IEC 61968-9:2009

Application integration at electric utilities - System interfaces for distribution management - Part 9: Interfaces for meter reading and control

IEC 61968-9:2009(E) specifies the information content of a set of message types that can be used to support many of the business functions related to meter reading and control. Typical uses of the message types include meter reading, meter control, meter events, customer data synchronization and customer switching. Although intended primarily for electrical distribution networks, IEC 61968-9 can be used for other metering applications, including non-electrical metered quantities necessary to support gas and water networks.
This publication is of core relevance for Smart Grid.

General Information

• Status: Published
• Publication Date: 15-Sep-2009
• 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: 16-Oct-2013
• Completion Date: 26-Oct-2025

Relations

• Revised: IEC 61968-9:2013 - Application integration at electric utilities - System interfaces for distribution management - Part 9: Interfaces for meter reading and control
• Effective Date: 05-Sep-2023

Overview

IEC 61968-9:2009 - Application integration at electric utilities: System interfaces for distribution management - Part 9: Interfaces for meter reading and control - specifies the information content and message types used to integrate meter reading and meter control functions across utility systems. The standard defines reference and information models, message formats and XML schemas to support meter reading, meter control, meter events, customer data synchronization and customer switching. Although aimed at electrical distribution, IEC 61968-9 is applicable to other metered quantities (gas, water) and is of core relevance to Smart Grid and AMI (Advanced Metering Infrastructure) integration.

Key topics and requirements

• Message types and payloads: Detailed definitions for message families including End Device Events, Synchronization, Meter Readings, End Device Controls, Meter Service Requests, Metering System Events, Customer Switching and Payment Metering Service messages.
• Information models: UML-based reference and static information models describing metering system components (meters, load control devices, MDM, MAM, CIS, OMS, WM).
• Interface patterns: Support for common exchange patterns - request/reply, publish/subscribe and scheduled reads - with recommended message structures.
• Data schemas and formats: Normative XML Schemas for message payloads (Annex H) and guidance on quality codes, event and control enumerations (informative annexes).
• Synchronization and asset management: Procedures for system synchronization, subscription/publication examples, and handling of meter asset lifecycle (install, change-out, firmware upgrade).
• Interoperability: Mappings to external industry exchanges (e.g., ebIX) and conventions for maintaining relationships between objects to enable consistent cross-system operations.

Practical applications and users

IEC 61968-9 is intended for stakeholders who design, implement or operate metering and distribution integration solutions:

• Utility IT architects integrating Meter Data Management (MDM), Customer Information Systems (CIS), Outage Management (OMS) and Work Management (WM).
• AMI / smart meter vendors implementing device-side messaging and control interfaces.
• System integrators building middleware, ESBs or adapters to standardize meter-reading and control flows.
• Meter asset managers and operations teams managing firmware upgrades, device events, and remote connect/disconnect workflows.
• Regulators and program managers defining supplier switching and customer data exchange procedures.

Practical benefits include improved interoperability, reduced integration cost, predictable messaging behavior for meter reads and control actions, and a standardized foundation for Smart Grid services.

Related standards

• Part of the IEC 61968 family (application integration at electric utilities - system interfaces for distribution management).
• Includes Annex I mappings to industry exchange profiles (ebIX) and Annex H XML schemas for implementation.

Standards Content (Sample)

IEC 61968-9 ®
Edition 1.0 2009-09
INTERNATIONAL
STANDARD
colour
inside
Application integration at electric utilities – System interfaces for distribution
management –
Part 9: Interfaces for meter reading and control

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IEC 61968-9 ®
Edition 1.0 2009-09
INTERNATIONAL
STANDARD
colour
inside
Application integration at electric utilities – System interfaces for distribution

management –
Part 9: Interfaces for meter reading and control

INTERNATIONAL
ELECTROTECHNICAL
PRICE CODE
COMMISSION
XH
ICS 33.200 ISBN 978-2-88910-592-2

– 2 – 61968-9 © IEC:2009(E)
CONTENTS
FOREWORD.7
INTRODUCTION.9
1 Scope.11
2 Normative references .11
3 Terms, definitions and abbreviations .12
3.1 Terms and definitions .12
3.2 Abbreviations .13
4 Reference and information models .14
4.1 General approach to metering systems .14
4.2 Reference model .15
4.2.1 General .15
4.2.2 Metering system (MS) – Data collection.18
4.2.3 Metering system (MS) – Control and reconfiguration.19
4.2.4 Load control .19
4.2.5 Load management system (LMS).19
4.2.6 Outage management system (OMS) .19
4.2.7 Meter asset management (MAM) system .20
4.2.8 Meter data management (MDM) system.20
4.2.9 Customer information system (CIS) .20
4.2.10 Network operations (NO) .20
4.2.11 Meter maintenance (MM) .20
4.2.12 Planning .21
4.2.13 Work management (WM) .21
4.2.14 Point of sale (POS).21
4.2.15 Meter.21
4.2.16 Load control devices.21
4.3 Interface reference model.21
4.4 Meter reading and control functions and components .22
4.5 Static information model.23
4.5.1 General .23
4.5.2 Classes for meter reading and control .24
4.5.3 Classes related to meter reading and control.28
5 Meter reading and control message types .29
5.1 General .29
5.2 End device event messages .30
5.2.1 General .30
5.2.2 Applications.30
5.2.3 Message format.35
5.3 Synchronization between systems.37
5.3.1 General .37
5.3.2 Applications.37
5.3.3 Message format.41
5.4 Meter reading messages .43
5.4.1 General .43
5.4.2 Applications.43
5.4.3 Message format.50

61968-9 © IEC:2009(E) – 3 –
5.5 End device control messages .51
5.5.1 General .51
5.5.2 Applications.51
5.5.3 Message format.59
5.6 Meter service requests .60
5.6.1 General .60
5.6.2 Applications.60
5.6.3 Message format.64
5.7 Metering system events.65
5.7.1 General .65
5.7.2 Applications.66
5.7.3 Message formats .67
5.8 Customer switching .69
5.8.1 General .69
5.8.2 Message format.70
5.9 Payment metering service messages.70
5.9.1 General .70
5.9.2 MS information configuration .71
5.9.3 MS financial information .91
6 Document conventions .95
6.1 UML diagrams .95
6.2 Message definitions.95
6.2.1 Mandatory versus optional.95
Annex A (informative) Description of message type verbs.96
Annex B (informative) Recommended message structure.99
Annex C (informative) Recommended procedure for the generation of a ReadingType. 106
Annex D (informative) Recommended quality code enumerations .123
Annex E (informative) Recommended EndDeviceEvent category enumerations . 127
Annex F (informative) Recommended EndDeviceControl code enumerations . 149
Annex G (informative) Recommended procedure for maintaining relationships between
objects.151
Annex H (normative) XML Schemas for message payloads. 154
Annex I (informative) Mappings to ebIX.248
Annex J (informative) Request parameters .254

Figure 1 – Example of an end device with functions.16
Figure 2 – IEC 61968-9 reference model.17
Figure 3 – IEC 61968-9 reference model with customer information and billing system .18
Figure 4 – Outage detection, request/reply message exchange, example 1.31
Figure 5 – Outage detection, request/reply message exchange, example 2.31
Figure 6 – Outage detection, publish/subscribe exchange, example 1.32
Figure 7 – Outage detection, publish/subscribe exchange, example 2.33
Figure 8 – Meter health event exchange, example 1 .33
Figure 9 – Meter health event exchange, example 2 .34
Figure 10 – Power quality event exchange, example 1.35
Figure 11 – Power quality event exchange, example 2.35

– 4 – 61968-9 © IEC:2009(E)
Figure 12 – End device event message format.36
Figure 13 – Example of meter asset management subscriptions .37
Figure 14 – Example of meter asset management publications .38
Figure 15 – Example of WM to MAM exchange – test results .38
Figure 16 – Example of WM to MAM exchange – asset status update .39
Figure 17 – Example of reciprocal subscriptions (with MDM present) .40
Figure 18 – Example of synchronization exchanges .41
Figure 19 – End device asset message format.42
Figure 20 – Customer meter data set message format .42
Figure 21 – Example use of meter read schedule to create subscription .43
Figure 22 – Meter read schedule message format.44
Figure 23 – Meter readings message format .45
Figure 24 – Example manual meter reading exchange .47
Figure 25 – Example on-request meter read exchange .48
Figure 26 – HistoricalMeterData exchange.49
Figure 27 – Example billing inquiry message exchange .50
Figure 28 – Meter asset reading message format.51
Figure 29 – Example load control message exchange.52
Figure 30 – Example message exchange for LC unit installation .53
Figure 31 – Example message exchange for change of customer program (meter
reconfigured) .54
Figure 32 – Example message exchange for meter reconfiguration due to change of
customer program where there is no MDM.55
Figure 33 – Example message exchange for change of customer program with meter
changed out.56
Figure 34 – Example message exchange for meter connect/disconnect .57
Figure 35 – Example message exchange for remote connect/disconnect operation
directly between a CIS and MS .58
Figure 36 – Example message exchange for real-time price signal .59
Figure 37 – End device controls message format .60
Figure 38 – Example meter installation and removal message exchange .61
Figure 39 – Example end device event message exchange due to meter changeout.62
Figure 40 – Example message exchange due to CIS alarms .63
Figure 41 – Example message exchange when meter is changed out for recalibration .64
Figure 42 – Meter service requests message format .65
Figure 43 – Example of MeterSystemHealth message exchange.66
Figure 44 – Example of firmware upgrade message exchange .67
Figure 45 – Example of meter system event message format.68
Figure 46 – End device firmware message format.69
Figure 47 – Example of customer switching message exchange .70
Figure 48 – Message exchange for transferring supplier information.71
Figure 49 – Supplier configuration message format.72
Figure 50 – Message exchange for transferring customer information .73
Figure 51 – Customer configuration message .74

61968-9 © IEC:2009(E) – 5 –
Figure 52 – Message exchange for transferring customer agreement information .75
Figure 53 – Customer agreement configuration message.75
Figure 54 – Message exchange for transferring customer account information.76
Figure 55 – Customer account configuration message .77
Figure 56 – Message exchange for transferring auxiliary agreement information.78
Figure 57 – Auxiliary agreement configuration message format.79
Figure 58 – Message exchange for transferring pricing structures.80
Figure 59 – PricingStructureConfig message format .81
Figure 60 – Message exchange for transferring service category information.82
Figure 61 – ServiceCategoryConfig message format.82
Figure 62 – Message exchange for transferring service delivery point information .83
Figure 63 – ServiceDeliveryPointConfig message format .84
Figure 64 – Message exchange for transferring meter information .85
Figure 65 – Meter asset configuration message .86
Figure 66 – Message exchange for transferring service delivery point location
information.87
Figure 67 – SDPLocationConfig message format .88
Figure 68 – Message exchange for transferring service location information .89
Figure 69 – ServiceLocationConfig message format.90
Figure 70 – Message exchange for transferring receipt information.91
Figure 71 – ReceiptRecord message format .92
Figure 72 – Message exchange for transferring transaction information .93
Figure 73 – TransactionRecord message format .94
Figure B.1 – Recommended message message-format.99
Figure B.2 – Recommended.Header message format. 100
Figure B.3 – Recommended.RequestType message format . 100
Figure B.4 – Recommended.ReplyType message format . 101
Figure G.1 – Typical CIM naming object .151
Figure I.1 – ebIX XML schema .249
Figure I.2 – ebIX metered data as UML class diagram .251
Figure J.1 – Message request structure .254
Figure J.2 – GetMeterReadings .255
Figure J.3 – GetEndDeviceAssets.256
Figure J.4 – GetCustomerMeterDataSet.257

Table 1 – Business functions and abstract components .23
Table 2 – Classes for meter reading and control .25
Table 3 – Classes related to meter reading and control.29
Table A.1 – Commonly used verbs.96
Table B.1 – ReplyCode categories.101
Table B.2 – ReplyCode enumerations .102
Table C.1 – Time attribute enumerations .107
Table C.2 – Data qualifier enumerations .108

– 6 – 61968-9 © IEC:2009(E)
Table C.3 – Accumulation behaviour enumerations. 109
Table C.4 – Direction of flow enumerations .110
Table C.5 – Unit of measure enumerations .111
Table C.6 – Measurement categories.114
Table C.7 – MeasurementCategory enumerations.114
Table C.8 – Phase enumerations .116
Table C.9 – Metric multiplier enumerations .117
Table C.10 – Unit of measure enumerations .118
Table C.11 – Example ReadingTypes .121
Table D.1 – Example System IdentifiersValue .123
Table D.2 – Example quality code categories.124
Table D.3 – Example categorized codes .124
Table D.4 – Example quality codes .126
Table E.1 – Example EndDeviceEvent domain codes.127
Table E.2 – Example EndDeviceEvent domain part codes .128
Table E.3 – Example EndDeviceEvent type codes .129
Table E.4 – Example EndDeviceEvent indexes .129
Table E.5 – Example EndDeviceEvent codes .136
Table E.6 – Example EndDeviceEvent codes .148
Table F.1 – Comparison of example demand reset codes . 149
Table F.2 – Example EndDevice control codes .149
Table G.1 – Example meter relationships.153
Table I.3 – Meter reading: Mapping ebIX metered data to IEC MeterReadings .252

61968-9 © IEC:2009(E) – 7 –
INTERNATIONAL ELECTROTECHNICAL COMMISSION
______________
APPLICATION INTEGRATION AT ELECTRIC UTILITIES –
SYSTEM INTERFACES FOR DISTRIBUTION MANAGEMENT –

Part 9: Interfaces for meter reading and control

FOREWORD
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International Standard IEC 61968-9 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
57/1009/FDIS 57/1020/RVD
Full information on the voting for the approval of this standard can be found in the report on
voting indicated in the above table.
This publication has been drafted in accordance with the ISO/IEC Directives, Part 2.

– 8 – 61968-9 © IEC:2009(E)
A list of all parts in IEC 61968 series, under the general title: Application integration at electric
utilities – System interfaces for distribution management, can be found on the IEC website.
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the data related to the specific publication. At this date, the publication will be
• reconfirmed,
• withdrawn,
• replaced by a revised edition, or
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61968-9 © IEC:2009(E) – 9 –
INTRODUCTION
The purpose of this document is to define a standard for the integration of metering systems
(MS), which would include traditional (one or two-way) automated meter reading (AMR)
systems, with other systems and business functions within the scope of IEC 61968. The
scope of this standard is the exchange of information between a metering system and other
systems within the utility enterprise. The specific details of communication protocols those
systems employ are outside the scope of this standard. Instead, this standard will recognize
and model the general capabilities that can be potentially provided by advanced and/or legacy
meter infrastructures, including two-way communication capabilities such as load control,
dynamic pricing, outage detection, distributed energy resource (DER) control signals and on-
request read. In this way, this standard will not be impacted by the specification, development
and/or deployment of next generation meter infrastructures, 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 optimized for close, real-
time, synchronous connections and interactive request/reply or conversation communication
models. Therefore, these 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: System interfaces for
distribution management – Part 1: Interface architecture and general requirements.
.
– 10 – 61968-9 © IEC:2009(E)
This part of IEC 61968 contains the clauses listed below.
Document overview for IEC 61968-9
Clause/Annex Title Purpose
Scope The scope and purpose of the document are described
Normative references Documents that contain provisions which, through reference in
this text, constitute provisions of this International Standard
Terms, definitions and Provides terms, definitions and abbreviations
abbreviations
Reference and information Description of general approach to metering system,
models reference model, use cases, interface reference model, meter
reading and control functions and components, message type
terms and static information model
Meter reading and control Message types related to the exchange of information for
message types documents related to meter reading and control
Annex A
Description of message type Description of the verbs that are used for the message types
verbs
Annex B
Recommended message CIM extensions to support the recommended message
structure structure for meter reading and control
Annex C
Recommended procedure for Recommended technique for constructing, and offers sample
the generation of a enumerations for the ReadingTypeId textual name and mRID
ReadingType
Annex D
Recommended Quality code Recommends technique for constructing, and offers sample
enumerations enumerations for reading quality codes
Annex E
Recommended Recommends EndDeviceEvent alarm codes
EndDeviceEvent category
enumerations
Annex F
Recommended Describes recommended technique for leveraging
EndDeviceControl code EndDeviceEvent codes to create EndDeviceControl codes
enumerations
Annex G
Recommended procedure for To describe the use of the master resource identifier (mRID)
maintaining relationships
between objects
Annex H
XML schemas for message To provide xsd information for use by developers to create
payloads IEC 61968-9 messages
Annex I
Mappings to ebIX To provide mappings between IEC 61968-9 meter readings
and ebIX.
Annex J
Request parameters Describes the qualification of GET requests using request
parameters
61968-9 © IEC:2009(E) – 11 –
APPLICATION INTEGRATION AT ELECTRIC UTILITIES –
SYSTEM INTERFACES FOR DISTRIBUTION MANAGEMENT –

Part 9: Interfaces for meter reading and control

1 Scope
This document is Part 9 of the IEC 61968 standard and specifies the information content of a
set of message types that can be used to support many of the business functions related to
meter reading and control. Typical uses of the message types include meter reading, meter
control, meter events, customer data synchronization and customer switching. Although
intended primarily for electrical distribution networks, IEC 61968-9 can be used for other
metering applications, including non-electrical metered quantities necessary to support gas
and water networks.
The purpose of this document is to define a standard for the integration of metering systems
(MS), which includes traditional manual systems, and (one or two-way) automated meter
reading (AMR) systems, with other systems and business functions within the scope of
IEC 61968. The scope of this International Standard is the exchange of information between a
metering system and other systems within the utility enterprise. The specific details of
communication protocols those systems employ are outside the scope of this standard.
Instead, this standard will recognize and model the general capabilities that can be potentially
provided by advanced and/or legacy meter infrastructures, including two-way communication
capabilities such as load control, dynamic pricing, outage detection, distributed energy
resource (DER) control signals and on-request read. In this way, this standard will not be
impacted by the specification, development and/or deployment of next generation meter
infrastructures either through the use of standards or proprietary means.
The capabilities and information provided by a meter reading system are important for a
variety of purposes, including (but not limited to) interval data, time-based demand data, time-
based energy data (usage and production), outage management, service interruption, service
restoration, quality of service monitoring, distribution network analysis, distribution planning,
demand reduction, customer billing and work management. This standard also extends the
CIM (Common Information Model) to support the exchange of meter data.
2 Normative references
The following referenced documents are indispensable for the application 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 60050-300, International Electrotechnical Vocabulary – Electrical and electronic
measurements and measuring instruments – Part 311: General terms relating to
measurements – Part 312: General terms relating to electrical measurements – Part 313:
Types of electrical measuring instruments – Part 314: Specific terms according to the type of
instrument
IEC 61968-1, Application integration at electric utilities – System interfaces for distribution
management – Part 1: Interface architecture and general requirements
IEC 61968-2, Application integration at electric utilities – System interfaces for distribution
management – Part 2: Glossary
– 12 – 61968-9 © IEC:2009(E)
IEC 61968-3, Application integration at electric utilities – System interfaces for distribution
management – Part 3: Interface for network operations
IEC 61970-301, Energy management system application program interface (EMS-API) – Part
301: Common information model (CIM) base
IEC 62051-1, Electricity metering – Data exchange for meter reading, tariff and load control –
Glossary of terms – Part 1: Terms related to data exchange with metering equipment using
DLMS/COSEM
IEC 62055-31, Electricity metering – Payment systems – Part 31: Particular requirements –
Static payment meters for active energy (classes 1 and 2)
IEC 62056 (all parts), Electricity metering – Data exchange for meter reading, tariff and load
control
ISO 4217, Codes for the representation of currencies and funds
ISO 8601:2004, Data elements and interchange formats – Information interchange –
Representation of dates and times
ANSI C12.19, Utility Industry End Device Data Tables
3 Terms, definitions and abbreviations
3.1 Terms and definitions
For the purposes of this document, the terms and definitions given in IEC 60050-300,
IEC 61968-2, IEC 62051-1, IEC 62055-31 and the following apply.
Where there is a difference between the definitions in this document and those contained in
other referenced IEC documents, then those defined in IEC 61968-2 shall take precedence
over the others listed, and those defined in IEC 61968-9 shall take precedence over those
defined in IEC 61968-2.
3.1.1
customer program
classification scheme for the sale of energy to consumers according to a particular tariff
The program may specify the purpose, conditions on the time of use, the service voltage(s),
the volumes consumed, and/or other terms as a condition of the sale.
NOTE Utilities may promote particular programs to their industrial, commercial, agricultural, and residential
customers in an effort to encourage a particular behaviour, or to make them aware of their options.
3.1.2
end device
equipment located at the end of the communication system, usually on the customer
premises, which may perform functions such as metrology, connect/disconnect, load control,
demand response, or other functions, and may have power relay and/or communications
capability
This is represented within the CIM using the EndDeviceAsset class.
3.1.3
load control device
type of end device which can receive signals causing it to shed load for the purposes of
maintaining network reliability and/or commercial agreements

61968-9 © IEC:2009(E) – 13 –
3.1.4
meter
type of end device which performs metrology and supports the tariffing of the distribution
and/or transmission network
This is represented using the CIM MeterAsset class, which is a subclass of EndDeviceAsset.
NOTE A meter could be defined as a 61850 device with logical nodes.
3.1.5
meter changeout
process of replacing an existing meter with a new meter
NOTE The installer will customarily follow a work order which specifies a given location, and usually requires that
he or she capture readings from the old and new meters, and record the time and day in which the work was
performed.
3.1.6
payment meter
electricity meter with additional functionality that can be operated and controlled to allow the
flow of energy according to agreed payment modes
3.1.7
prepayment mode
payment mode in which automatic interruption occurs when available credit is exhausted
3.2 Abbreviations
AM asset management
AMR automated meter reading
AMI advanced metering infrastructure
CIM common information model
CIS customer information system
COSEM companion specification for energy metering
DLMS UA device language message specification user
association
DMS distribution management system
IDR interval data recorder
IEC International Electrotechnical Commission
LC load control
LMS load management system
MAM meter asset management
MDM meter data management
MM meter maintenance
MR meter reading
MS metering system
NO network operations
OMS outage management system
POS point of sale
RF radio frequency
– 14 – 61968-9 © IEC:2009(E)
VEE validating, editing, and estimating
WM work management
4 Reference and information models
4.1 General approach to metering systems
The spinning disk in an electromechanical meter generally serves as a pulse initiator to the
meter recorder module. In a similar fashion, solid-state meters may also employ a metrology
unit that generates pulses which represent a fraction of a kWh, and if more sophisticated, the
solid-state meter may have a meter recorder which is able to accumulate many different kinds
of information and store it for presentation to the meter communications module using a
message and table-driven protocol such as ANSI C12.19 or IEC 62056.
The most common metered data element is kWh, but many electricity meters can also capture
kW, kVAr, kVArh, and other similar billing quantities. Some meters can also capture pure
engineering quantities such as voltage, current, power factor, etc.
Some AMR systems attempt to add value to low-end meters by adding functionality that the
meter may lack. For low-end meters (e.g., energy only), it is common for an AMR meter
module to add the capability to perform demand metering, interval dat
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