EN IEC 61968-3:2018

SLOVENSKI STANDARD
01-oktober-2018
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SIST EN 61968-3:2004
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Application integration at electric utilities - System interfaces for distribution management
- Part 3: Interface for network operations
Integration von Anwendungen in Anlagen der Elektrizitätsversorgung -
Systemschnittstellen für Netzführung - Teil 3: Schnittstelle für Netzbetriebsarten
Intégration des applications dans les entreprises de distribution électrique - Système
d'interfaces pour la gestion de la distribution - Partie 3: Interface pour l'exploitation du
réseau
Ta slovenski standard je istoveten z: EN IEC 61968-3:2018
ICS:
29.240.30 Krmilna oprema za Control equipment for electric
elektroenergetske sisteme power systems
35.200 Vmesniška in povezovalna Interface and interconnection
oprema equipment
2003-01.Slovenski inštitut za standardizacijo. Razmnoževanje celote ali delov tega standarda ni dovoljeno.

EUROPEAN STANDARD EN IEC 61968-3

NORME EUROPÉENNE
EUROPÄISCHE NORM
May 2018
ICS 33.200 Supersedes EN 61968-3:2004
English Version
Application integration at electric utilities - System interfaces for
distribution management - Part 3: Interface for network
operations
(IEC 61968-3:2017)
Intégration d'applications pour les services électriques - Integration von Anwendungen in Anlagen der
Interfaces système pour la gestion de la distribution - Partie Elektrizitätsversorgung - Systemschnittstellen für
3: Interface pour l'exploitation du réseau Netzführung - Teil 3: Schnittstelle für Netzbetriebsarten
(IEC 61968-3:2017) (IEC 61968-3:2017)
This European Standard was approved by CENELEC on 2017-03-03. CENELEC members are bound to comply with the CEN/CENELEC
Internal Regulations which stipulate the conditions for giving this European Standard the status of a national standard without any alteration.
Up-to-date lists and bibliographical references concerning such national standards may be obtained on application to the CEN-CENELEC
Management Centre or to any CENELEC member.
This European Standard exists in three official versions (English, French, German). A version in any other language made by translation
under the responsibility of a CENELEC member into its own language and notified to the CEN-CENELEC Management Centre has the
same status as the official versions.
CENELEC members are the national electrotechnical committees of Austria, Belgium, Bulgaria, Croatia, Cyprus, the Czech Republic,
Denmark, Estonia, Finland, Former Yugoslav Republic of Macedonia, France, Germany, Greece, Hungary, Iceland, Ireland, Italy, Latvia,
Lithuania, Luxembourg, Malta, the Netherlands, Norway, Poland, Portugal, Romania, Serbia, Slovakia, Slovenia, Spain, Sweden,
Switzerland, Turkey and the United Kingdom.

European Committee for Electrotechnical Standardization
Comité Européen de Normalisation Electrotechnique
Europäisches Komitee für Elektrotechnische Normung
CEN-CENELEC Management Centre: Rue de la Science 23, B-1040 Brussels
© 2018 CENELEC All rights of exploitation in any form and by any means reserved worldwide for CENELEC Members.
Ref. No. EN IEC 61968-3:2018 E

European foreword
The text of document 57/1810/FDIS, future edition 2 of IEC 61968-3, prepared by IEC/TC 57 "Power
systems management and associated information exchange" was submitted to the IEC-CENELEC
parallel vote and approved by CENELEC as EN IEC 61968-3:2018.

The following dates are fixed:
(dop) 2018-11-18
• latest date by which the document has to be
implemented at national level by
publication of an identical national
standard or by endorsement
• latest date by which the national (dow) 2021-05-18
standards conflicting with the
document have to be withdrawn
This document supersedes EN 61968-3:2004.

Attention is drawn to the possibility that some of the elements of this document may be the subject of
patent rights. CENELEC shall not be held responsible for identifying any or all such patent rights.

This document has been prepared under a mandate given to CENELEC by the European Commission
and the European Free Trade Association.

Endorsement notice
The text of the International Standard IEC 61968-3:2017 was approved by CENELEC as a European
Standard without any modification.
In the official version, for Bibliography, the following notes have to be added for the standards indicated:

IEC 61968-4 NOTE Harmonized as EN 61968-4.
IEC 61968-6 NOTE Harmonized as EN 61968-6.
IEC 61968-8 NOTE Harmonized as EN 61968-8.
IEC 61968-9 NOTE Harmonized as EN 61968-9.
IEC 61968-11 NOTE Harmonized as EN 61968-11.
IEC 61968-13 NOTE Harmonized as EN 61968-13.
IEC 62361-100 NOTE Harmonized as EN 62361-100.

Annex ZA
(normative)
Normative references to international publications
with their corresponding European publications

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.
NOTE 1  Where an International Publication has been modified by common modifications, indicated by (mod), the relevant
EN/HD applies.
NOTE 2  Up-to-date information on the latest versions of the European Standards listed in this annex is available here:
www.cenelec.eu.
Publication Year Title EN/HD Year
IEC 61968-1 -  Application integration at electric utilities - EN 61968-1 -
System interfaces for distribution
management -- Part 1: Interface
architecture and general requirements
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 - EN 61968-100 -
System interfaces for distribution
management -- Part 100: Implementation
profiles
IEC 61970-301 -  Energy Management System Application EN 61970-301 -
Program Interface (EMS-API) - Part 301:
Common information model (CIM) base

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

IEC 61968-3:2017 © IEC 2017 – 3 –
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

IEC 61968-3:2017 © IEC 2017 – 5 –
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
1) The International Electrotechnical Commission (IEC) is a worldwide organization for standardization comprising
all national electrotechnical committees (IEC National Committees). The object of IEC is to promote
international co-operation on all questions concerning standardization in the electrical and electronic fields. To
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8) Attention is drawn to the Normative references cited in this publication. Use of the referenced publications is
indispensable for the correct application of this publication.
9) Attention is drawn to the possibility that some of the elements of this IEC Publication may be the subject of
patent rights. IEC shall not be held responsible for identifying any or all such patent rights.
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.
IEC 61968-3:2017 © IEC 2017 – 7 –
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
that it contains colours which are considered to be useful for the correct
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.

IEC 61968-3:2017 © IEC 2017 – 9 –
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

IEC 61968-3:2017 © IEC 2017 – 11 –
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

– 12 – IEC 61968-3:2017 © IEC 2017
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
IEC 61968-3:2017 © IEC 2017 – 13 –
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.
– 14 – IEC 61968-3:2017 © IEC 2017
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)
Inform
...