should produce. It is expected that a concrete (physical) application will provide the
functionality of one or more abstract (logical) components as listed in this standard. These
abstract components are grouped by the business functions of the Interface Reference Model.
In this standard, the term abstract component is used to refer to that portion of a software
system that supports one or more of the interfaces defined in this part of IEC 61968 through
IEC 61968-9. It does not necessarily mean that compliant software is delivered neither as
separate modules nor as a single system.
IEC 61968-1 describes infrastructure services common to all abstract components while
IEC 61968-3 through IEC 61968-9 define the details of the information exchanged for specific
types of abstract component.
IEC 61968 defines that:
• An inter-application infrastructure is compliant if it supplies services defined in Part 1 to
support at least two applications with interfaces compliant to sections of Parts 3 to 9.
• An application interface is compliant if it supports the interface standards defined in Parts
3 to 9 for the relevant abstract components defined in the Interface Reference Model.
• An application is only required to support interface standards of the applicable
components listed under abstract components. An application is not required to support
interfaces required by other abstract components of the same business sub-function or
within the same business function. While this standard primarily defines information
exchanged among components in different business functions, it will occasionally also
define information exchanged among components within a single business function when
a strong market need for this capability has been realised.
4.4 Network operations functions and components
It should be noted that the message payloads defined in this document, IEC 61968-3,
Interfaces for Network Operations, may be sent or received by any type of component within a
distribution management system (DMS) system.
Table 1 shows these functions and typical abstract components that are expected to be
producers of information for these message payloads. This is not intended to be an
exhaustive list of functions and abstract components, rather they are examples. Typical
consumers of the information include, but are not restricted to, the other components as listed
in IEC 61968-1.
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Table 1 – Business Functions and Abstract Components
Business Functions Business Sub-Functions Abstract Components
Network Operations (NO) Network Operation Monitoring Substation state supervision
(NMON)
Network state supervision
Switching action supervision
Switching pinning action supervision
Process and network data
management
Operation data management
Regulation step supervision
Alarm supervision
Operation and event logs
Weather monitoring (lightning
detection)
Network Control (CTL) User access control
Automatic controls
Assisted control
Safety document management
Safety checking and interlocks
Major incident coordination
Fault Management (FLT) Trouble call handling
Protective relays analysis
Fault location
Supply restoration assessment
Customer incident information usage
Distribution circuit energization
supervision
Operation Feedback Analysis (OFA) Mal-operation analysis
Network fault analysis
Quality index analysis
Device operation history
Post-disturbance review
Operation Statistics and Reporting Maintenance information
(OST)
Information for planning
Information for management control
Network Calculations Load estimation
real-time (CLC) Energy trading analysis
Load flow/voltage profile
Fault current analysis
Adaptive relay settings
Dispatcher training (TRN) SCADA simulation

The use case sequence diagrams presented in this document assume a simplified
interpretation of the business functions listed in Table 1. This allowed for easier mapping of
business functions to systems familiar to the participated vendors.

Table 2 shows the interpretation of the business functions defined in Table 1 as it relates to
61968-3 use cases. These interpretations are used to assist the reader understand of the use
cases.
Table 2 – Interpretation of Network Operations Business Functions
Business Function IRM Description 61968-3 Use Case Interpretation
NO-NMON Network Operation Distribution Management System (DMS) as used in
Monitoring the control room for network operations management
NO-CTL Network Control SCADA as used for network monitoring and control
NO-FTL Fault Management Outage Management System (OMS)

4.5 Static Information Model
4.5.1 General
The information model relevant to network operation
...