PE ELECTRIC POWER INDUSTRY OF SERBIA
Updated by Deepview
FUNCTIONAL REQUIREMENTS AND
TECHNICAL SPECIFICATIONS OF
AMI/MDM SYSTEM
Version 3.0
April 2014
Updated by Deepview, Version 3.0, April 2014
TABLE OF CONTENTS
ABBREVIATIONS ............................................................................................................................. 9
APPLIED STANDARDS ................................................................................................................... 10
FUNCTIONAL REQUIREMENTS AND TECHNICAL SPECIFICATIONS OF SYSTEM ARCHITECTURE12
1.
HIGH LEVEL ARCHITECTURE .......................................................................................... 13
FUNCTIONAL REQUIREMENTS AND TECHNICAL SPECIFICATIONS OF AMI SYSTEM ................ 17
1.
FUNCTIONAL REQUIREMENTS FOR AMM CENTRE ....................................................... 18
1.1.
DESCRIPTION AND GENERAL REQUIREMENTS FOR AMM CENTRE IN AMI CONTEXT .. 18
2.
AMM CENTRE FUNCTIONS ............................................................................................ 19
2.1
ADMINISTRATION FUNCTIONS...................................................................................... 19
2.2
AMM CENTRE DATA COLLECTION/READING AND MEMORISING FUNCTIONS ............ 23
2.3
REPORTING FUNCTIONS OF AMM CENTRE ................................................................... 24
2.4
DATA AND INFORMATION EXCHANGE FUNCTIONS WITH MDM SYSTEM AND OTHER
ISS OF ELECTRIC UTILITY ................................................................................................ 26
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR LOW VOLTAGE
CONCENTRATOR ................................................................................................... 28
1.
TECHNICAL CHARACTERISTICS OF LOW VOLTAGE CONCENTRATOR ............................ 29
1.1.
SUPPLY:.......................................................................................................................... 29
1.2.
MOUNTING:................................................................................................................... 29
1.3.
OPERATION TEMPERATURE RANGE:............................................................................. 29
1.4.
MAXIMUM OPERATION HUMIDITY:.............................................................................. 29
1.5.
ANTICIPATED OPERATION LIFE: .................................................................................... 29
1.6.
MAXIMUM HOUSING DIMENSIONS (WХLХH):.............................................................. 29
1.7.
NUMBER OF SUPPORTED METERS (CAPACITY):............................................................ 29
1.8.
STORAGE CAPACITY:...................................................................................................... 29
1.9.
COMMUNICATION PORTS (MINIMUM): ....................................................................... 29
1.10.
OTHER PORTS (OPTIONAL): ........................................................................................... 29
1.11.
HARDWARE MONITORING: ........................................................................................... 30
1.12.
REAL TIME CLOCK .......................................................................................................... 30
1.13.
PROTECTION AGAINST DUST AND WATER: .................................................................. 30
1.14.
OPERATING SYSTEM: ..................................................................................................... 30
2.
CONCENTRATOR ROLE AND FUNCTIONS ...................................................................... 30
2.1.
CONCENTRATOR ROLE .................................................................................................. 30
2.2.
GENERAL DESCRIPTION OF CONCENTRATOR FUNCTIONS ........................................... 31
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR AMM
GATEWAY/ROUTER ............................................................................................... 39
1.
TECHNICAL CHARACTERISTICS AMM GATEWAY/ROUTER ............................................ 40
1.1.
SUPPLY:.......................................................................................................................... 40
1.2.
MOUNTING:................................................................................................................... 40
1.3.
OPERATION TEMPERATURE RANGE:............................................................................. 40
1.4.
MAXIMUM OPERATION HUMIDITY:.............................................................................. 40
1.5.
ANTICIPATED OPERATION LIFE: .................................................................................... 40
1.6.
MAXIMUM HOUSING DIMENSIONS (WХLХH):.............................................................. 40
1.7.
NUMBER OF SUPPORTED METERS (CAPACITY):............................................................ 40
1.8.
COMMUNICATION PORTS (MINIMUM): ....................................................................... 40
1.9.
OTHER PORTS (OPTIONAL): ........................................................................................... 40
1.10.
HARDWARE MONITORING: ........................................................................................... 40
1.11.
REAL TIME CLOCK .......................................................................................................... 41
1.12.
PROTECTION AGAINST DUST AND WATER: .................................................................. 41
2.
AMM GATEWAY/ROUTER ROLE AND FUNCTIONS........................................................ 41
2.1.
GATEWAY/ROUTER ROLE .............................................................................................. 41
2.2.
GATEWAY/ROUTER FUNCTIONS ................................................................................... 42
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR CELLULAR MODEM . 44
1
BASIC CHARACTERISTICS OF CELLULAR MODEM ............................................. 45
1.1.
GPRS MOBILE STATION CLASS: ..................................................................................... 45
1.2.
GPRS MULTI-SLOT CLASS:.............................................................................................. 45
1.3.
DUAL BAND GSM/GPRS:................................................................................................ 45
1.4.
OPERATING TEMPERATURE RANGE: ............................................................................. 45
1.5.
EXTERNAL ANTENNA CONNECTION: ............................................................................. 45
2
REQUIREMENTS FOR CELLULAR MODEM ........................................................... 45
2.1
GENERAL REQUIREMENTS FOR CELLULAR MODEM ........................................ 45
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR PLC MODEM ........... 47
1.
GENERAL REQUIREMENTS FOR PLC MODEM ............................................................... 48
1.1
SPECIAL REQUIREMENTS OF PLC MODEM FOR THE CONCENTRATOR/ROUTER .......... 48
1.2
SPECIAL REQUIREMENTS OF PLC MODEM FOR METERS .............................................. 48
2.
BASIC TECHNICAL CHARACTERISTICS OF OFDM PLC MODEM ...................................... 50
2.1
GENERAL REQUIREMENTS FOR OFDM PLC COMMUNICATION.................................... 50
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR RADIO MODEM ...... 51
1.
GENERAL REQUIREMENTS FOR A RADIO MODEM ....................................................... 52
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1.1
SPECIAL REQUIREMENTS OF RADIO MODEM FOR THE CONCENTRATOR/ROUTER ..... 52
1.2
SPECIAL REQUIREMENTS OF A RADIO MODEM FOR METERS ...................................... 52
2.
BASIC TECHNICAL CHARACTERISTICS OF A RADIO MODEM ......................................... 54
FUNCTIONAL REQUIREMENTS FOR SWITCHING MODULE (BISTABLE SWITCH) ...................... 55
1.
SWITCHING MODULE (BISTABLE SWITCH) .................................................................... 56
1.1.
INTEGRATED SWITCHING MODULE (BISTABLE SWITCH) .............................................. 56
1.2.
EXTERNAL SWITCHING MODULE (BISTABLE SWITCH) .................................................. 56
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR SINGLE-PHASE AND
THREE-PHASE METERS OF ACTIVE ELECTRICAL ENERGY ......................................... 57
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR SINGLE-PHASE
METERS OF ACTIVE ELECTRICAL ENERGY ............................................................... 58
SINGLE-PHASE METER WITH CONSUMPTION MANAGEMENT FUNCTION ............................. 59
1.
TECHNICAL CHARACTERISTICS OF SINGLE-PHASE ACTIVE ELECTRICITY METER FOR
DIRECT CONNECTION (SINGLE-PHASE METER WITH CONSUMPTION MANAGEMENT
FUNCTION) .................................................................................................................... 60
1.1.
GENERAL TECHNICAL CHARACTERISTICS ...................................................................... 60
1.2
OTHER TECHNICAL CHARACTERISTICS .......................................................................... 63
2.
METER FUNCTIONS ....................................................................................................... 65
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS ................................................. 65
2.2.
ADDITIONAL FUNCTIONS .............................................................................................. 68
2.3.
CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT ......................................... 70
2.4.
ELECTRICITY METERING QUALITY ................................................................................. 72
2.5.
METER FIRMWARE UPGRADE ....................................................................................... 73
2.6.
SELF-CHECK.................................................................................................................... 73
2.7.
MULTI-UTILITY METERING ............................................................................................ 73
2.8.
DATA SECURITY ............................................................................................................. 74
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE-PHASE
ELECTRICITY METERS OF ACTIVE ELECTRICAL ENERGY ............................................ 75
THREE-PHASE METER WITH CONSUMPTION MANAGEMENT FUNCTION .............................. 76
1.
TECHNICAL CHARACTERISTICS OF THREE-PHASE ACTIVE ELECTRICITY METER FOR
DIRECT CONNECTION (THREE-PHASE METER WITH CONSUMPTION MANAGEMENT
FUNCTION) .................................................................................................................... 77
1.1.
GENERAL TECHNICAL CHARACTERISTICS ...................................................................... 77
1.2
OTHER TECHNICAL CHARACTERISTICS .......................................................................... 80
2.
METER FUNCTIONS ....................................................................................................... 82
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS ................................................. 82
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2.2.
ADDITIONAL FUNCTIONS .............................................................................................. 86
2.3.
CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT ......................................... 88
2.4.
ELECTRICITY METERING QUALITY ................................................................................. 90
2.5.
METER FIRMWARE UPGRADE ....................................................................................... 90
2.6.
SELF-CHECK.................................................................................................................... 91
2.7.
MULTI-UTILITY METERING ............................................................................................ 91
2.8.
DATA SECURITY ............................................................................................................. 91
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE-PHASE
ELECTRICITY METERS OF ACTIVE AND REACTIVE ELECTRICAL ENERGY .................... 93
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE-PHASE
ELECTRICITY METERS OF ACTIVE AND REACTIVE ELECTRICAL ENERGY FOR DIRECT
CONNECTION ........................................................................................................ 94
DIRECT C/I METER WITHOUT THE POSSIBILITY OF DEMAND MANAGEMENT ........................ 94
1.
TECHNICAL CHARACTERISTICS OF METERS OF ACTIVE AND REACTIVE ELECTRICITY FOR
DIRECT CONNECTION (THREE-PHASE DIRECT C/I METER WITHOUT CONSUMPTION
MANAGEMENT) ............................................................................................................. 95
1.1.
GENERAL TECHNICAL CHARACTERISTICS ...................................................................... 95
1.2.
OTHER TECHNICAL CHARACTERISTICS .......................................................................... 99
2.
METER FUNCTIONS ..................................................................................................... 101
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS ............................................... 101
2.2.
ADDITIONAL FUNCTIONS ............................................................................................ 104
2.3.
CONTROL OUTPUT ...................................................................................................... 106
2.4.
ELECTRICITY QUALITY METERING ............................................................................... 106
2.5.
SELF-CHECK.................................................................................................................. 106
2.6.
DATA SECURITY ........................................................................................................... 106
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE-PHASE METERS
OF ACTIVE AND REACTIVE ELECTRICITY FOR DIRECT CONNECTION ....................... 108
DIRECT C/I METER WITH CONSUMPTION MANAGEMENT .................................................. 108
1.
TECHNICAL CHARACTERISTICS OF THREE-PHASE METER OF ACTIVE AND REACTIVE
ELECTRICITY FOR DIRECT CONNECTION (THREE-PHASE DIRECT C/I METER WITH
CONSUMPTION MANAGEMENT) ................................................................................ 109
1.1.
GENERAL TECHNICAL CHARACTERISTICS .................................................................... 109
1.2.
OTHER TECHNICAL CHARACTERISTICS ........................................................................ 113
2.
METER FUNCTIONS ..................................................................................................... 115
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS ............................................... 115
2.2.
ADDITIONAL FUNCTIONS ............................................................................................ 118
2.3.
CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT ....................................... 120
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2.4.
ELECTRICITY QUALITY METERING ............................................................................... 122
2.5.
SELF-CHECK.................................................................................................................. 122
2.6.
DATA SECURITY ........................................................................................................... 122
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE-PHASE METERS
OF ACTIVE AND REACTIVE ELECTRICITY ............................................................... 124
CT CONNECTED C/I METER ................................................................................................ 124
1.
TECHNICAL CHARACTERISTICS FOR THREE-PHASE METERS OF ACTIVE AND REACTIVE
ELECTRICITY FOR SEMI-INDIRECT CONNECTION (THREE-PHASE CT CONNECTED C/I
METER) ........................................................................................................................ 125
1.1.
GENERAL TECHNICAL CHARACTERISTICS .................................................................... 125
1.2.
OTHER TECHNICAL CHARACTERISTICS ........................................................................ 129
2.
METER FUNCTIONS ..................................................................................................... 131
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS ............................................... 131
2.2.
ADDITIONAL FUNCTIONS ............................................................................................ 134
2.3.
CONTROL OUTPUT ...................................................................................................... 135
2.4.
ELECTRICITY QUALITY METERING ............................................................................... 136
2.5.
SELF-CHECK.................................................................................................................. 136
2.6.
DATA SECURITY ........................................................................................................... 136
TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE-PHASE METERS
OF ACTIVE AND REACTIVE ELECTRICITY ............................................................... 138
1.
TECHNICAL CHARACTERISTICS FOR THREE-PHASE METERS OF ACTIVE AND REACTIVE
ELECTRICITY FOR INDIRECT CONNECTION (THREE-PHASE CT VT CONNECTED C/I
METER) ........................................................................................................................ 139
1.1.
GENERAL TECHNICAL CHARACTERISTICS .................................................................... 139
1.2.
OTHER TECHNICAL CHARACTERISTICS ........................................................................ 143
2.
METER FUNCTIONS ..................................................................................................... 145
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS ............................................... 145
2.2.
ADDITIONAL FUNCTIONS ............................................................................................ 149
2.3.
ELECTRICITY QUALITY METERING ............................................................................... 150
2.4.
SELF-CHECK.................................................................................................................. 151
2.5.
DATA SECURITY ........................................................................................................... 151
ADDITIONAL METER FUNCTIONS FOR CONNECTION OF ELECTRICITY GENERATION FACILITIES
..................................................................................................................................... 153
1.
ADDITIONAL METER FUNCTIONS FOR CONNECTION OF ELECTRICITY GENERATION
FACILITIES .................................................................................................................... 154
1.1.
MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR METERS WITH DIRECT
CONNECTION ............................................................................................................... 154
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1.2.
MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR CT METERS ............................. 155
1.3.
MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR CT VT METERS ........................ 155
2.
OPTIONAL SCOPE OF ADDITIONAL FUNCTIONS .......................................................... 155
2.1.
SEALING ....................................................................................................................... 155
2.2.
PROFILES OF METERED AND REGISTERED VALUES ..................................................... 155
2.3.
MAXIMUM APPARENT POWER ................................................................................... 156
2.4.
MINIMUM POWER FACTOR ........................................................................................ 156
2.5.
DATA STORAGE PERIOD .............................................................................................. 156
3.
OPTIONAL SCOPE OF ADDITIONAL FUNCTIONS FOR CT METERS ............................... 156
3.1.
RATED ACCURACY CLASS ............................................................................................. 156
FUNCTIONAL REQUIREMENTS OF METER DATA MANAGEMENT AND REPOSITORY SYSTEM
(MDM/R) ............................................................................................................ 157
1.
METER DATA MANAGEMENT AND REPOSITORY SYSTEM .......................................... 158
1.1.
ABBREVIATIONS .......................................................................................................... 158
1.2.
APPLIED STANDARDS .................................................................................................. 161
1.3.
PURPOSE...................................................................................................................... 162
1.4.
SCOPE .......................................................................................................................... 162
1.5.
MDM/R SYSTEM OVERVIEW ....................................................................................... 162
1.6.
GENERAL FUNCTIONAL REQUIREMENTS .................................................................... 163
2.
DETAILED FUNCTIONAL REQUIREMENTS .................................................................... 164
2.1.
OVERVIEW OF FUNCTIONALITIES ................................................................................ 165
2.2.
REGULATORY AGENCY REQUIREMENTS ..................................................................... 165
2.3.
UNIQUE POINT OF DELIVERY (POD) ID NUMBER ........................................................ 166
2.4.
DATA ENTRY INTO MDM/R SYSTEM ........................................................................... 166
2.5.
TIME FLOW OF DATA EXCHANGE ................................................................................ 170
2.6.
DATA SUBMISSION BY MDM/R SYSTEM ..................................................................... 172
2.7.
DATA MANAGEMENT .................................................................................................. 175
2.8.
FUNCTIONAL REQUIREMENTS IN TERMS OF DATA STORAGE .................................... 178
FUNCTIONAL REQUIREMENTS - PRINCIPLES OF END-TO-END SECURITY ............................. 183
FUNCTIONAL REQUIREMENTS - PRINCIPLES OF INTEGRATION ........................................... 188
FUNCTIONAL REQUIREMENTS - GENERAL .......................................................................... 190
CHANGES TO THE DOCUMENT................................................................................................... 192
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ABBREVIATIONS
Table 1 – Overview of used abbreviations
AMCD
Advanced Metering Communication Device
AMR
Automated Meter Reading
AMRC
Advanced Metering Regional Collector
AMI
Advanced Metering Infrastructure
AMM
Automated/Advanced Metering Management
AMCC
Advanced Metering Control Computer
CET
Central European Time
CIM
Common Information Model
CIS
Customer Information System
COSEM
Companion Specification for Energy Metering
DLMS
Device Language Message Specification
IEC
International Electrotechnical Commission
MDM/R Meter Data Management and Repository
OMS
Outage Management System
RF
Radio Frequency
CT
Current transformer
VT
Voltage transformer
C/I
Commercial or Industrial
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APPLIED STANDARDS
The following standards were used in the course of development of this document:
IEC 60529
Degrees of protection provided by enclosures (IP Code)
International Electrotechnical Vocabulary – Electrical and electronic measurements
and measuring instruments
IEC 60050-300
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 61334-5-1
IEC 61968-1
Distribution automation using distribution line carrier systems - Part 5-1: Lower
layer profiles - The spread frequency shift keying (S-FSK) profile
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
IEC 61968-3
Application integration at electric utilities – System interfaces for distribution
management
Part 3: Interface for network operations
IEC 61968-9
Application integration at electric utilities – System interfaces for distribution
management
Part 9: Interface for meter reading and control
IEC 61968-11
Application integration at electric utilities – System interfaces for distribution
management
Part 11:Common Information Model (CIM) Extensions for Distribution
IEC 61970-301
IEC 62051:1999
Energy management system application program interface (EMS-API)
Part 301: Common information model (CIM) base
Electricity metering – Glossary of terms
Electricity metering – Data exchange for meter reading, tariff and load control
IEC 62051-1
Part 1: Terms related to data exchange with metering equipment using
DLMS/COSEM
IEC 62052-11
Electricity metering equipment (AC) - General requirements, tests and test
conditions - Part 11: Metering equipment.
IEC 62053-31
Electricity metering equipment (a.c.) - Particular requirements - Part 31: Pulse
output devices for electromechanical and electronic meters (two wires only).
IEC 62053-21
Electricity metering equipment (a.c.) - Particular requirements -Static meters for
active energy (classes 1 and 2)
IEC 62053-22
Electricity metering equipment (a.c.) - Particular requirements -Static meters for
active energy (classes 0.2S and 0.5S)
IEC 62053-52
Electricity metering equipment (AC) - Particular requirements - Part 52: Symbols.
IEC 62054-11
Electricity metering (a.c.) - Tariff and load control - Part 11: Particular requirements
for electronic ripple control receivers.
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IEC 62054-21
Electricity metering (a.c.) - Tariff and load control - Part 21: Particular requirements
for time switches.
Electricity metering – Payment systems
IEC 62055-31
Part 31: Particular requirements – Static payment meters for active energy (classes
1 and 2)
IEC 62056-21
Electricity metering - Data exchange for meter reading, tariff and load control Part 21: Direct local data exchange.
IEC 62056-42
Electricity metering - Data exchange for meter reading, tariff and load control Part 42: Physical layer services and procedures for connection-oriented
asynchronous data exchange.
IEC 62056-46
Electricity metering - Data exchange for meter reading, tariff and load control Part 46: Data link layer using HDLC protocol.
IEC 62056-47
Electricity metering - Data exchange for meter reading, tariff and load control Part 47: COSEM transport layers for IPv4 networks.
IEC 62056-53
Electricity metering - Data exchange for meter reading, tariff and load control Part 53: COSEM application layer.
IEC 62056-61
Electricity metering - Data exchange for meter reading, tariff and load control Part 61: Object identification system (OBIS).
IEC 62056-62
Electricity metering - Data exchange for meter reading, tariff and load control Part 62: Interface classes.
EN 13757-2
EN 13757-2 Communication systems for remote reading of meters. Physical and
link layer.
DIN 43857
Watthour meters in moulded insulation case without instrument transformers, up
to 60 A rated maximum current; principal dimensions for three-phase meters
EN 50065-1
CENELEC EN 50065-1 Signalling on Low-Voltage Electrical Installations in the
Frequency Range 3 kHz to 148,5 kHz Part 1: General Requirements, Frequency
Bands and Electromagnetic Disturbances
EN 50470-1
EN 50470-1 Electricity metering equipment (a.c) - General requirements, tests and
test conditions – Metering equipment (class indexes A, B, C)
EN 50470-3
EN 50470-3 Electricity metering equipment (a.c) - Particular requirements, Static
meters for active energy (class indexes A, B, C)
VDN
Recommendation of German Electric Industry Association
MID 2004/22/EC
Directive 2004/22/EC of the European Parliament and of the Council of 31 March
2004 on measuring instruments
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FUNCTIONAL REQUIREMENTS AND TECHNICAL SPECIFICATIONS OF
SYSTEM ARCHITECTURE
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1. HIGH LEVEL ARCHITECTURE
This chapter describes high level architecture of the Smart Metering system in a wider context
of Smart Grid activities, home automation etc.
In general MDM and AMM systems have to be integrated in the context of EPS application
infrastructure (EPS legacy systems, DSOs legacy systems and).
Regular data exchange regarding metered consumption and related information will be
provided to relevant third parties (e.g. suppliers, market operator, market regulator).
The smart metering infrastructure will enable EPS to measure consumption of:

- MV/LV substations;

- MV commercial and industrial customers;

- LV households and commercial and industrial customers.
Smart metering context
Smart metering provides two-way information flows between the smart meters and the
designated market participants. Smart metering systems may exist in the context of larger
smart grid infrastructures and may co-exist with home automation systems.
In the context of this document we will focus mainly on the elements of Smart metering
systems – technologies and architectures which enable modern data acquisition and
processing.
Figure 1 - Intersection of Smart Metering, Smart Grid and Home Automation systems
As it is shown above, smart metering applications may overlap with applications of smart grid
systems and building / home automation systems.
Indeed, the functional scope of smart metering can vary from just automating the meter value
collection process, to full automation and surveillance of the low voltage network.
Particularly in relation to electricity metering, there is the important additional objective of
facilitating smart grid applications, notably through the incorporation of distributed
generation.
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Smart metering architecture
AMI is a system of smart meters, data concentrators, two-way communications networks, and
data management systems implemented to enable metering and other information exchange
between utilities and their customers.
High level architecture of Smart Metering system and its connections with ICT environment of
EPS, grid operator and third parties is shown below.
Figure 2 – High level architecture
Decentralized deployment model is recommended.
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The smart metering infrastructure will enable EPS to measure consumption of:

MV/LV substations;

MV commercial and industrial customers;

LV households and commercial and industrial customers.
Different types of communications have to be assumed for these groups:
Smart Meter segment
PLC
RF
GPRS/LTE Ethernet
Substation balancing meters
MV industrial and commercial customers
LV households and industrial and commercial
customers
Table 1 - Smart meter segments and types of communications to be used
Smart meters communicate using Power Line Communications (PLC) and Radio Frequency (RF)
with Field Area Concentrators /Routers in Neighbour Area Network (NAN). This network is
specific because it is limited to certain geographic area (usually on the level of sub-station).
Field Area Concentrators / Routers are through WAN connected with AMI (Advanced Meter
Infrastructure) application center(s) which consists of:

Advanced metering infrastructure Head-End (AMI Head End),

This systems controls collection of metring data, manage two-way communication with
meters, and monitors and manage communication network (Network Management
System – NMS),

Meter Data Management/ (MDM) and Data Center,

Meter Data Management process data collected from the meters and is also repository
of data. Amount of these data is potentially extremely big, so Data Centre is build for
purpose of keeping this data.
Main connections of AMI are:

to other technical subsystems – SCADA, Outage management systems (OMS),
Distribution management systems (DMS),

to business support systems: billing, CRM, asset management,

to third party systems: market operators, market regulator, suppliers, etc.
Security aspects (authorization and authentication of all elements of the system, keys,
certificates, cryptography, access control, etc) can be handled by separate security sub-system
or security system for complete ICT infrastructure.
ESB (Enterprise Service Bus) is preferable way to connect all applications of grid operator. In
general every new system which is to be built shall be integrated on related EPS legacy systems
via ESB layer. ESB doesn’t handle processes within AMM but exposes connectors on and
among all related. New processes realized in the new AMM system are integrated through ESB.
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AMI should be monitored as a whole. It means that also status of communication technology
or for example service level of telecommunication networks are also gathered and evaluated.
Two main components of Smart Metetering system are decriebed in this document:

Meter Data Management (MDM);

Advanced Metering Infrastructure System (AMI/AMM).
Requirements concerning the following closely related topics are furder described in grater
detail in separate sections:

Integration,

Security.
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FUNCTIONAL REQUIREMENTS AND TECHNICAL SPECIFICATIONS OF
AMI SYSTEM
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1. FUNCTIONAL REQUIREMENTS FOR AMM CENTRE
1.1. DESCRIPTION AND GENERAL REQUIREMENTS FOR AMM CENTRE IN AMI CONTEXT
AMM centre is based on AMM (Automated Meter Management) concept implying remote
reading and simultaneous efficient supervision and management of other AMI components
(Advanced Metering Infrastructure) (hereinafter referred to as: ’the System’), high data
processing speed in multiuser environment (Client/Server architecture), connection with other
information systems (Billing system, Customer Information System, etc.) and data transfer into
MDM/R (Meter Data Management & Repository) (hereinafter referred to as: ’MDM’).
Depending on the size of demand area of individual subsidiaries, the scope of AMM system will
be in the range from 30.000 to 1.000.000 units (meters). The system is sufficiently flexible to
allow easy upgrade and thereby cover the changes within PE EPS, whether due to the change
of the number of customers, or due to the changes in the organization of subsidiaries, i.e. PE
EPS.
Data are stored into the data base of standard and licensed system for relation data bases
management. Applied data model has to enable simple integration with other information
systems and subsystems implemented in subsidiaries for electricity distribution of PE EPS
(electric utility). AMM Centre data model needs to be realised and delivered in a standard
format of modelling programmes with descriptive names and/or clear description of all data
base objects (entities, attributes, views, relations, procedures, etc.).
AMM Centre is based on a corresponding computer and telecommunication infrastructure
enabling its continual and efficient operation - (existing „fail safe“ systems provide required
redundancy, disturbance-free operation in case of power supply outage and like). Servers
(AMCC - Advance Metering Control Computer) and clients of AMM Centre have a
corresponding system and application software installed enabling execution of all specific
functions. AMM Centre needs to function under the conditions of existing computer and
telecommunication organisation of electric utility. It is desirable that administrator and client
GUI (Graphical User Interface) is realised on the latest computer platform not requiring special
software installation.
Functional requirements to be specified in this document imply that AMM Centre will be
realised to enable functionality indicated in technical specification of other System
components related to AMM Centre.
Communication between AMM Centres and other System components is executed via WAN.
Every electric utility will according to its current state of telecommunication and computer
infrastructure define redundant communication routes with System components.
Security in AMM Centre is part of overall security system, e.g. access to data is strictly
protected by role based security, devices (meters, data concentrator/ routers) are check for
validity and encryption is mandatory for storing data and any type of communication.
Data export into files option is mandatory (min. ASCII, EXCEL and XML type files). More
detailed file formats would be additionally determined based on the needs of electric utility.
Also, standardized interfaces (see functional request for integration in this document) will be
used for advanced information exchange.
AMM system should support data concentrators and/or meter routers/gateways (see
respective chapters in the rest of this document). In this chapter we will make alternatives of
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requested functionalities for both ways. Alternatives will be marked with DC and RG marks.
Alternative text will be in italic.
Functions of AMM Centre in terms of data reading and configuration should be executed on
laptops connected directly to the concentrator and/or router/gateway and the meter.
In addition to this, functions related to meter data reading and configuration should also be
executed on handhelds.
2. AMM CENTRE FUNCTIONS
AMM Centre functions may be divided into the following:

Administration functions.

Data reading/collection and archiving functions.

Reporting functions.

Data and information exchange functions with MDM system and other information systems
and subsystems of electric utility.
2.1 ADMINISTRATION FUNCTIONS
System administration is executed via multiuser application for the purpose of:

System components administration

AMM Centre administration
2.1.1 SYSTEM COMPONENTS ADMINISTRATION
Administration of System components is realised via remote management/parameterisation in
two ways. First operation mode is when desired parameters are changed with corresponding
administrative rights in direct communication with the meter or DC: concentrator.
The second operation mode is when automated management/parameterisation is performed
over a group of system elements. In AMM Centre, commands/parameters are set for
management/parameterisation of System components, while afterwards superordinate
System component individually realises the task.
DC: For example, in case when all meters within one substation region are in question, AMM
Centre sets necessary parameters for the authorised concentrator, while the task is performed
by the concentrator without direct connection with AMM Centre.
RG: In the case of router/gateway, automation scheduling of tasks are done by centralised
scheduler.
According to the number of managed i.e. parameterised System elements we have:

Management/parameterisation of an individual element.

Management/parameterisation of the group of elements.
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According to the manner of execution, management/parameterisation may be:

Automated management/parameterisation according to sequence.

Manual management/parameterisation on request.
Administration of System components is realised to make possible any combination of the
above-indicated divisions according to the number of elements or the manner of
management/parameterisation execution.
Administration of System components will after its every action generate a corresponding
report available to the system administrator, containing the success percentage of the set
action and the list of elements from which there was no confirmation of
management/parameterisation execution.
Administration of System components enables:

Meter administration.

Administration of communication devices.

DC: Concentrator administration.

Monitoring of System components replacement history.

Monitoring of command and parameter history of System components.

Monitoring of the communication network
2.1.2 METER ADMINISTRATION
Meter administration enables the following:

Meter data entry and update.

Customer data entry and update.

Meter parameters entry and update.

Entry, update and monitoring of data on installation and replacement of meters.

Introducing previously automatically detected meters into the system.

Real time clock synchronisation.

Daylight saving time changes.

Tariff programme change.

Change of value display period on meter display.

Change of sequence and selection of registers for display on meter display.

Activation of function keys on the meter (e.g. conditional reconnection).

Change of electric power integration period.

Change of phase presence detection threshold.

Change of approved mean power limit.

Change of remote command regime (prohibition of remote meter disconnection).
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
Remote customer disconnection/connection.

Controllable output management.

Change of reconnection regime (automatic or conditional).

Update of ‘penalty time’ parameters.

Change of registers within profile framework.

Change of profile periods.

Change of voltage thresholds related to electricity quality.

Meter software change (single-phase and three-phase meters).

Credit change for Pre-Paid meters.

Enabling of message sending to the customer (HAN)
AMM Centre will execute automatic generation of a unique point of delivery identifier
(contains identification attribute of the meter) – POD (Point of Delivery).
Meter administration should enable simple concurrent POD connection with identification
attributes of entities (customer data, network resources data, etc) from other information
systems and subsystems of ELECTRIC UTILITY via ‘drag-and-drop’ procedure.
In addition to this, meter administration enables meter location into hierarchically organised
logical wholes (customer categories, substation regions, geographical – administrative areas,
etc), with possibility of simultaneous location into the higher number of hierarchically equal
logical wholes. It is necessary to provide simple relocation of one meter/groups of meters from
one logical whole to another (drag-and-drop).
2.1.3 CONCENTRATOR ADMINISTRATION
Concentrator administration enables the following:

Concentrator data entry and update.

Concentrator parameters entry and update.

Entry, update and monitoring of data on installation and replacement of concentrators.

Review, organisation and change of ancillary meters.

Real time clock synchronisation.

Review and synchronisation of reading programmes/sequence.

Review and synchronisation of programmes/sequence of management/parameterisation.

Review and synchronisation of programme/sequence execution priorities.

Review of communication PLC route (if not set automatically).

Review and change of concentrator reporting time and frequency parameters.

Review and change of event parameters for emergency concentrator reporting.

Review and change of communication parameters of concentrator.

Review and change of other concentrator parameters.
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
Change of concentrator management software.

Review of corresponding concentrator records on the change of parameters and
concentrator adjustment.

Setting of security parameters (keys,etc…) of concentrator.
2.1.4 ADMINISTRATION OF COMMUNICATION CELLLULAR MODEMS

Entry, update and monitoring of data on installation and replacement of router/gateway.

Real time clock synchronisation

Review and change of communication parameters of gateway/router.

Change of gateway/router management software.

Setting of security parameters (keys, etc…) of gateway/router.
2.1.5 ADMINISTRATION OF COMMUNICATION CELULAR MODEMS
Administration of communication celular modems enables the change of communication
parameters.
2.1.6 ADMINISTRATION OF AMM CENTRE

Defining of roles and users/user groups.

Access control to System components and AMM Centre.

Administration of reporting functions of AMM Centre.

Regular automatic backup of all data at the desired time.
Defining of user/user group rights needs to be defined in relation to:

Entry and update of data and parameters.

Defining of possibilities for command execution.

Hierarchically organised logical wholes.
Optionally, AMM Centre administration also ensures the following:

Administration of software components (versions of application software and firmware)
and all the settings of AMI system, i.e. its components.

Automatic monitoring of parameters and performances of AMM Centre operation, analysis
and generation of the reports on the system operation, as well as informing the system
operator on the observed problems.

Management (generating, taking over, archiving, monitoring and controlling the access) of
the documents required for proper system operation.
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2.2 AMM CENTRE DATA COLLECTION/READING AND MEMORISING FUNCTIONS
Data collection/reading and memorising function collects data automatically in an efficient and
reliable manner from the DC: concentrator/meter and memorises (archive) them in a
corresponding data base or performs instant reading of the concentrator/meter upon user
request.
Reading function is realized through corresponding reading programmes/sequences.
According to the amount of concentrator/meters being read we differentiate:

Reading of individual DC: concentrator/meter.

Reading of the group of DC: concentrator /meters
According to the reading frequency we differentiate:

Automated reading according to the sequence

Reading on request

Periodical reading on request

Special reading on request
Data collected automatically according to the sequence set in advance (no difference is made
whether these data are collected from the concentrator or via direct communication with the
meter) include:

Daily register values*.

Meter states*.

Electricity quality log.

Event log.

Load profile.

Hourly register values *.

State of monthly accounting registers.

Time and date.
Data collected from the meter on request (via DC: concentrators or direct communication with
the meter) include the following, in addition to data collected automatically:

Effective voltage values per phases at the moment of reading.

Effective current values per phases at the moment of reading.

Current power – (load power at the moment of reading)*.

Tariff programme.

Integration period for 15-minute maximum power.

Consumption management parameters.

Parameters for voltage thresholds within electricity quality log.

Parameters or time intervals of profiles.
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
Parameters for registers within profiles.

Parameters related to the presentation on meter display.

Archive states of accounting registers.

Current state of bi-stabile switch.

Meter software version.

Factory number and type of meter.
* The data is transmitted together with the time stamp of data creation
Data read according to the sequence from the DC: concentrator RG: router/gateway (in
addition to data obtained by meter reading) include:

Statistics of communication.

Emergency and regular reports.
DC: Data read from the concentrator upon the request include:

Concentrator data archive.

Reading programmes/sequences.

Management/parameterisation programmes/sequences.

Programme/sequence execution priorities.

Communication PLC routes.

Concentrator response time and frequency parameters.

Communication parameters of the concentrator.

Current date and time.

Other concentrator parameters.

Concentrator software version.

Records on concentrator parameter changes and adjustments.
Data collection/reading function offers reading control with the display of percentage of
successfully read meters/DC: concentrators in every reading.
2.3 REPORTING FUNCTIONS OF AMM CENTRE
Reporting functions are divided in:

Reports with analysis of statuses and alarms.

Reports on electricity quality.

Reports related to parameterisation and management.
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
Communication reports.

Control reports.

Reports generated by the concentrator.
Reports with analysis of statuses and alarms
This type of reporting functions processes alarms and statuses of meters/concentrators, event
logs, with the making of corresponding reports after finding corresponding alarms, statuses
and events.
These functions would minimally process events and alarms related to the disruption of meter
integrity (e.g. opening of termination cover), as well as attempt or disruption of data integrity
in meters or concentrators themselves (e.g. meter reprogramming attempt).
Result of such reports should be the daily, i.e. periodical report on the state clearly showing all
alarms, statuses and events and on which meters, representing the basis for further action on
these meters.
Reports on electricity quality
This reporting function would execute analysis of voltage circumstances on meters themselves
since there are corresponding records in the electricity quality log recording voltage
drop/overvoltage below/above defined voltage thresholds and supply interruptions. In this
way the function would indicate poor voltage circumstances with one or a group of customers
and it would represent the reason for the crews to go out into the field.
Reports related to parameterisation and management
In addition to the reports which were the consequence of parameterisation/management over
System elements, it is also necessary to anticipate a number of reports.
Due to great significance, there also needs to be a report on disconnected customers, i.e. the
report on the management of bistable switch which needs to contain the date when the action
was set and when action execution confirmation arrived.
Communication reports
Successfulness statistics of communication between system elements represents a special
whole within the reporting functions.
Control reports
These reports would indicate real time detuning or disagreement in tariff programme. Results
of these reports represent the basis for the setting of automatic parameterisation over
elements where detuning has been noticed.
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DC: Reports generated by the concentrator
Reporting functions also support the presentation of reports the concentrator sends upon
emergency reporting request to AMM Centre.
General requirements
It goes without saying that reports may be sorted according to all parameters. Moreover,
search function needs to have the possibility of search according to all System element
attributes.
Form of registered energy and power report is dynamically/automatically adapted to the
current tariff programme without the need for additional software intervention.
Print/Print Preview option is mandatory with every report automatically generated in the form
of PDF file.
This list of reports is not final since it is not possible at this moment to anticipate all necessary
types of reports. This is a minimum set which surely needs to exist and which will in time
evolve into a final and detailed list of reporting functions based on electric utility needs.
Generator of ad hoc reports should be realised within AMM Centre.
2.4 DATA AND INFORMATION EXCHANGE FUNCTIONS WITH MDM SYSTEM AND OTHER ISS
OF ELECTRIC UTILITY
This function is realized to enable most efficiently the connection and exchange of data from
MDM system. This function will also provide the connection towards other information
subsystems.
By the use of existing computer and telecommunications infrastructure within subsidiaries,
required safety of communication route/routes between AMM Centre and MDM System is
ensured.
2.4.1 DATA TRANSFER INTO MDM SYSTEM
AMM Centre should support push and pull procedure of data submission on metered
consumption and other data to MDM system. Data on metered consumption to be transferred
to MDM system are as follows:

Data on metered consumption for households, where there are no requirements in terms
of requested load on hourly level; data on consumption need to be transferred in the end
of the daily accounting interval.

Data on metered consumption for industrial customers, where there are requirements in
terms of requested load; data on consumption need to be transferred either as 15 or 60minute data in the end of the daily accounting interval.
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All data transferred via this data transfer method need to be related to the same calendar day.
Finally, transferred parameters should minimally have identified information in their heading
reporting to MDM system the priority during data upload for more subordinated devices
simultaneous data transfer is requested.
Data transfer priorities
MDM system will preserve all versions of meter data received from the control AMM Centre.
For the purpose adaptation to enable MDM system to execute urgent data processing in
accordance with critical situations, when several requests need to be processed at the same
moment, it needs to have data processing procedure according to priority. MDM system
should support processing priority determination procedure in relation to data to be submitted
by AMM Centre. Priority should be based on time and date of meter data occurrence.
AMM Centre should be able to enable the sending of all data on metered consumption every
day for the previous daily reading period. In order to perform data transfer successfully, all
process clocks on all computers within the subject subsystems should be synchronised.
Confirmation
After all data sent by AMM Centre are received and processed for the purpose of verification
by MDM system, MDM system will send a message to AMM Centre for confirmation of
successful message receipt or possible problem in the course of transfer.
2.4.2 REPORT SUBMISSION TO MDM SYSTEM BY AMM CENTRE
AMM Centre should submit reports to MDM system defined by this document. MDM system
should archive submitted reports.
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
LOW VOLTAGE CONCENTRATOR
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1. TECHNICAL CHARACTERISTICS OF LOW VOLTAGE CONCENTRATOR
CONSTRUCTION: Fanless Embedded PC – Concentrator is executed without moving parts, in
accordance with standards for industrial computers (resistant to temperature, humidity, dust,
vibrations, electromagnetic radiation and other) adapted to operation conditions in
substations (SS).
1.1.
SUPPLY:
AC: 1х230V or 3х230V, 50Hz, Optional, DC: 24V.
1.2.
MOUNTING:
vertical (wall mounted).
1.3.
OPERATION TEMPERATURE RANGE:
from -20 c to +55 c.
1.4.
MAXIMUM OPERATION HUMIDITY:
90%.
1.5.
ANTICIPATED OPERATION LIFE:
10 years.
1.6.
MAXIMUM HOUSING DIMENSIONS (WХLХH):
400х400х200 (mm).
1.7.
NUMBER OF SUPPORTED METERS (CAPACITY):
1000 meters.
1.8.
STORAGE CAPACITY:
Capacity: minimum 4 GB.
1.9.
COMMUNICATION PORTS (MINIMUM):
1хLAN 10/100, RJ45.
COMMUNICATION PORTS FOR COMMUNICATION WITH CELLULAR or PLC modem – depending
on cellular or PLC modem performance):

If cellular modem is executed as external device, corresponding communication port for
communication with cellular modem;

If PLC modem is executed as external device, corresponding communication port for
communication with PLC modem.
COMMUNICATION PORTS (Optional) - depending on communication module):

1хUSB (minimum 2.0)

1хRS-232 (Isolated)

1хRS-485 (Isolated)
1.10. OTHER PORTS (OPTIONAL):
1xD-Sub (DB15) VGA
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1.11. HARDWARE MONITORING:
watchdog timer, optional CPU and housing temperature monitoring.
1.12. REAL TIME CLOCK
1.13. PROTECTION AGAINST DUST AND WATER:
IP 51 or better
1.14. OPERATING SYSTEM:
Embedded OS (ex: Windows XP embedded, Windows CE, Windows Mobile, Linux...)
2. CONCENTRATOR ROLE AND FUNCTIONS
2.1.
CONCENTRATOR ROLE
Concentrator is a device executing automatically or on request the functions of meter reading
and parameterization and data transfer functions to AMM Centre.
Concentrator has to execute operations defined in programmes/sequences submitted to it
remotely (from AMM Centre) or locally (via laptop) independently from AMM Centre and to
memorise read data obtained through execution of defined programmes/sequences for a
specified time period. The concentrator follows priorities of programmes/sequences during
execution of such programmes/sequences. At the request of AMM Centre or under reporting
programme/sequence, the concentrator needs to submit memorised data to AMM Centre or
deliver the data to laptop on request.
Concentrator also needs to enable immediate communication with individual meters, remotely
(from AMM Centre) or locally (via laptop).
Concentrator has communication ports for communication with meters and AMM Centre, as
well as communication port for local communication.
Handheld terminal for reading
and parameterisation
(Handheld, Lap-top...)
PLC modem
CONCENTRATOR
Meters with PLC modem
GPRS
modem
Management Centre
Figure 3 - Block diagram of concentrator communication ports
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Concentrator needs to support operation with DLMS/COSEM protocol along PLC
communication with meters.
In parallel with the above-indicated tasks, the concentrator executes initial data processing
collected until such moment, not affecting data reading, parameterisation and delivery.
Local access is used during the installation procedure or for the performance of other
maintenance activities, for local reading and configuration of the concentrator, as well as when
there are communication problems with AMM Centre. Local access between other accesses
has to support Remote Desktop approach.
Communication via local access has hierarchical precedence over the remote one.
External devices optionally connected to the concentrator may be used for future smart
network functionalities, e.g. control and supervision of substations, where concentrators are
usually located.
In addition to the connection of several networks, the concentrator may provide optimization
of communication. Optimisation methods include:

Data compression

Communication channels engagement time reduction

Response time optimisation
It is expected that new communication technologies, as well as additional requirements in
terms of expansion concentrator functions will emerge during the operation life of the
concentrator and the system in general. Concentrator software needs to have upgrade option
for future functionalities.
2.2.
GENERAL DESCRIPTION OF CONCENTRATOR FUNCTIONS
Concentrator software package has to realise at least the following functions:

Reading and memorising functions

Management/parameterisation functions

Communication functions

Data processing functions

Data and access protection functions

Administration functions
2.2.1. READING AND MEMORISING (ARCHIVING) FUNCTIONS
One of the basic functions of the concentrator is reading of meters located in its
communication network. Reading function is realised through the reading
programme/sequence. We differentiate:
1. According to the purpose of read meters:

Meters for total metering at the substation

Public lighting meters

Control meters
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
Customer meters – Households

Customer meters – Contractual customers
2. According to the type of read meters:

Single-phase

Three-phase

Direct metering groups.

Semi-indirect metering groups.
3. According to the amount of read meters:

Reading of individual meter

Reading of the group of meters
4. According to reading frequency:

Automated reading according to sequence

Reading on request

Periodical reading on request

Special reading on request.
Data read according to sequence:

Daily states of registers

Meter statuses

Electricity supply quality register

Event log

Load profile

Hourly states of registers

States of monthly accounting registers

Time and date.
Data read on request include the following, in addition to all data indicated as read according
to sequence:

Effective voltage values per phases at the moment of reading

Effective current values per phases at the moment of reading

Instantaneous power – (load power at the moment of reading)
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
Tariff programme

Integration period for 15-minute maximum power

Consumption management parameters

Parameters for voltage thresholds within electricity quality log

Parameters for time intervals of profiles

Parameters for registers within profiles

Parameters related to presentation of meter display

Archive states of accounting registers

Current state of bistable switch

Meter software version

Factory number and type of meter
Reading function in the concentrator is realised to enable all reading combinations (through
corresponding reading programmes/sequences) indicated above and the ones making sense.
Concentrator should have sufficient storage space (storage – point 1.1.9), therefore data
storage (archiving) function reliably should store all read data for at least 6 months, except
accounting data which need to be stored for 12 months.
2.2.1.1.
PROPOSAL FOR AUTOMATED READING ACCORDING TO SEQUENCE
Programmes/sequences related to this type of reading are divided into:

Daily

Weekly

Monthly
Initial daily reading programme/sequence of three-phase meters (households) reads the
following:
1. Daily value of meter register (value from 00:00) and meter statuses are read first.
2. When reading from point 1 is finalised, reading of electricity quality logs starts on all
meters.
3. When reading from point 2 is finalised, reading of event logs starts on all meters.
4. Hourly data from the meter are read after finalisation of Event Log reading.
5. Load profiles from the meter are read.
Under the current technical solution for PLC communication it can hardly be expected that
daily programmes will fully be executed on all meters within one substation region. That is way
reading algorithms should be provided enabling 98% realisation of daily reading
programme/sequence of points 1, 2 and 3 in accordance with the remaining time for execution
of this programme/sequence and priorities for other programmes/sequences.
Initial weekly reading programme/sequence of three-phase meters (households) reads the
following:
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1. Real time clock reading from all meters.
Initial monthly reading programme/sequence of three-phase meters (households) reads the
following:
2. Reading of monthly accounting data from all meters.
Programme/sequence reading priority should be as follows:
If the date on the real time clock is within between the 1st and 3rd day of the month, monthly
programme/sequence of reading has absolute priority and it is executed until all monthly
accounting data are completed for all meters or other conditions are created for programme
interruption. Otherwise, daily reading programme/sequence is executed.
Readings on request have priority over automated programmes/sequences of reading.
2.2.2. MANAGEMENT/PARAMETERISATION FUNCTION
Concentrator should have management/parameterisation function in charge for the change of
meter parameters, bistable switch control as well as meter software change (applied only for
single-phase and three-phase meters). This Function is realised through the
programme/sequence of management/parameterisation. We differentiate:
1. According to the purpose of read meters:

Meters for total metering at the substation

Public lighting meters

Control meters

Customer meters – Households

Customer meters – Contractual customers
2. According to the type of managed/parameterised meters:

Single-phase

Three-phase

Direct metering groups.

Semi-indirect metering groups.
3. According to the amount of managed/parameterised meters:

Management/parameterisation of individual meter

Management/parameterisation of the group of meters
According to frequency, function may be divided in:

Management/parameterisation according to sequence

Management/parameterisation on request
The list of parameters:

Real time clock synchronisation.
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
Daylight saving time changes.

Tariff programme change.

Change of value presentation period on meter display.

Change of sequence and selection of registers for presentation on meter display.

Key roles - conditional reconnection.

Change of integration period in case of 15-minute power.

Voltage threshold for phase presence decision.

Change of maximum power limit.

Change of bistable switch position. Remote disconnection/connection of the customer.

Controllable output management.

Automatic or conditional repeated disconnection

Penalty time.

Change of registers within profile framework.

Change of profile periods.

Voltage thresholds related to electricity quality.

Meter software change (only for single-phase and three-phase meters).

Credit change for Pre-Paid meters.

Message sending to the customer (HAN)
Management/parameterisation function will generate a corresponding report to be sent to
AMM Centre after it’s every action, containing assigned action success percentage and the list
of meters from which there is no management/parameterisation execution confirmation.
Management/parameterisation function initially has execution priority over automated regular
reading function. Setting of priorities is fully configurable.
2.2.3. COMMUNICATION FUNCTION
Concentrator is in communication terms realised as the device communicating with at least
two sides: on one side there are electricity meters located in the substation region where the
concentrator is also installed, while on the other side it communicates with AMM Centre. The
connection via both communication paths shall be bidirectional.
Communication with meters goes on via PLC (Power Line Carrier) communication.
Communication with AMM Centre goes on via cellular communication.
2.2.3.1.
COMMUNICATION WITH METERS
Concentrator is equipped with corresponding PLC modem enabling communication between
the concentrator and the meter.
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PLC modem on the concentrator should meet general requirements from point 1 and 2 of the
Technical Requirements for PLC Modem, as well as special requirements from point 2.1.
Communication with meters is realised to make automatic meter detection of newly-installed
meters mandatory. It goes without saying that no information should be sent to the
concentrator, so that it could be able to execute meter detection procedure.
Communication function with meters needs to support a fully automated repetition procedure
and finding of optimal communication path, except in case that this functionality is provided by
the protocol itself in the PLC modem.
If the concentrator realizes the repetition function itself, it memorizes communication route
(topology) towards every meter in its network and submits this information locally or remotely.
It goes without saying that PLC technology has to support operation with repeaters. Every
communication module on meters also has to operate as repeater, without any additional
device.
Communication function has to offer information on line quality such as signal/noise ratio,
attenuation and data loss statistics.
2.2.3.2.
COMMUNICATION WITH AMM CENTRE
Concentrator is equipped with the corresponding cellular modem (it also has GSM
functionality, due to possible implementation of the system with dynamic addressing of
cellular modem) enabling bidirectional communication of the concentrator and AMM Centre.
Cellular modem meets technical characteristics from Technical Requirements for cellular
modem.
Communication with AMM Centre is initiated in several ways:

According to automatic concentrator response sequence.

According to emergency request of the concentrator.

Upon the request from AMM Centre
Sequence of automatic concentrator reporting to AMM Centre is fully configurable, in terms of
the number of reports during the day and defining of reporting time.
2.2.4. DATA PROCESSING FUNCTION
Concentrator software, in addition to reading and data sending towards AMM Centre as
primary functions, also performs partial processing of collected data. Distributed data
processing would be introduced in this manner, as well as partial reduction of pressure on
transmission communication path to AMM Centre, and on AMM Centre servers.
Concentrator shall execute initial data processing collected up to that moment, in the manner
not affecting data reading, parameterisation and delivery.
Data processing function processes alarms and statuses of meters, electricity supply quality
logs, event logs, with the making of corresponding reports after finding corresponding alarms,
statuses and events to be sent to AMM Centre upon emergency request of the concentrator.
This function should minimally process events and alarms related to the disruption of meter
integrity (e.g. opening of termination cover), as well as attempt or disruption of data integrity
in the meters themselves (e.g. meter reprogramming attempt, etc).
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This function should also perform analysis of voltage circumstances on meters themselves,
since there are corresponding records in electricity delivery quality register recording voltage
drops below agreed voltage thresholds and supply interruptions. In this manner, this function
would indicate poor voltage circumstances of one or a group of customers and it would serve
as the reason to send crews into the field.
The concentrator also automatically informs AMM Centre on the detection of new meters in
the subordinate substation region.
2.2.5. DATA AND ACCESS PROTECTION FUNCTION
Access to data and functions of the concentrator has to be protected by authentication and
authorisation procedure.
Concentrator should have the possibility of creating access logs, both for local or remote access
through communication channels.
Concentrator has to support communication encryption with meters and with AMM Centre.
Communication security
The concentrator when communicating with meter must fully support DLMS Security as
described in the DLMS/COSEM Green Book, 7th ed., section 9.2 ( layer 7 of OSI model)
In addition, concentrator must encrypt data using Advanced Encryption Standard (AES) at least
at one of:
● Layer 2 (IEEE 802.15.4g or IEEE P1901.2)
● Layer 3 (IP Security [IPsec])
In this context, the concentrator must store and manage the keys in a secure way
The concentrator must raise an alarm if a meter's key is changed for more than x time per
hour. (x to be defined as changeable parameter)
2.2.6. ADMINISTRATION FUNCTION
Administration function may be done locally or remotely. It minimally has to provide:

Review and synchronisation of reading programmes/sequences with AMM Centre or a
laptop.

Review and synchronisation of management/parameterisation programmes/sequences
with AMM Centre or local laptop.

Review and change of programmes/sequences execution priorities.

Real time clock synchronisation.

Review of communication PLC route, if not implemented through PLC protocol itself in PLC
modems.

Review and change of concentrator reporting time and frequency parameters.
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
Review and change of communication parameters of concentrator.

Review and change of all other concentrator parameters.

Change of concentrator management software.
Concentrator needs to have data stored in its memory (in the form of logs) on changes of all of
its parameters and settings at least for the last 6 months.
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
AMM GATEWAY/ROUTER
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1. TECHNICAL CHARACTERISTICS AMM GATEWAY/ROUTER
CONSTRUCTION: AMM gateway/router is implemented without moving parts, in accordance
with standards for industrial computers (resistant to temperature, humidity, dust, vibrations,
electromagnetic radiation and other) adapted to operation conditions in substations (SS).
1.1.
SUPPLY:
AC: 1х230V or 3х230V, 50Hz, Optional, DC: 24V.
1.2.
MOUNTING:
vertical (wall mounted).
1.3.
OPERATION TEMPERATURE RANGE:
from -20 c to +55 c.
1.4.
MAXIMUM OPERATION HUMIDITY:
90%.
1.5.
ANTICIPATED OPERATION LIFE:
10 years.
1.6.
MAXIMUM HOUSING DIMENSIONS (WХLХH):
400х400х200 (mm).
1.7.
NUMBER OF SUPPORTED METERS (CAPACITY):
Min. 1000 meters.
1.8.
COMMUNICATION PORTS (MINIMUM):
1хLAN 10/100, RJ45.
COMMUNICATION PORTS/SLOTS FOR COMMUNICATION WITH GPRS or PLC/RF modem –
depending on GPRS or PLC modem implementation):

If GPRS, PLC or RF modem is executed as external device, corresponding communication
port for communication with respective modem;

GPRS, PLC and RF modems can also be implemented as slots in device
COMMUNICATION PORTS (Optional) - depending on communication module):

1хUSB (minimum 2.0)

1хRS-232 (Isolated)

1хRS-485 (Isolated)
1.9.
OTHER PORTS (OPTIONAL):
1xD-Sub (DB15) VGA
1.10. HARDWARE MONITORING:
watchdog timer, optional CPU and housing temperature monitoring.
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1.11. REAL TIME CLOCK
1.12. PROTECTION AGAINST DUST AND WATER:
IP 51 or better
2. AMM GATEWAY/ROUTER ROLE AND FUNCTIONS
2.1.
GATEWAY/ROUTER ROLE
Gateway/router is device in AMM and Smart grid networks network that enables end-to-end IP
communications in such system. In the case of AMM, this means that each meter is IP
addressable and AMM applications directly communicate with meters, without additional
functionality in the middle (concentrator) level.
Picture below show this architecture.
Figure 4 - General architecture of IPv6 based SG network
One of the main functions of the gateway/router is to adapt IP packets to PLC and RF
environment, which is not ideal for communications. This is done by segmenting/desegmenting
IP packets. Set of the protocols is developed to enable standardization of such communication
techniques. Picture below shows protocols stack in Smart Grid/AMM environment.
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Figure 5 - Implementation of current IP, SG and SM protocols
Gateway/router covers 6LoWPAN parts of the protocols and implement RPL: IPv6 Routing
Protocol for Low power and Lossy Networks. Since gateway/router is intended to be used in
Smart Grid networks, IPv6 is preferred protocol, although tunnelling of IPv6 trough IPv4 (for
example for GPRS implementations) is also possible.
2.2.
GATEWAY/ROUTER FUNCTIONS
There are two main functional areas of functions:
-
Routing between RF and PLC devices (meters) and IP network
-
Security
2.2.1. ROUTING
As previously stated, IPv6 and RPL protocol is used to communicate with PLC or RF based
meters.
At least one of requested protocols should be supported by router /gateway:
-
G3 (PLC OFDM)
-
PRIME (PLC OFDM)
-
1902.1 (RF and PLC OFDM)
2.2.2. SECURITY
Security is of crucial importance of router/gateway functionality. The main areas are: Security
-
Access control,
Router/should have possibility to identify itself using certificates (e.g. X.509) and also
pass certificates of meters connected to it to AAA server to enable their identifications
-
Data integrity, confidentiality and privacy,
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Data confidentiality uses encryption mechanisms available at various layers of the
communication stack. Router/gateway should encrypt data using Advanced Encryption
Standard (AES) at least:
-
Layer 2 (IEEE 802.15.4g or IEEE P1901.2)
-
Layer 3 (IP Security [IPsec])
-
Layer 4 (Datagram Transport Layer Settings [DTLS])
Threat detection and mitigation
-
Router should logically separate different functional elements that should never be
communicating with each other. For example, traffic originating from field technicians
should be logically separated from AMI and DA. Router should enable VPN technology
and firewalls for that purpose.
-
Also, event logs from firewalls, routers, network management systems (NMS) and headend systems, meters, and other endpoints need to be collected and passed on to a
security incident and event manager (SIEM) tool.
Device and platform integrity
-
Router should be tamper resistant using different mechanisms (locks, alarms etc…)
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
CELLULAR MODEM
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1
1.1.
BASIC CHARACTERISTICS OF CELLULAR MODEM
GPRS MOBILE STATION CLASS:
minimum B.
1.2.
GPRS MULTI-SLOT CLASS:
minimum 10.
1.3.
DUAL BAND GSM/GPRS:
900/1800 MHz.
1.4.
OPERATING TEMPERATURE RANGE:
from -25 c to +55 c.
1.5.
EXTERNAL ANTENNA CONNECTION:
Should be available for installation in particular locations (ex. SMA).
2
2.1
REQUIREMENTS FOR CELLULAR MODEM
GENERAL REQUIREMENTS FOR CELLULAR MODEM
Cellular modem mandatory has GSM functionality, due to possible system implementation
with dynamic addressing of cellular modem.
Cellular modem starts communication between the concentrator/router/meter to which it is
connected as external communication module, and AMM Centre.
Cellular modem has a built-in protection against calls from unwanted number. Numbers from
which communication is allowed are entered as a parameter into the modem. Modem needs
to have storage space for at least 5 numbers. There should be an option to turn off (remotely
or locally) this protection, as well as to change the list of permitted numbers.
Cellular modem is structured and executed to be resistant to overvoltages, as well as incorrect
meter connection to the network, in the same extent to which the meter is resistant to the
same disturbances (atmospheric discharge, irregular connection, neutral conductor
disconnection, one or two phases disconnection etc.).
During irregular network conditions, modem functioning is not conditioned.
After distortion is over and nominal operation regime is recovered modem continues regular
operation, with no intervention (reset, confirmation etc.)
Cellular modem must not logically depend on factory number of the meter, i.e. replacement of
old and installation of new modem is reduced to simple physical replacement, while software
in the concentrator/AMM Centre executes the logical replacement.
Cellular modem should automatically take serial number of the meter and then check into the
system under the same number.
Every cellular modem could be hardware reset if the modem was not active for a longer time.
This can be provided by the watchdog function inside cellular modem itself or can be initiated
from meter/concentrator.
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All communication parameters located in the modem at the moment of reset remain saved.
At the request of the users from AMM Centre, based on the tasks given in advance from AMM
Centre, or locally via portable computer, it is possible to read and perform the change of
configuration of cellular modem.
The function of reading and change of configuration of cellular modem, remote AMM Centre
upon the request of users, based on the tasks given in advance from AMM Centre, or locally via
portable computer is provided.
It is desirable that the modem supports operation in the advanced mobile network
technologies such as 3G, UMTS, LTE.
2.1.1. ADDITIONAL REQUIREMENTS OF CELLULAR MODEM FOR METERS
Size and connectors of cellular modem are such to enable its location into the space
anticipated for external communication module of the meter. This space may be anticipated
either below the terminal cover or below a special cover, but not below the metering part
cover (replacement of communication module is performed without state seal disruption).
All electrical connections of communication module with meter are connected according to
‘PLUG IN’ principle (connector to connector, with the possibility of the existence of the
connector with short cable/cables).
Cellular modem supply is realised in the meter or within cellular modem, so that it works in
entire voltage range of metering device to which is connected, i.e. from 57V(AC) and 100V(AC)
for indirect metering groups, up to 230 V(AC) for semi indirect, direct metering groups, threephase meters and single-phase meters.
Regardless of whether it is realized in the meter or within cellular modem, modem supply is
single-phase or three-phase, by which meter consumption and connected cellular
communication module does not exceed maximal allowed consumption of the meter.
Due to unification, it is desirable for one type of cellular modem to operate on all specified
types of meters.
Cellular modem in communication with the meter and AMM Centre uses communication
protocol defined according to DLMS/COSEM specification.
2.1.2. ADDITIONAL REQUIREMENTS
CONCENTRATOR/ROUTER
FOR
CELLULAR
MODEM
FOR
THE
Cellular modem is connected to the concentrator via communication port if it is not executed
as the internal module in the concentrator. Replacement of that internal module has to be
possible without the replacement of the concentrator itself.
Cellular modem supply also has to be executed autonomously or from the concentrator. If it is
executed as autonomously, it can be executed as single-phase or as three-phase or via DC
remote, which is in that case always delivered with the modem.
Antenna with extension cord of at least 5 m should also be delivered with this cellular modem.
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
PLC MODEM
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1.
GENERAL REQUIREMENTS FOR PLC MODEM
PLC modem serves for communication between meters to which it is connected as external
communication module, i.e. between the meters in which it is integrated and concentrator at
SS x/0.4 kV, also equipped with corresponding PLC modem.
All PLC modems located in the system shall optimally use the existing low voltage power grid
for communication, in a manner to ensure required communication performances.
Operating temperature range of all PLC modems in the system is from -25 C to +55 C.
PLC modem is structured and executed to be resistant to overvoltages, as well as incorrect
meter connection to the network, in the same extent to which the meter is resistant to the
same disturbances (atmospheric discharge, irregular connection, neutral conductor
disconnection, one or two phases disconnection etc.). During irregular network conditions,
modem functioning is not conditioned.
After distortion is over and nominal operation regime is recovered modem continues regular
operation, with no intervention (reset, confirmation etc.)
Cellular modem in communication with the meter and AMM Centre uses communication
protocol defined according to DLMS/COSEM specification.
Every PLC modem is equipped with the watchdog function in charge to execute hardware reset
of PLC modem if the modem was not active for a longer time (this time represents a
parameter). All communication parameters located in the modem at the moment of reset
remain saved.
1.1
SPECIAL REQUIREMENTS OF PLC MODEM FOR THE CONCENTRATOR/ROUTER
PLC modem for the concentrator/router has to be completely three-phased.
PLC modem for the concentrator may be external and internal. In both cases its modularity is
implied.
If PLC modem is connected to the concentrator as external communication module it is
connected to specific port on the concentrator. In addition to this, it needs to have
corresponding connectors for direct connection of all three voltage phases so that PLC
communication may be executed continuously on all phases.
1.2
SPECIAL REQUIREMENTS OF PLC MODEM FOR METERS
PLC modem for meters may be as separate external module, installed below the meter
terminal cover, or below the housing cover, or inside meter housing (meter with integrated
PLC modem.
Preferably, the PLC modem shall be implemented in such a manner as to enable
communication via RF, and, in the case that the PLC communication cannot be realized, or in
the case where it is necessary to establish an interface between the RF module and the PLC.
The manner of executing PLC modem (external or integrated) depends on the request of
electricity distributor.
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1.1.1 EXTERNAL PLC MODEM
Size and connectors of external PLC modem are such to enable its location into the space
anticipated for external communication module of the meter. This space may be anticipated
either below the terminal cover or below a special cover, but not below the metering part
cover (replacement of communication module is performed without state seal disruption).
External PLC modem is connected to meter via special electrical interface on the meter.
All electrical connections of external PLC modem with the meter are realized according to
“PLUG IN” principle (connector to connector with possibility to have short cable/cables).
External PLC modem for meters use at least one phase for communication.
Supply of external PLC modem is realized either from meter or within the PLC modem itself.
Regardless of whether it was realized from the meter or within PLC modem, modem supply is
at least singe phased, whereby total meter and communication module consumption does not
exceed the maximum permitted consumption of that meter type.
Due to unification, it is desirable for one type of PLC modem to operate on the following meter
types: single-phase, three-phase, direct and semi-indirect metering groups.
PLC modem should not logically depend on the factory number of the meter, i.e. replacement
of old and installation of new modem is reduced to simple physical replacement, while the
concentrator/AMM Centre software executes the logical replacement.
It is desirable for PLC modem to automatically transport the serial number of the meter, and to
sign in to the system with the same number.
1.1.2 INTEGRATED PLC MODEM
PLC modem is integrated within the housing.
Integrated PLC modem for meter uses at least one phase for communication.
As integrated PLC modem is an integral part of the meter, total consumption of meter and
integrated communication modem does not exceed the maximum permitted consumption of
this type of meter.
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2.
BASIC TECHNICAL CHARACTERISTICS OF OFDM PLC MODEM
2.1
GENERAL REQUIREMENTS FOR OFDM PLC COMMUNICATION
OFDM PLC communication shall meet the following requirements:
1. PLC communication should be in accordance with at least one of the following documents:
•
PRIME Specification1
•
G3 -PLC Specification2
•
IEEE1901.23
2. PLC communications shall fully support the IP protocol, preferably IPv6 protocol.
3. PLC communication on application level should be according to DLMS/COSEM
specification.
2.1.1 SPECIAL REQUIREMENTS FOR AN INTEGRATED OFDM PLC MODEM FOR METERS
Preferably, the PLC modems are implemented in a way which shall support G3, PRIME, and
IEEE1901.2 standards by simple firmware replacement.
1
http://www.prime-alliance.org/?page_id=769
http://www.g3-plc.com/content/g3-plc-specifications
3
http://standards.ieee.org/findstds/standard/1901.2-2013.html
2
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
RADIO MODEM
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1.
GENERAL REQUIREMENTS FOR A RADIO MODEM
Radio modem is used for communication between the meter to which is connected as an
external communication module, or between the meter in which it is integrated and the
concentrator at SS x/0.4 kV, also equipped with the appropriate radio modem.
Operating temperature range of radio modems in the system is from -25°C to +55°C.
The radio shall be designed and manufactured to meet the surge voltage resistance, as well as
improper connection of the meter to the network, possessing the same resistance to such
disturbances as the meter (e.g., atmospheric discharge, irregular connection, neutral
conductor termination prior to the meter, loss of one or two phases, etc.). During irregular
statuses of the network, modem operation shall not be influenced.
After disturbance termination and the establishment of a nominal operation mode, the
modem shall continue to operate properly without the need for intervention of any kind (reset,
certificates, etc.).
Radio modem and concentrator shall communicate with the meter via a communication
protocol defined by the DLMS/COSEM specification.
Each radio modem shall be equipped with a watchdog function responsible for the radio
modem hardware reset in the case of long-term modem inactivity. All communication
parameters stored in the modem at the time of reset shall be retained.
1.1
SPECIAL REQUIREMENTS OF RADIO MODEM FOR THE CONCENTRATOR/ROUTER
Radio modem for the concentrator may be external and internal. In both cases its modularity is
implied.
If the radio modem is connected to the concentrator as external communication module it is
connected to specific port on the concentrator.
1.2
SPECIAL REQUIREMENTS OF A RADIO MODEM FOR METERS
Radio modem for meters may be as separate external module, installed below the meter
terminal cover, or below the housing cover, or inside meter housing (meter with integrated
radio modem.
Preferably, the radio modem shall be implemented in such a manner as to enable PLC
communication, and, in the case that the PLC communication cannot be realized, or in the case
where it is necessary to establish an interface between the RF module and the PLC.
Installation of a radio modem (external or integrated) depends on the request of electricity
distributor.
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1.2.1 EXTERNAL RADIO MODEM
Size and connectors of an external radio modem are such to enable its location into the space
anticipated for external communication module of the meter. This space may be anticipated
either below the terminal cover or below a special cover, but not below the metering part
cover (replacement of communication module is performed without state seal disruption).
External radio modem is connected to meter via special electrical interface on the meter.
All electrical connections of external radio modem with the meter are realized according to
“PLUG IN” principle (connector to connector with possibility to have short cable/cables).
Supply of external radio modem is realized either from meter or within the radio modem itself.
Regardless of whether it was realized from the meter or within a radio modem, modem supply
is at least singe phased, whereby total meter and communication module consumption does
not exceed the maximum permitted consumption of that meter type.
Due to unification, it is desirable for one type of radio modem to operate both on the singlephase and three-phase meters. Radio modem should not logically depend on the factory
number of the meter, i.e. replacement of old and installation of new modem is reduced to
simple physical replacement, while the concentrator/AMM Centre software executes the
logical replacement.
It is desirable for a radio modem to automatically transport the serial number of the meter,
and to sign in to the system with the same number.
1.2.2 INTEGRATED RADIO MODEM
Radio modem is integrated within the housing.
As integrated radio modem is an integral part of the meter, total consumption of meter and
integrated communication modem does not exceed the maximum permitted consumption of
this type of meter.
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2.
BASIC TECHNICAL CHARACTERISTICS OF A RADIO MODEM
2.1
2.2
2.3
2.4
6LoWPAN - IPv6 over Low power Wireless Personal Area Networks
Mesh topology
OPERATING TEMPERATURE RANGE: -25 °C to +55 °C.
EXTERNAL ANTENNA TERMINAL: should be available for installation in particular
locations (e.g. SMA).
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FUNCTIONAL REQUIREMENTS FOR SWITCHING MODULE
(BISTABLE SWITCH)
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1.
SWITCHING MODULE (BISTABLE SWITCH)
Switching module for consumption management may be realized within the meter housing
(meter with integrated switch), or as a separate external module, installed below the terminal
cover of the meter or below the meter.
It is realized in such a way that, in case when it is possible to change the state of the meter by
external action, meter mandatory detects external action and records it in the Event Log.
Electrical and mechanical specifications of switching module are in accordance with SRPS EN
62055-31 UC3, where maximum switching current is equal to the maximum meter current or
higher.
Switching module needs to perform at least 10000 position changes without the need for any
maintenance.
Disconnection is always performed in all phases simultaneously. Neutral phase is never
disconnected.
The manner of execution of switching module (integrated or external) depends on the request
of electricity distributor or is it up to the meter manufacturer when not defined.
1.1.
INTEGRATED SWITCHING MODULE (BISTABLE SWITCH)
Integrated switching module is executed as bistable switch, i.e. it has two stabile states, while
the change of the state is performed only as the result of command for
disconnection/connection and it is executed as an integral part of the meter, while the
requirements from point 1.1.8 are met.
Meter manufacturer shall submit corresponding document (attests) proving that it has met
indicated standards for the switching module.
1.2.
EXTERNAL SWITCHING MODULE (BISTABLE SWITCH)
External switching module is executed as bistable switch, i.e. it has two stabile states, while
the change of the state is performed only as the result of command for
disconnection/connection and it is installed as an extended terminal below the terminal cover,
or as a separate module below the meter, whereby the requirements under item 1.1.8
(dimension h4) and item 1.1.9 (terminal) of technical specifications of meter are met.
Meter manufacturer shall submit corresponding document (attests) proving that it has met
indicated standards for the switching module.
When distributor wants meter with external switching module, meter functions should not be
conditioned by the connection of external switching module. Only exception are options for
meter management- remote disconnection/connection of customer and limitation of
maximum permitted power.
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
SINGLE-PHASE AND THREE-PHASE METERS OF ACTIVE ELECTRICAL
ENERGY
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
SINGLE-PHASE METERS OF ACTIVE ELECTRICAL ENERGY
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SINGLE-PHASE METER WITH CONSUMPTION MANAGEMENT
FUNCTION
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1. TECHNICAL CHARACTERISTICS OF SINGLE-PHASE ACTIVE ELECTRICITY METER
FOR DIRECT CONNECTION (SINGLE-PHASE METER WITH CONSUMPTION
MANAGEMENT FUNCTION)
1.1. GENERAL TECHNICAL CHARACTERISTICS
1.1.1. OPERATION MODE - CONSTRUCTION:
Meter shall be electronic (static) for single-phase two-wire direct connection.
1.1.2. RATED (REFERENCE) VOLTAGE:
230 V (-20%, +15%).
1.1.3. RATED CURRENT:
5 (≥ 60) А.
1.1.4. RATED FREQUENCY:
50 Hz.
1.1.5. AUXILIARY CONSUMPTION OF THE METER:
Average mean power of voltage circuit under reference voltage, reference temperature of 23°C
and reference frequency shall not exceed the value of 5 W and 25 VA (SRPS EN 62053-61
standard).
Auxiliary consumption of the meter current circuit under basic current, reference frequency
and reference temperature of 23°C shall not exceed the value of 2.5 VA for the meters of class
2, i.e. 4 VA for the meter of class 1 (SRPS EN 62053-61 standard).
1.1.6. MINIMUM ACCURACY CLASS:
For active energy and power
SRPS EN 62053-21 standard
2
SRPS EN 50470-3 standard
A
1.1.7. ANTICIPATED OPERATION LIFE:
minimum 15 years.
1.1.8. SIZE (HOUSING, TERMINAL AND COVERS):
Dimensions (main measures) have to be done according to Figure 1.
All measures are given in mm.
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b1
b2
C
h1
h2
h3
h44
105± 1
≤ 135
≤ 140
≤ 155
≤ 171
≤ 240
≥40
Figure 6 - Meter draft of principle
Dimension h4 has to fulfil the indicated condition for all conductor introductions, regardless of
the shape of the cover and it is measured from the lowest part of the terminal (end of the
switching module when it is installed) to lower part of its cover vertically below the conductor
introductions on terminal.
1.1.9. TERMINAL
In terminal, meter lines for direct connection are coupled with clamps with copper rail and one
or two screws, or capsular clamps according to the standard SRPS EN 62052 – 11.
Each clamp screw shall have the size and corresponding travel to fully and reliably fasten the
conductor and secure reliable and secure mechanical and electrical connection of current rail
with the conductor, without additional interventions on the conductor (bending, cross-section
increase, etc.).
Auxiliary and control terminals are executed under the ‘PLUG IN’ principle or through
corresponding clamps.
4
Procuring Entity retains the right to, in accordance with its needs, also define other values for
minimum dimension of h4
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1.1.10. DISPLAY
Metered values and characteristic codes are represented on LC display. Presentation of
metered values and characteristic codes shall be easily readable even in badly lit environment,
as well as under direct lighting.
Display may be executed as segment, “dot matrix” and other, when the data presentation is
provided in accordance with the request.
LC display operates in automatic and manual display regime. Transition between automatic
and manual display operation regime is executed in a simple manner, e.g. by pressing the
key/keys. Default display regime is automatic, to which the display returns from manual display
after corresponding idle period (keys are not pressed).
Under automatic regime, values of metered and registered values are shown cyclically. Initially,
only accounting elements and current date and time are cyclically changed on meter display
while the display period is between 5 and 20 sec.
Under manual display regime (value display regime based on selection), access should be
enabled to the standard data menu (accounting data, current power, voltages, currents).
If display elements are blinking, this shall have the frequency of about 1 Hz.
Presentation of metered values covers minimum 8 (eight) digits, while there is minimum 6 (six)
whole digits, and minimum 2(two) decimal digits.
Display of maximum power (maxigraph) has minimum 5 (five) digits, while at least 2 (two)
digits are used for display of decimal digits, and the remaining for whole digits.
Minimum 5 (five) digits are anticipated for display of characteristic codes.
Display of metered values and characteristic codes shall be clearly separated from one another.
Characteristic codes are in accordance with SRPS EN 62056-61 (OBIS).
Figures for value display shall at least be:

For metered values
7 mm

For characteristic codes
5 mm
The corresponding symbols shall be turned off (“fade out”) in the absence of individual phase
voltages.
The display shall at least show the following information:
• Value of the measured values,
• Measured values unit,
• Typical code in accordance with EN 62056-61 (OBIS),
• Phase presence indication,
• Current tariff indication.
Access to accounting elements for previous accounting period (at least 3 (three) periods) is
realised in a very simple manner, grouping the values according to accounting period,
chronologically, starting from the last accounting period towards previous ones.
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1.1.11. KEYS
Meter has at least one easily accessible key for menu scrolling. Keys enable menu scrolling
functions, selection of desired menu, return to the previous menu level, return to automatic
operation regime, as well as reconnection of bistable switch under meter operation regime
‘conditional switch reclosing’.
1.1.12. NUMBER OF TARIFFS
Meter has the possibility of storing metered values in min. 4 (four) tariff registers.
1.1.13. IMPULSE (TEST) TERMINALS
Optical impulse output (via LE diode) is mandatory.
In case that in meter is realised electrical impulse output, it is with galvanic insulation, passive
and executed on a corresponding terminal connection.
1.1.14. CHARACTERISTICS OF IMPULSE TERMINALS
Characteristics of impulse terminals of the meter are realised according to the standard SRPS
EN 62053 – 31 i.e. SRPS EN 62052 – 11.
1.1.15. METER CONSTANT
Meter constant is expressed by the number of impulses per energy unit (imp/kWh), amounting
to:
Optical
–
1000 imp/kWh
If the meter has one electrical and one impulse terminal, the constant shall equal:
Electrical
–
500 imp/kWh
1.1.16. TEMPERATURE RANGE AND CLIMATIC CONDITIONS
Meter functions under the standard temperature range for climatic area in which JP EPS
customers are located.
Operating temperature is within the range from – 25°C to + 55°C.
Meter functions under the conditions of relative humidity from 95% in the period of 24 hours.
1.2
OTHER TECHNICAL CHARACTERISTICS
1.2.1. METER HOUSING – MATERIALS, SHAPE AND FORM OF MEASURE
All meter housing parts, including the terminal shall be made of material resistant to
mechanical impact, humidity, UV radiation and self-quenching characteristics in accordance
with the requirements indicated by SRPS EN 62052–11 standard.
Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN
62052 – 11 standard).
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Meters shall use the space to the best possible extent in the course of transport and storage
and they shall also be stored as compact whole. Buckles and openings serving for meter
fastening to the base of installation cubicles shall be manufactured so that the meter can be
fastened well after mounting.
Meter housing should contain space for communication module installation (point 2.2.1). This
space shall be realised not to overlap with the space anticipated for other purposes (meter
wiring, signalling/tariff control terminals, etc.). This space shall be anticipated either under the
terminal cover or below a special cover, but not below metering part cover (replacement of
communication module shall be done without affecting the state seal).
Total dimensions (main measures) of the meter with installed communication module shall be
done in accordance with dimensions from point 1.1.8.
1.2.2. IRREGULAR CONNECTION
Conductor ‘input-output’ connection sequence, as well as crossing of phase and neutral
conductor shall not have an impact on accuracy and regular metering.
1.2.3. ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS
Meter shall meet norms required by regulations from this field under SRPS EN 62052 – 11 and
SRPS EN 62053 – 21 standards, i.e. SRPS EN 50470-1 and SRPS EN 50470-3 (for meters
according to MID directive).
1.2.4. METER LABEL
Basic meter data, given in the following table (items 1 – 11) shall completely be labelled on the
meter in accordance with SRPS EN 62052 – 11 standard, i.e. SRPS EN 50470-1 (for meters
according to MID directive).
In addition to these data, meter shall have the following data from the table (items 12 – 15).
Data shall be inerasable, and located on the front side of the meter.
Bar code label with the type of meter from position 16 is optional and it can be included in the
label in the form of bar code from position 15.
Connection diagram with terminal labels (item 17 from the following table) may be located on
some of the covers.
№
Type of label
1.
Serial number
2.
Name and brand of the manufacturer
3.
Type label
4.
Rated accuracy class
5.
Year of manufacture
6.
Type approval label (official label of the competent authority)
7.
Reference voltage
8.
Rated frequency
9.
Basic and maximum current
10.
Constants of output impulses
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11.
Class II insulation level label
12.
Communication protocol
13.
Accounting value code label shown on LC display
14.
Protection class label
15.
Label in the form of a barcode with the meter serial number. Serial number in the
barcode form shall be the same as the serial number under № 1 of this table, which is
included with no ambiguity.
16.
Label in the form of a barcode with the meter type (Type label in the barcode form
shall be the same as the type label under № 3 of this table, i.e. mark the type of meter
in the same way.
17.
Connection diagram with labels (numbers) of contact points
1.2.5. SEALING
Meter is constructed to provide a corresponding protection level against dust and humidity
penetration. According to SRPS IEC 60529 meters are manufactured to provide the protection
level of at least IP 51.
2. METER FUNCTIONS
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS
2.1.1. ACTIVE ENERGY
The meter measures, registers and displays active energy within the rated accuracy class.
Meter measures total active energy (register labels 15.8.x in accordance with SRPS EN 6205661 (OBIS)).
2.1.2. MAXIMUM POWER
The meter measures, registers and displays maximum mean active power under all tariffs and
(register mark 1.6.x in accordance with SRPS EN 62056-61 (OBIS)). Power integration period is
initially 15 minutes. This value is programmable and display of this value is easily accessible in
manual display operating mode and remotely. Manual maxigraph reset is not possible.
2.1.3. INSTANTANEOUS ACTIVE POWER
The meter measures and displays on request current active power on LC display.
2.1.4. LOAD PROFILES OF METERED AND REGISTERED VALUES
Meter shall have the possibility to record at least 2 profiles. Sampling period inside each profile
can be independently set.
Change of all recording and registering parameters of metering and registered values may be
done locally (via optical port) and remotely (via external communication).
Initially, meter records the following profiles:
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2.1.4.1 LOAD PROFILE
Meter records and registers the load profile (mean active power value). Integration period is
initially 15 minutes. In the load profile, together with corresponding block of registered mean
active power value, the data which clearly defines when the block is recorded is also
memorised.
Total capacity for load profile storage shall enable memorising of at least 4320 power metering
records.
2.1.4.2 PROFILE OF HOURLY REGISTER VALUES
Meter records and registers values of all accounting registers each 60 minutes. Hourly value
recording and registering time is initially at the full hour.
Hourly consumption values can be displayed absolutely (register values) or relatively (register
increments).
Memory for the storage of profiles of hourly values of meter registers and statuses has the
capacity of at least 24 entries, under FIFO principle.
2.1.5. EVENT LOG
Meter memorises events related to metering, adjustment and handling into the special
memory registers (organised under FIFO principle). A record in the memory is generated for
each event memorising the type of event, time stamp and meter status when the event
occurred.
Each of those memory registers is separate Event log for the type of event (events related to
the electricity quality, metering integrity, consumption management etc.) It is possible to
integrate events into one unique Event Log.
Meter registers at least 200 events.
Event coding as well as the type of events entered in the Event Log should be organised under
the recommendations given in IDIS or equivalent specification.
Event Log is not erasable via any external intervention.
2.1.6. VOLTAGE METERING
Meter measures and displays effective voltage value on request.
2.1.7. CURRENT METERING
Meter measures and displays effective current value on request.
2.1.8. PHASE PRESENCE
The meter shall display the phase voltage presence on the connected conductor. The phase
display function provides information about phase presence.
2.1.9. TIME AND DATE
Meter displays time and date from internal switching clock.
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2.1.10. INTERNAL CLOCK
Accuracy and other features of internal clock shall be realised in accordance with SRPS EN
62052-21 and SRPS EN 62054-21 standards. Setting and adjustment of time and other internal
clock features shall be realised in the same manner as in the case of energy value
parameterisation and via the same communication ports.
Internal clock supply shall be realised as basic and stand-by. Basic supply comes from the
power grid.
Stand-by supply provides data storing of real time.
Meter possesses real time calendar.
2.1.11. STANDBY SUPPLY
Stand-by supply of internal clock shall be realised via battery or super capacitor, where the
super capacitor provides data storing for minimum 7 days.
Battery operating life is minimum 10 years.
If battery operating life is shorter than the seal validity period of the Measures and Precious
Metals Directorate, battery change has to be realized in such a way not to require removal of
the Measures and Precious Metals Directorate seal. In this case battery access shall be
protected by a special seal (electricity distributor seal).
Battery change shall be realised without the loss of meter data during the time anticipated for
battery change. During battery change process, clock on the display is not conditioned.
In addition to internal clock, battery/ super capacitor may supply a corresponding part of
meter memory: e.g. part of the memory for the storage of communication parameters, etc.,
but not master or accounting data.
Battery state testing function shall be realised inside the meter. If irregular battery state is
detected (failure, if the battery is empty or if it does not exist), the function of clear display of
irregular state is realized.
2.1.12. DAYLIGHT SAVING TIME – DST
Meter shall possess automatic daylight saving time function (Daylight saving time – DST) and
according to the calendar of Central European Time – CET.
2.1.13. CURRENT TARIFF
Meter shall have continuous display of current active tariff register, regardless of its display
mode.
2.1.14. LOCAL TARIFF REGISTER MANAGEMENT
Local tariff register management shall be realised via internal clock.
Tariff programme shall anticipate the possibility of defining four different seasons, at least
three different days within the season and two different days for holidays.
Tariffs may be changed during one day for at least eight times.
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2.1.15. METERING INTEGRITY
Meters shall have metering integrity violation (terminal cover opening, meter housing opening,
parameter change, strong magnetic field impact on the meter, etc.) recording and signalling
function.
If the meter cover is sealed in such a way that it cannot be opened without a permanent,
clearly visible and easily visible deformation or damage to the meter or its parts (“sealed for
life”), meter opening recording function is not necessary.
For each of the indicated events, Event Log shall make a record with a time stamp when this
event occurred.
2.1.15.1 DETECTION OF STRONG MAGNETIC FIELD
Meter shall have realised strong magnetic field detection function which can influence its
regular operation.
Upon detecting magnetic field that can influence its regular operation, time and date of
detection of magnetic field is recorded in the Event Log.
This function shall be realised upon the request of electricity distributor.
2.1.16. DATA STABILITY AND MEMORISING
Master data about the meter (year of manufacture, type label and serial number) shall not be
changeable. In addition to this, electricity data as well as data on maximum 15-minute power
shall not be changeable. These data are located in the part of permanent meter memory and
their integrity is not dependent on period when meter was not supplied (basic and stand-by).
All other data may be, via communication module (communicator) and IR port, altered
according to the current tariff system and upon the order of authorised persons.
Meter shall record and register (memorise) states of all tariff registers during the accounting
period (first and last day of the month) and at an exactly defined moment (programmable
locally or remotely).
2.1.17. COUNTDOWN
Meter shall have the reduction blockade of achieved individual register values.
2.1.18. DATA STORAGE PERIOD
Accounting data (active electricity and maximum mean power with date and time of
achievement, registered according to tariffs) shall be stored for at least 12 last accounting
periods (usually 12 months). After the new cycle starts, space shall be provided for the new
memory block, with the deletion of the last (the oldest) in the sequence of registers.
Total registered electricity cannot be deleted.
2.2.
ADDITIONAL FUNCTIONS
2.2.1. COMMUNICATION WITH THE METER
Meter shall have communication between the meter and different devices (hand terminals,
communication modules, registers, data concentrators, etc.). Communication shall be
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executed via interfaces given in the following table, with the usage of data model, application
layer and identification structure according to DLMS/COSEM.
Meter shall have DLMS/COSEM certificate issued based on the verification with the latest
version of testing software (at least version 2.0).
Electrical interface is galvanically insulated from the metering part of the meter.
Communication part of the meter is executed to enable communication with the meter via all
meter interfaces, without impact on the measuring part of the meter.
External communication is executed via special communication module, situated in the
corresponding space (point 1.2.1).
All electrical connections of communication module with the meter is achieved under PLUG IN
principle (connector to connector or connector on a short cable / cables) , whereas the total
consumption of the meter and communication module does not exceed the requirement from
point 1.1.5.
Communication module shall not logically depend from the meter, i.e. replacement of old and
installation of new communication module is reduced to simple physical replacement, while
software in the concentrator/AMM Centre performs logic replacement.
Communication module uses the protocol defined according to DLMS/COSEM.
The meter shall have the following interfaces:
1. Optical Interface: Infrared (IR) port, physical characteristics in accordance with SRPS EN
62056-21.
2. Electrical interface № 1, which is used to interface with the remote reading
communication module (cellular modem, PLC modem, radio modem etc.)
The implemented communication protocol - DLMS/COSEM.
3. Electrical interface no.2 used for management of switching module for remote
disconnection/connection of customers, in case that it is realized by the external switch
module (item 1.2 of the Chapter Functional Requirements for switching module (bistable
switch)).
In case of integrated switching module electrical interface no 2 is not mandatory.
Implemented at the request of the electricity distributor.
4. Electrical interface № 3, which is used to connect the meter with HAN (Home Area
Network) modem/module (depending on the design).
Implemented at the request of the electricity distributor.
5. Electrical interface № 4, which is used to connect the meter and other measuring devices
that may be located on the electricity customer side (Section 2.7).
It may be realized through existing electrical interface in a way that does not interfere with
communication with other modules.
Implemented at the request of the electricity distributor.
Electrical interface № 2, 3 and 4, as well as other additional dedicated interfaces may be
realised:


via separate connector on the meter (auxiliary contacts) or
via separate connector on communication module for remote reading (cellular modem,
PLC modem, radio modem, etc.), or
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
via appropriate module for the extension of external interfaces. In that case the
indicated module shall always be delivered with the meter.
2.2.1.1 CELLULAR COMMUNICATION
At the request of Electric distribution network operator, the meter may be equipped with
cellular communication module which is connected to the meter via specific electrical
interface, whereas the requests from items 1.1.8 (dimensions) and 1.2.1 (housing) are fulfilled.
Characteristics of cellular communication module are given in the Chapter Technical
Characteristics and functional requests for cellular modem, items 1, 2.1 and 2.1.1.
2.2.1.2 PLC COMMUNICATION
At the request of Electric distribution network operator, the meter may be equipped with PLC
communication module which may be, in accordance with the Electric distribution network
operator’s request, installed as:


External PLC communication modem, which is connected to the meter via specific
electrical interface. Characteristics of external PLC communication modem are given in
the Chapter Technical Characteristics and functional requests for PLC modem, items 1,
2 and 2.2.1.
Integrated PLC communication modem, which is installed inside the meter housing.
Characteristics of integrated PLC communication modem are given in the Chapter
Technical Characteristics and functional requests for PLC modem, items 1, 2 and 2.2.2.
In that case, electrical interface № 1 is not mandatory.
2.2.1.3 RADIO COMMUNICATION
At the request of Electric distribution network operator, the meter may be equipped with radio
communication module which may be, in accordance with the Electric distribution network
operator’s request, installed as:


External radio communication modem, which is connected to the meter via specific
electrical interface. Characteristics of external radio communication modem are given
in the Chapter Technical Characteristics and functional requests for radio modem, items
1, 2 and 2.2.1.
Integrated radio communication modem, which is installed inside the meter housing.
Characteristics of integrated radio communication modem are given in the Chapter
Technical Characteristics and functional requests for radio modem, items 1, 2 and 2.2.2.
In that case, electrical interface № 1 is not mandatory.
2.3.
CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT
Meter has the possibility of consumption management, by means of a special switching
module (bistable switch) executing remote disconnection/connection of customers and
limiting of permitted maximum active power.
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That function is realized at the request of electricity distributor.
Switching module may be realized as:

Integrated switching module (bistable switch). Characteristics of integrated switching
module are given in the item 1.1 of the Chapter Functional Requirements for switching
module (bistable switch).

External switching module (bistable switch). Characteristics of external switching
module are given in the item 1.2 of the Chapter Functional Requirements for switching
module (bistable switch).
In the case of meter with external switching module, meter functions are not conditioned by
connecting external switching module. Exceptions are only the options of consumption
management-remote disconnection/connection of customers and limiting of permitted
maximum power.
In the course of meter parameterisation it should be possible to define the category (group) to
which the meter belongs, in terms of consumption management function realisation in the
case of simultaneous disconnection/connection of switching modules with the larger number
of users.
Switch reclosing is programmable and there are two switch operation regimes:
2.3.1. “CONDITIONAL SWITCH RECLOSING”
After receiving instructions for reconnection/expiry of penalty time, it is necessary to confirm
switch reclosing locally via key/keys. The meter (ex. display) shows a corresponding notification
that the condition necessary for connection has been achieved, and that key confirmation is
expected.
2.3.2. “AUTOMATIC SWITCH RECLOSING”
After receiving instructions for reconnection/expiry of penalty time, the switch is automatically
reconnected.
2.3.3. CONTROL OUTPUT
Meter has at least one control output (independent relay) for signalling of current tariff.
Control output is galvanically separated as a relay, with minimum technical characteristics
230V, 2A, whose connections are executed on meter terminal.
Activation of this output is primarily done automatically in accordance with the current tariff
programme (low tariff signalling). However, the manner of activation of control output can be
programmed.
2.3.4 LIMITING OF PERMITTED MAXIMUM POWER
Meter has software possibility of limiting power with which the customer can load the power
network, by entering limiting value (power limit), time tolerance period of such load (overload
time) and penalty time of customer disconnection with corresponding registers in the meter
memory. Meter has the possibility of entering two power limit levels – one value for ‘normal’
level, in accordance with the contracted value, and other, lower value, activated upon AMM
Centre command, in case of electricity reductions within the system.
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Values of power limit, permitted overload time and penalty time may be set remotely and
locally.
Power limit is the value of contracted active power maximum contracted between the
customer and electricity distributor.
Permitted overload time is the contracted time contracted between the customer and
electricity distributor and it defines minimum power limit exceeding time after which switching
module is activated.
Penalty time is the contracted time between the customer and electricity distributor and it
defines the time after customer disconnection due to power limit exceedence, during which it
is not possible to reconnect the customer (programmable).
When the meter detects power limit exceedence, after the permitted overload time has
expired, the customer will be disconnected from the network.
After the expiry of ‘penalty time’ reconnection is done in accordance with active switch
operation regime (conditional or automatic switch reconnection).
It is desirable to have the mechanism within AMI system or the meter itself that would inform
the customer on the status of management consumption (for example that the limit is
exceeded and the customer shall be disconnected from the network, i.e. there was a
disconnection since the limit has been exceeded, i.e. that the conditions for reconnection were
met etc.).
Special Event Log records entries for at least 10 previous disconnections, i.e. reconnections of
the switching module, with the time stamp and switching module status.
2.3.5 REMOTE DISCONNECTION/CONNECTION OF THE CUSTOMER (ELECTRICITY SUPPLY
INTERRUPTION)
Switching module for remote disconnection/connection of the customer may be activated via
AMM Centre command (unsettled financial liabilities of the customer against electricity
distributor).
Only phase disconnection shall be done during remote disconnection, while reconnection is
executed in accordance with active switch operation regime (conditional or automatic switch
closing).
Special Event Log records entries for at least 10 previous disconnections, i.e. reconnections of
the switching module, with the time stamp and switching module status.
2.4.
ELECTRICITY METERING QUALITY
2.4.1. UNDER AND OVER VOLTAGES
Meter registers under-voltage/overvoltage occurrence event and termination of the latter.
Events are entered into a special event log (electricity quality log) with the date/time of event,
with the capacity of at least 10 entries.
Under-voltage and overvoltage thresholds may be adjusted. Initially: under-voltage = -20% Un,
overvoltage = +15% Un.
2.4.2. SUPPLY INTERRUPTION REGISTRATION
Meter registers supply interruptions in accordance with SRPS ЕN 50160.
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Meter registers the number and total duration of short-term supply interruptions (supply
interruptions shorter than 3 minutes) and long-term supply interruptions (supply interruptions
longer than 3 minutes), recorded in the electricity quality log. Meter records corresponding
codes into electricity quality log for each supply interruption.
2.5.
METER FIRMWARE UPGRADE
Meter shall support firmware upgrade option in accordance with the Directive WELMEC 7.2,
publication 5 or newer, Firmware Guideline (Directive 2004/22/EC of the European Parliament
and of the Council on measuring instruments 2004/22/EC).
Firmware upgrade option in the meter is realised not to alter in any way the metering
characteristics (metrology) of the meter, data memorised in the meter (metering data,
statuses, etc.), configuration parameters or operational parameters of the meter – all these
data remain unchanged even after firmware upgrade.
Meter firmware upgrade, local or remote, shall be executed in accordance with the current
legal regulations.
New meter firmware will be submitted to the meter with date/time parameter of new
firmware application (i.e. meter will memorise the new software but it will start executing it
when the defined parameter is achieved).
Meter will after receiving the new firmware verify its compatibility in case that verification
does not end positively, new firmware will not be executed.
Meter will record time and data of new firmware receipt in the Event Log, as well as time and
date of new firmware application.
Meter will during application of new firmware perform self-check. Results of this self-check will
be available on the meter (locally and remotely).
New firmware upgrade in the meter may be done locally or remotely.
2.6.
SELF-CHECK
Meter should have a self-check function implemented. The purpose of this function is to verify
proper execution of basic meter functions.
Meter performs self-check during network connection, i.e. after every supply restoration
(power – up).
Self – check verifies the following:
 Memory integrity of the meter
 Meter statuses and alarms
In addition to these, the following checks may be performed: connection check towards
external communication module, voltage presence, etc.
Errors discovered by Self-check procedure are entered into the Event Log.
2.7.
MULTI-UTILITY METERING
Meter possesses an electrical interface for connection of other metering devices located with
the electricity customer. In general, these include, water meter, gas meter and heat meter.
Meter minimally possesses memory registers for accounting data storage for each of the
above-specified meters. Storage capacity is 12 accounting periods for each of the meters
organised under FIFO principle.
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In its firmware, meter has corresponding algorithms for reading of the indicated metering
devices and storage of data read in this way.
This function is subject to additional request of electricity distributer.
2.8.
DATA SECURITY
Local security
For the purpose of data security, locally accessed data have to be protected by access right
verification with at least two access levels:

The first protection level is protection against unauthorised data reading via optical
port and it is realised through software package installed on the handheld
device/laptop, presenting itself to the meter, enabling data transfer and reading.
 The second level of protection is protection against unauthorised changes in meter
parameters. These meter actions shall be enabled either after removal of terminal
cover (violation of distribution company seal) or after verification of user type of
software package installed on the handheld device/laptop, as well as meter password.
Each change of parameters shall be registered in the standard Event Log with the date and
time of change.
Registers storing accounting data may not be changed.
Remote parameterisation of the meter shall be enabled only after entering the corresponding
password, whereas, AMM Centre software records permanently the data about the user, time
and type of action.
Communication security
The meter must fully support DLMS Security as described in the DLMS/COSEM Green Book, 7th
ed., section 9.2 ( layer 7 of OSI model)
In addition, meter must encrypt data using Advanced Encryption Standard (AES) at least at one
of:
● Layer 2 (IEEE 802.15.4g or IEEE P1901.2)
● Layer 3 (IP Security [IPsec])
In this context, the meter must store and manage the keys in a secure way
The meter must raise an alarm if a meter's key is changed for more than x time per hour. (x to
be defined as changeable parameter)
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
THREE-PHASE ELECTRICITY METERS OF ACTIVE ELECTRICAL ENERGY
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THREE-PHASE METER WITH CONSUMPTION MANAGEMENT
FUNCTION
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1. TECHNICAL CHARACTERISTICS OF THREE-PHASE ACTIVE ELECTRICITY METER
FOR DIRECT CONNECTION (THREE-PHASE METER WITH CONSUMPTION
MANAGEMENT FUNCTION)
1.1. GENERAL TECHNICAL CHARACTERISTICS
1.1.1. OPERATION MODE - CONSTRUCTION:
Meter shall be electronic (static) for single-phase two-wire direct connection.
1.1.2. RATED (REFERENCE) VOLTAGE:
3 x 230/400 (-20%, +15%) V.
1.1.3. RATED CURRENT:
5 (≥ 60) А.
1.1.4. RATED FREQUENCY:
50 Hz.
1.1.5. AUXILIARY CONSUMPTION OF THE METER:
Auxiliary mean power of voltage circuit under reference voltage, reference temperature of
23°C and reference frequency shall not exceed the value of 5 W and 25 VA (SRPS EN 62053-61
standard).
Auxiliary consumption of the meter current circuit under basic current, reference frequency
and reference temperature of 23°C shall not exceed the value of 2.5 VA for the meters of class
2, i.e. 4 VA for the meter of class 1 (SRPS EN 62053-61 standard).
1.1.6. MINIMUM ACCURACY CLASS:
For active energy and power
SRPS EN 62053-21 standard
2
SRPS EN 50470-3 standard
A
1.1.7. ANTICIPATED OPERATION LIFE:
minimum 15 years.
1.1.8. SIZE (HOUSING, TERMINAL AND COVERS):
Dimensions (main measures) have to be done according to Figure 1.
All measures are given in mm.
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b1
b2
C
h1
h2
h3
h45
150± 1
≤ 180
≤ 150
≤ 230
≤ 265
≤ 330
≥40
Figure 7 - Meter draft of principle
Dimension h4 has to fulfil the indicated condition for all conductor introductions, regardless of
the shape of the cover and it is measured from the lowest part of the terminal (end of the
switching module when it is installed) to lower part of its cover vertically below the conductor
introductions on terminal.
1.1.9. TERMINAL
In terminal, meter lines for direct connection are coupled with clamps with copper rail and one
or two screws, or capsular clamps according to the standard SRPS EN 62052 – 11.
Each clamp screw shall have the size and corresponding travel to fully and reliably fasten the
conductor and secure reliable and secure mechanical and electrical connection of current rail
with the conductor, without additional interventions on the conductor (bending, cross-section
increase, etc.).
Auxiliary and control terminals are executed under the ‘PLUG IN’ principle or through
corresponding clamps.
5
Procuring Entity retains the right to, in accordance with its needs, also define other values for
minimum dimension of h4
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1.1.10. DISPLAY
Metered values and characteristic codes are represented on LC display. Presentation of
metered values and characteristic codes shall be easily readable even in badly lit environment,
as well as under direct lighting.
Display may be executed as segment, “dot matrix” and other, when the data presentation is
provided in accordance with the request.
LC display operates in automatic and manual display regime. Transition between automatic
and manual display operation regime is executed in a simple manner, e.g. by pressing the
key/keys. Default display regime is automatic, to which the display returns from manual display
after corresponding idle period (keys are not pressed).
Under automatic regime, values of metered and registered values are shown cyclically. Initially,
only accounting elements and current date and time are cyclically changed on meter display
while the display period is between 5 and 20 sec.
Under manual display regime (value display regime based on selection), access should be
enabled to the standard data menu (accounting data, current power, voltages, currents).
If display elements are blinking, this shall have the frequency of about 1 Hz.
Presentation of metered values covers minimum 8 (eight) digits, while there is minimum 6 (six)
whole digits, and minimum 2(two) decimal digits.
Display of maximum power (maxigraph) has minimum 5 (five) digits, while at least 2 (two)
digits are used for display of decimal digits, and the remaining for whole digits.
Minimum 5 (five) digits are anticipated for display of characteristic codes.
Display of metered values and characteristic codes shall be clearly separated from one another.
Characteristic codes are in accordance with SRPS EN 62056-61 (OBIS).
Figures for value display shall at least be:

For metered values
7 mm

For characteristic codes
5 mm
The corresponding symbols shall be turned off (“fade out”) in the absence of individual phase
voltages.
The display shall at least show the following information:
• Value of the measured values,
• Measured values unit,
• Typical code in accordance with EN 62056-61 (OBIS),
• Phase presence indication,
• Current tariff indication.
Access to accounting elements for previous accounting period (at least 3 (three) periods) is
realised in a very simple manner, grouping the values according to accounting period,
chronologically, starting from the last accounting period towards previous ones.
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1.1.11. KEYS
Meter has at least one easily accessible key for menu scrolling. Keys enable menu scrolling
functions, selection of desired menu, return to the previous menu level, return to automatic
operation regime, as well as reconnection of bistable switch under meter operation regime
‘conditional switch reclosing’.
1.1.12. NUMBER OF TARIFFS
Meter has the possibility of storing metered values in min. 4 (four) tariff registers.
1.1.13. IMPULSE (TEST) TERMINALS
Optical impulse output (via LE diode) is mandatory.
In case that in meter is realised electrical impulse output, it is with galvanic insulation, passive
and executed on a corresponding terminal connection.
1.1.14. CHARACTERISTICS OF IMPULSE TERMINALS
Characteristics of impulse terminals of the meter are realised according to the standard SRPS
EN 62053 – 31 i.e. SRPS EN 62052 – 11.
1.1.15. METER CONSTANT
Meter constant is expressed by the number of impulses per energy unit (imp/kWh), amounting
to:
Optical
–
1000 imp/kWh
If the meter has one electrical and one impulse terminal, the constant shall equal:
Electrical
–
500 imp/kWh
1.1.16. TEMPERATURE RANGE AND CLIMATIC CONDITIONS
Meter functions under the standard temperature range for climatic area in which JP EPS
customers are located.
Operating temperature is within the range from – 25°C to + 55°C.
Meter functions under the conditions of relative humidity from 95% in the period of 24 hours.
1.2
OTHER TECHNICAL CHARACTERISTICS
1.2.1. METER HOUSING – MATERIALS, SHAPE AND FORM OF MEASURE
All meter housing parts, including the terminal shall be made of material resistant to
mechanical impact, humidity, UV radiation and self-quenching characteristics in accordance
with the requirements indicated by SRPS EN 62052–11 standard.
Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN
62052 – 11 standard).
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Meters shall use the space to the best possible extent in the course of transport and storage
and they shall also be stored as compact whole. Buckles and openings serving for meter
fastening to the base of installation cubicles shall be manufactured so that the meter can be
fastened well after mounting.
Meter housing should contain space for communication module installation (point 2.2.1). This
space shall be realised not to overlap with the space anticipated for other purposes (meter
wiring, signalling/tariff control terminals, etc.). This space shall be anticipated either under the
terminal cover or below a special cover, but not below metering part cover (replacement of
communication module shall be done without affecting the state seal).
Total dimensions (main measures) of the meter with installed communication module shall be
done in accordance with dimensions from point 1.1.8.
1.2.2. IRREGULAR CONNECTION AND NEUTRAL CONDUCTOR DISCONNECTION
1.2.2.1 IRREGULAR CONNECTION
Phase conductor ‘input-output’ connection sequence shall not have an impact on accuracy and
regular metering.
In case of the detection of phase and neutral conductor crossing, the meter continues to
operate, but not necessarily within specified accuracy class, and without time restriction. After
the re-establishment of nominal mode, the meter shall continue regular operation within the
specified accuracy class.
1.2.2.2 NEUTRAL CONDUCTOR DISCONNECTION
In case of neutral conductor disconnection before the meter (‘neutral’ disappearance), the
meter shall continue operating, without obligation for this to be within the rated accuracy
class, without time restriction. After re-establishment of nominal regime, the meter shall
continue operation within the rated accuracy class
1.2.2.3 DISCONNECTION OF ONE OR TWO PHASES
Meter shall operate properly within the rated accuracy class boundaries in case of
disconnection of one or two phases.
1.2.3. ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS
Meter shall meet norms required by regulations from this field under SRPS EN 62052 – 11 and
SRPS EN 62053 – 21 standards, i.e. SRPS EN 50470-1 and SRPS EN 50470-3 (for meters
according to MID directive).
1.2.4. METER LABEL
Basic meter data, given in the following table (items 1 – 11) shall completely be labelled on the
meter in accordance with SRPS EN 62052 – 11 standard, i.e. SRPS EN 50470-1 (for meters
according to MID directive).
In addition to these data, meter shall have the following data from the table (items 12 – 15).
Data shall be inerasable, and located on the front side of the meter.
Bar code label with the type of meter from position 16 is optional and it can be included in the
label in the form of bar code from position 15.
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Connection diagram with terminal labels (item 17 from the following table) may be located on
some of the covers.
№
Type of label
1.
Serial number
2.
Name and brand of the manufacturer
3.
Type label
4.
Rated accuracy class
5.
Year of manufacture
6.
Type approval label (official label of the competent authority)
7.
Reference voltage
8.
Rated frequency
9.
Basic and maximum current
10.
Constants of output impulses
11.
Class II insulation level label
12.
Communication protocol
13.
Accounting value code label shown on LC display
14.
Protection class label
15.
Label in the form of a barcode with the meter serial number. Serial number in
the barcode form shall be the same as the serial number under № 1 of this
table, which is included with no ambiguity.
16.
Label in the form of a barcode with the meter type (Type label in the barcode
form shall be the same as the type label under № 3 of this table, i.e. mark the
type of meter in the same way.
17.
Connection diagram with labels (numbers) of contact points
1.2.5. SEALING
Meter is constructed to provide a corresponding protection level against dust and humidity
penetration. According to SRPS IEC 60529 meters are manufactured to provide the protection
level of at least IP 51.
2. METER FUNCTIONS
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS
2.1.1. ACTIVE ENERGY
The meter measures, registers and displays active energy within the rated accuracy class.
Meter measures total active energy (register labels 15.8.x in accordance with SRPS EN 6205661 (OBIS)).
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2.1.2. MAXIMUM POWER
The meter measures, registers and displays maximum mean active power under all tariffs and
(register mark 1.6.x in accordance with SRPS EN 62056-61 (OBIS)). Power integration period is
initially 15 minutes. This value is programmable and display of this value is easily accessible in
manual display operating mode and remotely. Manual maxigraph reset is not possible.
2.1.3. INSTANTANEOUS ACTIVE POWER
The meter measures and displays on request current active power on LC display.
2.1.4. LOAD PROFILES OF METERED AND REGISTERED VALUES
Meter shall have the possibility to record at least 2 profiles. Sampling period inside each profile
can be independently set.
Change of all recording and registering parameters of metering and registered values may be
done locally (via optical port) and remotely (via external communication).
Initially, meter records the following profiles:
2.1.4.1 LOAD PROFILE
Meter records and registers the load profile (mean active power value). Integration period is
initially 15 minutes. In the load profile, together with corresponding block of registered mean
active power value, the data which clearly defines when the block is recorded is also
memorised.
Total capacity for load profile storage shall enable memorising of at least 4320 power metering
records.
2.1.4.2 PROFILE OF HOURLY REGISTER VALUES
Meter records and registers values of all accounting registers each 60 minutes. Hourly value
recording and registering time is initially at the full hour.
Hourly consumption values can be displayed absolutely (register values) or relatively (register
increments).
Memory for the storage of profiles of hourly values of meter registers and statuses has the
capacity of at least 24 entries, under FIFO principle.
2.1.5. EVENT LOG
Meter memorises events related to metering, adjustment and handling into the special
memory registers (organised under FIFO principle). A record in the memory is generated for
each event memorising the type of event, time stamp and meter status when the event
occurred.
Each of those memory registers is separate Event log for the type of event (events related to
the electricity quality, metering integrity, consumption management etc.) It is possible to
integrate events into one unique Event Log.
Meter registers at least 200 events.
Event coding as well as the type of events entered in the Event Log should be organised under
the recommendations given in IDIS or equivalent specification.
Event Log is not erasable via any external intervention.
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2.1.6. VOLTAGE METERING
Meter measures and displays effective voltage value on request.
2.1.7. CURRENT METERING
Meter measures and displays effective current value on request.
2.1.8. PHASE PRESENCE
The meter shall display the phase voltage presence on the connected conductor. The phase
display function provides information about phase presence.
2.1.9. TIME AND DATE
Meter displays time and date from internal switching clock.
2.1.10. INTERNAL CLOCK
Accuracy and other features of internal clock shall be realised in accordance with SRPS EN
62052-21 and SRPS EN 62054-21 standards. Setting and adjustment of time and other internal
clock features shall be realised in the same manner as in the case of energy value
parameterisation and via the same communication ports.
Internal clock supply shall be realised as basic and stand-by. Basic supply comes from the
power grid.
Stand-by supply provides data storing of real time.
Meter possesses real time calendar.
2.1.11. STANDBY SUPPLY
Stand-by supply of internal clock shall be realised via battery or super capacitor, where the
super capacitor provides data storing for minimum 7 days.
Battery operating life is minimum 10 years.
If battery operating life is shorter than the seal validity period of the Measures and Precious
Metals Directorate, battery change has to be realized in such a way not to require removal of
the Measures and Precious Metals Directorate seal. In this case battery access shall be
protected by a special seal (electricity distributor seal).
Battery change shall be realised without the loss of meter data during the time anticipated for
battery change. During battery change process, clock on the display is not conditioned.
In addition to internal clock, battery/ super capacitor may supply a corresponding part of
meter memory: e.g. part of the memory for the storage of communication parameters, etc.,
but not master or accounting data.
Battery state testing function shall be realised inside the meter. If irregular battery state is
detected (failure, if the battery is empty or if it does not exist), the function of clear display of
irregular state is realized.
2.1.12. DAYLIGHT SAVING TIME – DST
Meter shall possess automatic daylight saving time function (Daylight saving time – DST) and
according to the calendar of Central European Time – CET.
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2.1.13. CURRENT TARIFF
Meter shall have continuous display of current active tariff register, regardless of its display
mode.
2.1.14. LOCAL TARIFF REGISTER MANAGEMENT
Local tariff register management shall be realised via internal clock.
Tariff programme shall anticipate the possibility of defining four different seasons, at least
three different days within the season and two different days for holidays.
Tariffs may be changed during one day for at least eight times.
2.1.15. METERING INTEGRITY
Meters shall have metering integrity violation (terminal cover opening, meter housing opening,
parameter change, strong magnetic field impact on the meter, etc.) recording and signalling
function.
If the meter cover is sealed in such a way that it cannot be opened without a permanent,
clearly visible and easily visible deformation or damage to the meter or its parts (“sealed for
life”), meter opening recording function is not necessary.
For each of the indicated events, Event Log shall make a record with a time stamp when this
event occurred.
2.1.15.1 DETECTION OF STRONG MAGNETIC FIELD
Meter shall have realised strong magnetic field detection function which can influence its
regular operation.
Upon detecting magnetic field that can influence its regular operation, time and date of
detection of magnetic field is recorded in the Event Log.
This function shall be realised upon the request of electricity distributor.
2.1.16. DATA STABILITY AND MEMORISING
Master data about the meter (year of manufacture, type label and serial number) shall not be
changeable. In addition to this, electricity data as well as data on maximum 15-minute power
shall not be changeable. These data are located in the part of permanent meter memory and
their integrity is not dependent on period when meter was not supplied (basic and stand-by).
All other data may be, via communication module (communicator) and IR port, altered
according to the current tariff system and upon the order of authorised persons.
Meter shall record and register (memorise) states of all tariff registers during the accounting
period (first and last day of the month) and at an exactly defined moment (programmable
locally or remotely).
2.1.17. COUNTDOWN
Meter shall have the reduction blockade of achieved individual register values.
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2.1.18. DATA STORAGE PERIOD
Accounting data (active electricity and maximum mean power with date and time of
achievement, registered according to tariffs) shall be stored for at least 12 last accounting
periods (usually 12 months). After the new cycle starts, space shall be provided for the new
memory block, with the deletion of the last (the oldest) in the sequence of registers.
Total registered electricity cannot be deleted.
2.2.
ADDITIONAL FUNCTIONS
2.2.1. COMMUNICATION WITH THE METER
Meter shall have communication between the meter and different devices (hand terminals,
communication modules, registers, data concentrators, etc.). Communication shall be
executed via interfaces given in the following table, with the usage of data model, application
layer and identification structure according to DLMS/COSEM.
Meter shall have DLMS/COSEM certificate issued based on the verification with the latest
version of testing software (at least version 2.0).
Electrical interface is galvanically insulated from the metering part of the meter.
Communication part of the meter is executed to enable communication with the meter via all
meter interfaces, without impact on the measuring part of the meter.
External communication is executed via special communication module, situated in the
corresponding space (point 1.2.1).
All electrical connections of communication module with the meter is achieved under PLUG IN
principle (connector to connector or connector on a short cable / cables) , whereas the total
consumption of the meter and communication module does not exceed the requirement from
point 1.1.5.
Communication module shall not logically depend from the meter, i.e. replacement of old and
installation of new communication module is reduced to simple physical replacement, while
software in the concentrator/AMM Centre performs logic replacement.
Communication module uses the protocol defined according to DLMS/COSEM.
The meter shall have the following interfaces:
Optical Interface: Infrared (IR) port, physical characteristics in accordance with SRPS EN The
meter shall have the following interfaces:
1. Optical Interface: Infrared (IR) port, physical characteristics in accordance with SRPS EN
62056-21.
2. Electrical interface № 1, which is used to interface with the remote reading
communication module (cellular modem, PLC modem, radio modem etc.)
The implemented communication protocol - DLMS/COSEM.
3. Electrical interface no.2 used for management of switching module for remote
disconnection/connection of customers, in case that it is realized by the external switch
module (item 1.2 of the Chapter Functional Requirements for switching module (bistable
switch)).
In case of integrated switching module electrical interface no 2 is not mandatory.
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Implemented at the request of the electricity distributor.
4. Electrical interface № 3, which is used to connect the meter with HAN (Home Area
Network) modem/module (depending on the design).
Implemented at the request of the electricity distributor.
5. Electrical interface № 4, which is used to connect the meter and other measuring devices
that may be located on the electricity customer side (Section 2.7).
It may be realized through existing electrical interface in a way that does not interfere with
communication with other modules.
Implemented at the request of the electricity distributor.
Electrical interface № 2, 3 and 4, as well as other additional dedicated interfaces may be
realised:



via separate connector on the meter (auxiliary contacts) or
via separate connector on communication module for remote reading (cellular modem,
PLC modem, etc.), or
via appropriate module for the extension of external interfaces. In that case the
indicated module shall always be delivered with the meter.
2.2.1.1 CELLULAR COMMUNICATION
At the request of Electric distribution network operator, the meter may be equipped with
cellular communication module which is connected to the meter via specific electrical
interface, whereas the requests from items 1.1.8 (dimensions) and 1.2.1 (housing) are fulfilled.
Characteristics of cellular communication module are given in the Chapter Technical
Characteristics and functional requests for cellular modem, items 1, 2.1 and 2.1.1.
2.2.1.2 PLC COMMUNICATION
At the request of Electric distribution network operator, the meter may be equipped with PLC
communication module which may be, in accordance with the Electric distribution network
operator’s request, installed as:


External PLC communication modem, which is connected to the meter via specific
electrical interface. Characteristics of external PLC communication modem are given in
the Chapter Technical Characteristics and functional requests for PLC modem, items 1,
2 and 2.2.1.
Integrated PLC communication modem, which is installed inside the meter housing.
Characteristics of integrated PLC communication modem are given in the Chapter
Technical Characteristics and functional requests for PLC modem, items 1, 2 and 2.2.2.
In that case, electrical interface № 1 is not mandatory.
2.2.1.3 RADIO COMMUNICATION
At the request of Electric distribution network operator, the meter may be equipped with radio
communication module which may be, in accordance with the Electric distribution network
operator’s request, installed as:
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

External radio communication modem, which is connected to the meter via specific
electrical interface. Characteristics of external radio communication modem are given
in the Chapter Technical Characteristics and functional requests for radio modem, items
1, 2 and 2.2.1.
Integrated radio communication modem, which is installed inside the meter housing.
Characteristics of integrated radio communication modem are given in the Chapter
Technical Characteristics and functional requests for radio modem, items 1, 2 and 2.2.2.
In that case, electrical interface № 1 is not mandatory.
2.3.
CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT
Meter has the possibility of consumption management, by means of a special switching
module (bistable switch) executing remote disconnection/connection of customers and
limiting of permitted maximum active power.
That function is realized at the request of electricity distributor.
Switching module may be realized as:

Integrated switching module (bistable switch). Characteristics of integrated switching
module are given in the item 1.1 of the Chapter Functional Requirements for switching
module (bistable switch).

External switching module (bistable switch). Characteristics of external switching
module are given in the item 1.2 of the Chapter Functional Requirements for switching
module (bistable switch).
In the case of meter with external switching module, meter functions are not conditioned by
connecting external switching module. Exceptions are only the options of consumption
management-remote disconnection/connection of customers and limiting of permitted
maximum power.
In the course of meter parameterisation it should be possible to define the category (group) to
which the meter belongs, in terms of consumption management function realisation in the
case of simultaneous disconnection/connection of switching modules with the larger number
of users.
Switch reclosing is programmable and there are two switch operation regimes:
2.3.1. “CONDITIONAL SWITCH RECLOSING”
After receiving instructions for reconnection/expiry of penalty time, it is necessary to confirm
switch reclosing locally via key/keys. The meter (ex. display) shows a corresponding notification
that the condition necessary for connection has been achieved, and that key confirmation is
expected.
2.3.2. “AUTOMATIC SWITCH RECLOSING”
After receiving instructions for reconnection/expiry of penalty time, the switch is automatically
reconnected.
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2.3.3. CONTROL OUTPUT
Meter has at least one control output (independent relay) for signalling of current tariff.
Control output is galvanically separated as a relay, with minimum technical characteristics
230V, 2A, whose connections are executed on meter terminal.
Activation of this output is primarily done automatically in accordance with the current tariff
programme (low tariff signalling). However, the manner of activation of control output can be
programmed.
2.3.4 LIMITING OF PERMITTED MAXIMUM POWER
Meter has software possibility of limiting power with which the customer can load the power
network, by entering limiting value (power limit), time tolerance period of such load (overload
time) and penalty time of customer disconnection with corresponding registers in the meter
memory. Meter has the possibility of entering two power limit levels – one value for ‘normal’
level, in accordance with the contracted value, and other, lower value, activated upon AMM
Centre command, in case of electricity reductions within the system.
Values of power limit, permitted overload time and penalty time may be set remotely and
locally.
Power limit is the value of contracted active power maximum contracted between the
customer and electricity distributor.
Permitted overload time is the contracted time contracted between the customer and
electricity distributor and it defines minimum power limit exceeding time after which switching
module is activated.
Penalty time is the contracted time between the customer and electricity distributor and it
defines the time after customer disconnection due to power limit exceedence, during which it
is not possible to reconnect the customer (programmable).
When the meter detects power limit exceedence, after the permitted overload time has
expired, the customer will be disconnected from the network.
After the expiry of ‘penalty time’ reconnection is done in accordance with active switch
operation regime (conditional or automatic switch reconnection).
It is desirable to have the mechanism within AMI system or the meter itself that would inform
the customer on the status of management consumption (for example that the limit is
exceeded and the customer shall be disconnected from the network, i.e. there was a
disconnection since the limit has been exceeded, i.e. that the conditions for reconnection were
met etc.).
Special Event Log records entries for at least 10 previous disconnections, i.e. reconnections of
the switching module, with the time stamp and switching module status.
2.3.5 REMOTE DISCONNECTION/CONNECTION OF THE CUSTOMER (ELECTRICITY SUPPLY
INTERRUPTION)
Switching module for remote disconnection/connection of the customer may be activated via
AMM Centre command (unsettled financial liabilities of the customer against electricity
distributor).
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Only phase disconnection shall be done during remote disconnection, while reconnection is
executed in accordance with active switch operation regime (conditional or automatic switch
closing).
Special Event Log records entries for at least 10 previous disconnections, i.e. reconnections of
the switching module, with the time stamp and switching module status.
2.4.
ELECTRICITY METERING QUALITY
2.4.1. UNDER AND OVER VOLTAGES
Meter registers under-voltage/overvoltage occurrence event and termination of the latter.
Events are entered into a special event log (electricity quality log) with the date/time of event,
with the capacity of at least 10 entries.
Under-voltage and overvoltage thresholds may be adjusted. Initially: under-voltage = -20% Un,
overvoltage = +15% Un.
2.4.2. SUPPLY INTERRUPTION REGISTRATION
Meter registers supply interruptions in accordance with SRPS ЕN 50160.
Meter registers the number and total duration of short-term supply interruptions (supply
interruptions shorter than 3 minutes) and long-term supply interruptions (supply interruptions
longer than 3 minutes), recorded in the electricity quality log. Meter records corresponding
codes into electricity quality log for each supply interruption.
2.5.
METER FIRMWARE UPGRADE
Meter shall support firmware upgrade option in accordance with the Directive WELMEC 7.2,
publication 5 or newer, Firmware Guideline (Directive 2004/22/EC of the European Parliament
and of the Council on measuring instruments 2004/22/EC).
Firmware upgrade option in the meter is realised not to alter in any way the metering
characteristics (metrology) of the meter, data memorised in the meter (metering data,
statuses, etc.), configuration parameters or operational parameters of the meter – all these
data remain unchanged even after firmware upgrade.
Meter firmware upgrade, local or remote, shall be executed in accordance with the current
legal regulations.
New meter firmware will be submitted to the meter with date/time parameter of new
firmware application (i.e. meter will memorise the new software but it will start executing it
when the defined parameter is achieved).
Meter will after receiving the new firmware verify its compatibility in case that verification
does not end positively, new firmware will not be executed.
Meter will record time and data of new firmware receipt in the Event Log, as well as time and
date of new firmware application.
Meter will during application of new firmware perform self-check. Results of this self-check will
be available on the meter (locally and remotely).
New firmware upgrade in the meter may be done locally or remotely.
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2.6.
SELF-CHECK
Meter should have a self-check function implemented. The purpose of this function is to verify
proper execution of basic meter functions.
Meter performs self-check during network connection, i.e. after every supply restoration
(power – up).
Self – check verifies the following:
 Memory integrity of the meter
 Meter statuses and alarms
In addition to these, the following checks may be performed: connection check towards
external communication module, voltage presence, etc.
Errors discovered by Self-check procedure are entered into the Event Log.
2.7.
MULTI-UTILITY METERING
Meter possesses an electrical interface for connection of other metering devices located with
the electricity customer. In general, these include, water meter, gas meter and heat meter.
Meter minimally possesses memory registers for accounting data storage for each of the
above-specified meters. Storage capacity is 12 accounting periods for each of the meters
organised under FIFO principle.
In its firmware, meter has corresponding algorithms for reading of the indicated metering
devices and storage of data read in this way.
This function is subject to additional request of electricity distributer.
2.8.
DATA SECURITY
For the purpose of data security, locally accessed data have to be protected by access right
verification with at least two access levels:

The first protection level is protection against unauthorised data reading via optical
port and it is realised through software package installed on the handheld
device/laptop, presenting itself to the meter, enabling data transfer and reading.
 The second level of protection is protection against unauthorised changes in meter
parameters. These meter actions shall be enabled either after removal of terminal
cover (violation of distribution company seal) or after verification of user type of
software package installed on the handheld device/laptop, as well as meter password.
Each change of parameters shall be registered in the standard Event Log with the date and
time of change.
Registers storing accounting data may not be changed.
Remote parameterisation of the meter shall be enabled only after entering the corresponding
password, whereas, AMM Centre software records permanently the data about the user, time
and type of action.
Communication security
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The meter must fully support DLMS Security as described in the DLMS/COSEM Green Book, 7th
ed., section 9.2 ( layer 7 of OSI model)
In addition, meter must encrypt data using Advanced Encryption Standard (AES) at least at one
of:
● Layer 2 (IEEE 802.15.4g or IEEE P1901.2)
● Layer 3 (IP Security [IPsec])
In this context, the meter must store and manage the keys in a secure way
The meter must raise an alarm if a meter's key is changed for more than x time per hour. (x to
be defined as changeable parameter)
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
THREE-PHASE ELECTRICITY METERS OF ACTIVE AND REACTIVE
ELECTRICAL ENERGY
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
THREE-PHASE ELECTRICITY METERS OF ACTIVE AND REACTIVE
ELECTRICAL ENERGY FOR DIRECT CONNECTION
DIRECT C/I METER WITHOUT THE POSSIBILITY OF DEMAND
MANAGEMENT
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1. TECHNICAL CHARACTERISTICS OF METERS OF ACTIVE AND REACTIVE
ELECTRICITY FOR DIRECT CONNECTION (THREE-PHASE DIRECT C/I METER
WITHOUT CONSUMPTION MANAGEMENT)
1.1.
GENERAL TECHNICAL CHARACTERISTICS
1.1.1. OPERATION MODE - CONSTRUCTION:
Meter shall be electronic (static) for three-phase four-wire direct connection with three
metering systems and operation in all four quadrants.
1.1.2. RATED (REFERENCE) VOLTAGE:
3 x 230/400 (-20%, +15%) V.
1.1.3. RATED CURRENT:
5 (≥ 60) А
1.1.4. RATED FREQUENCY:
50 Hz.
1.1.5. AUXILIARY CONSUMPTION OF THE METER:
Auxiliary mean power of each voltage circuit under reference voltage, reference temperature
of 23°C and reference frequency shall not exceed the value of 3 W and 15 VA (SRPS EN 6205361 standard).
Auxiliary consumption of each meter current circuit under basic current, reference frequency
and reference temperature of 23°C shall not exceed the value of 4 VA for the meter of class 1
(SRPS EN 62053-21 standard).
1.1.6. MINIMUM RATED ACCURACY CLASS:
For active energy and power
SRPS EN 62053-21 standard
1
SRPS EN 50470-3 standard
B
For reactive energy
SRPS EN 62053-23 standard
3
1.1.7. ANTICIPATED OPERATION LIFE:
minimum 15 years.
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1.1.8. SIZE (HOUSING, TERMINAL AND COVERS):
Dimensions (main measures) have to be done according to Figure 1.
All measures are given in mm.
b1
b2
150± 1 ≤ 180
C
h1
h2
h3
h46
≤ 150
≤ 230
≤ 265
≤ 330
≥40
Figure 8 - General meter draft
Dimension h4 has to fulfil the indicated condition for all conductor introductions, regardless of
the shape of the cover and it is measured from the lowest part of the terminal to lower part of
its cover vertically below the conductor introductions on terminal.
1.1.9. TERMINAL
Meter lines in the terminal for direct connection are coupled with clamps with copper rail and
one or two screws, or capsular clamps according to the standard SRPS EN 62052 – 11.
6
Procuring Entity retains the right to, in accordance with its needs, also define other values for
minimum dimension of h4
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Each clamp screw shall have the size and corresponding travel to, during maximum moment of
re-screwing the screw defined by manufacturer, fully and reliably fasten the conductor and
secure reliable and safe mechanical and electrical connection of current rail with the
conductor, without additional interventions on the conductor (bending, cross-section increase,
etc.).
Auxiliary and control terminals are executed under the ‘PLUG IN’ principle or through
corresponding clamps.
1.1.10. DISPLAY
Metered values and characteristic codes are represented on LC display. Presentation of
metered values and characteristic codes shall be easily readable even in badly lit environment,
as well as under direct lighting.
Display may be executed as segment, “dot matrix” and other, when the data presentation is
provided in accordance with the request.
LC display operates in automatic and manual display regime. Transition between automatic
and manual display operation regime is executed in a simple manner, e.g. by pressing the
key/keys. Default display regime is automatic, to which the display returns from manual display
after corresponding idle period (keys are not pressed).
Under automatic regime, values of metered and registered values are shown cyclically. Initially,
only accounting elements and current date and time are cyclically changed in the period of
minimum 5 to 20 sec on meter display.
Under manual display regime (value display regime based on selection), access should be
enabled to the standard data menu (accounting data, current power, voltages, currents, etc).
If display elements are blinking, this shall have the frequency of about 1 Hz.
Presentation of metered values covers minimum 8 (eight) digits, while there is minimum 6 (six)
whole digits, and minimum 2(two) decimal digits.
Display of maximum power (maxigraph) has minimum 5 (five) digits, while at least 2 (two)
digits are used for display of decimal digits, and the remaining for whole digits.
Minimum 5 (five) digits are anticipated for display of characteristic codes.
Display of metered values and characteristic codes shall be clearly separated from one another.
Characteristic codes are in accordance with SRPS EN 62056-61 (OBIS).
Figures for value display shall at least be:

for metered values
7mm

for characteristic codes
5mm
Corresponding symbols are turned off (‘fade out’) during absence of individual phase voltages.
Minimum following information have to be displayed:

Metered values
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
Units of metered values

Characteristic code in accordance with SRPS EN 62056-61 (OBIS)

Indication of phase presence

Indication of energy flow direction

Indication of current tariff
The approach to calculation elements for the previous calculation periods (minimum for 3
(three) periods) is realized in a very simple manner, by which the values are grouped according
to calculation period and chronologically listed, staring from the last calculation period and
then the previous ones.
1.1.11. KEYS
Meter has at least one easily accessible key for menu scrolling. Key, i.e. keys enable menu
scrolling functions, selection of desired menu, return to the previous menu level, return to
automatic operation regime.
1.1.12. NUMBER OF TARIFFS
Meter has the possibility of storing metered values in min. 4 (four) tariff registers.
1.1.13. IMPULSE (TEST) TERMINALS
Optical impulse output (via LE diode) is mandatory.
In case that in meter is realised electrical impulse output, it is with galvanic insulation, passive
and executed on a corresponding terminal connection.
1.1.14. CHARACTERISTICS OF IMPULSE TERMINALS
Characteristics of impulse terminals of the meter are realised according to the standard SRPS
EN 62053 – 31 i.e. SRPS EN 62052 – 11.
1.1.15. METER CONSTANT
Meter constant is expressed by the number of impulses per energy unit (imp/kWh or kVArh),
amounting to:
Optical
–
1000 imp/KWh (imp/kVArh).
In case that in meter is realised electrical impulse output, electrical impulse output constant is
Electrical
–
500 imp/KWh (imp/kVArh)
1.1.16. TEMPERATURE RANGE AND CLIMATIC CONDITIONS
Meter functions under the standard temperature range for climatic area in which JP EPS
customers are located.
Operating temperature is within the range from – 25°C to + 55°C.
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Meter functions under the conditions of relative humidity of 95% in the period of 24 hours.
1.2.
OTHER TECHNICAL CHARACTERISTICS
1.2.1. METER HOUSING – MATERIALS, SHAPE AND FORM OF DEVICES
All meter housing parts, including the terminal shall be made of material resistant to
mechanical impact, humidity, UV radiation and self-extinguishing characteristics in accordance
with the requirements indicated by SRPS EN 62052–11 standard.
Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN
62052 – 11standard).
Meters shall use the space to the best possible extent in the course of transport and storage
and they shall also be stored as compact whole. Buckles and openings serving for meter
fastening to the base of installation cubicles shall be manufactured so that the meter can be
fastened well after mounting.
Meter which anticipates installation of external communication module in meter housing
should contain space for communication module installation (point 2.2.1). This space shall not
overlap with the space anticipated for other purposes (meter wiring, tariff control terminals,
etc.) and shall not disturb direct access to the terminal and auxiliary contacts. This space shall
be anticipated either under the terminal cover or below a special cover, but not below
metering part cover (replacement of communication module shall be done without affecting
the state seal).
Total dimensions (main measures) of the meter as well as meter with installed communication
module shall be done in accordance with dimensions from item 1.1.8.
1.2.2. IRREGULAR CONNECTION AND NEUTRAL CONDUCTOR DISCONNECTION
1.2.2.1 IRREGULAR CONNECTION
Phase conductor ‘input-output’ connection sequence shall not have an impact on accuracy and
regular metering.
In case of the phase and neutral conductor crossing, the meter continues to operate, but not
necessarily within specified accuracy class, and without time restriction. After the
reestablishment of nominal mode, the meter shall continue regular operation within the
specified accuracy class.
1.2.2.2 NEUTRAL CONDUCTOR DISCONNECTION
In case of neutral conductor disconnection before the meter (‘neutral’ disappearance), the
meter shall continue operating, without obligation for this to be within the rated accuracy
class, without time restriction. After re-establishment of nominal mode, the meter shall
continue proper operation within the rated accuracy class.
1.2.2.3 DISCONNECTION OF ONE OR TWO PHASES
Meter shall operate properly within the rated accuracy class boundaries in case of
disconnection of one or two phases.
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1.2.3. ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS
Meter shall meet norms required by regulations from this field under SRPS EN 62052 – 11 and
SRPS EN 62053 – 21 standards, i.e. SRPS EN 50470-1 and SRPS EN 50470-3 (for meters under
MID Directive).
1.2.4. METER LABELS
Basic meter data, given in the following table (items 1 – 11) shall completely be labelled on the
meter in accordance with SRPS EN 62052 – 11 standard i.e. SRPS EN 50470-1 for meters
according to MID Directive.
In addition to these data, meter shall have the following data from the table (items 12 – 15).
Data shall be inerasable, and located on the front side of the meter.
Bar code with the type of the meter from item 16 is optional, and it may be included in the
label of the bar code in item 15.
Connection diagram with terminal labels (item 17 from the following table) may be located on
some of the covers.
№
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
15.
16.
17.
Type of label
Serial number
Name or brand of the manufacturer
Type label
Rated accuracy class
Year of manufacture
Type approval label (official label of the competent authority)
Reference voltage
Rated frequency
Basic and maximum current
Constants of output impulses
Class II insulation level label
Communication protocol
Accounting value code label shown on LC display
Protection class label
Label in the form of a barcode with the meter serial number. Serial number in
the barcode form shall be the same as the serial number under № 1 of this
table, i.e. included with no ambiguity.
Label in the form of a barcode with the meter type. Type label in the barcode
form shall be the same as the type label under № 3 of this table, i.e. mark the
meter type in the same way.
Connection diagram with labels (numbers) of contact points
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1.2.5. SEALING
Meter is constructed to provide a corresponding protection level against dust and humidity
penetration. According to SRPS EN 60529 meters are manufactured to provide the protection
level of at least IP 51.
2. METER FUNCTIONS
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS
2.1.1. ACTIVE ENERGY
The meter measures, registers and displays active energy within the rated accuracy class.
Meter measures active energy (register label 1.8.x in accordance with SRPS EN 62056-61
(OBIS)).
In addition to that, in manual display operating mode it shows the value of register 2.8.x
(register label in accordance with SRPS EN 62056-61 (OBIS)).
2.1.2. REACTIVE ENERGY
The meter measures, registers and displays reactive energy within the rated accuracy class
boundaries.
The meter measures imported reactive energy (register labels 3.8.x in accordance with SRPS
EN 62056-61 (OBIS)).
In addition to that, in manual display operating mode it shows the value 4.8.x of the register
(register label in accordance with SRPS EN 62056-61 (OBIS)).
2.1.3. MAXIMUM POWER
The meter measures, registers and displays maximum mean active power under all tariffs
(register mark 1.6.x in accordance with SRPS EN 62056-61 (OBIS)). Power integration period is
initially 15 minutes. This value is programmable and display of this value is easily accessible in
manual display operating mode and remotely. Manual maxigraph reset is not possible.
2.1.4. INSTANTANEOUS ACTIVE POWER
The meter measures and displays on request current active power on LC display.
2.1.5. PROFILES OF METERED AND REGISTERED VALUES
Meter shall have the possibility to record at least 2 profiles of metering or registered values.
Each profile should support the recording of at least 5 (five) selected values (channels).
Sampling period inside each profile can be independently set.
Change of all recording and registering parameters of metering and registered values may be
done locally (via optical port) and remotely (via external communication).
Initially, meter records the following profiles:
2.1.5.1 LOAD PROFILE
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Meter records and registers the load profile (mean active power value). Integration period is
initially 15 minutes. In the load profile, together with corresponding block of registered mean
active power value, the data which clearly defines when the block is recorded is also
memorised.
Total capacity for load profile storage shall enable memorising of at least 4320 power metering
records.
2.1.5.2 PROFILE OF HOURLY CONSUMPTION VALUES
Meter records and registers hourly consumption values each 60 minutes. Hourly value
recording and registering time is initially at the full hour.
Hourly consumption values can be displayed absolutely (register values) or relatively (register
increments).
Memory for the storage of profiles of hourly values of meter registers has the capacity of at
least 24 entries, under FIFO principle.
2.1.6. EVENT LOG
Meter memorises events related to metering, adjustment and handling into the special
memory registers (organised under FIFO principle). A record in the memory is generated for
each event memorising the type of event, time stamp and meter status when the event
occurred.
Each of those memory registers is separate Event log for the type of event (events related to
the electricity quality, metering integrity, etc.) It is possible to integrate events into one unique
Event log.
Meter registers at least 200 events.
Event coding as well as the type of events entered in the Event Log should be organised under
the recommendations given in IDIS or equivalent specification.
Event Log is not erasable via any external intervention.
2.1.7. VOLTAGE METERING
Meter measures and displays effective voltage value on request.
2.1.8. CURRENT METERING
Meter measures and displays effective current value on request.
2.1.9. PHASE PRESENCE
Meter indicates phase voltage presence on the connected conductors. Phase indication
function provides information on certain phase presence.
2.1.10. TIME AND DATE
Meter displays time and date from internal switching clock.
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2.1.11. INTERNAL CLOCK
Accuracy and other features of internal clock shall be realised in accordance with SRPS EN
62052-21 and SRPS EN 62054-21 standards. Setting and adjustment of time and other internal
clock features shall be realised in the same manner as in the case of energy value
parameterisation and via the same communication ports.
Internal clock supply shall be realised as basic and stand-by. Basic supply comes from the
power grid.
Stand-by supply provides data storing of real time.
Meter possesses real time calendar.
2.1.12. STANDBY SUPPLY
Stand-by supply of internal clock shall be realised via battery or super capacitor, where the
super capacitor provides data storing for minimum 7 days.
Battery operating life is minimum 10 years.
If battery operating life is shorter than the seal validity period of the Measures and Precious
Metals Directorate, battery change has to be realized in such a way not to require removal of
the Measures and Precious Metals Directorate seal. In this case battery access shall be
protected by a special seal (electricity distributor seal).
Battery change shall be realised without the loss of meter data during the time anticipated for
battery change. During the process of battery change, time does not have to be displayed.
In addition to internal clock, battery/ super capacitor may supply a corresponding part of
meter memory: e.g. part of the memory for the storage of communication parameters, etc, but
not master or accounting data.
Battery state testing function shall be realised inside the meter. If irregular battery state is
detected (failure, if the battery is empty or if it does not exist), the function of clear display of
irregular state is realized.
2.1.13. DAYLIGHT SAVING TIME – DST
Meter shall possess automatic daylight saving time function, according to the calendar of
Central European Time – CET.
2.1.14. CURRENT TARIFF
Meter shall have continuous display of current active tariff register, regardless of its display
mode.
2.1.15. LOCAL TARIFF REGISTER MANAGEMENT
Local tariff register management shall be realised via internal clock.
Tariff programme shall anticipate the possibility of defining four different seasons, at least
three different days within the season and two different days for holidays.
Tariffs may be changed during one day for at least eight times.
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2.1.16. METERING INTEGRITY
Meters shall have metering integrity violation (terminal cover opening, meter housing opening,
parameter change, strong magnetic field impact on the meter, etc.) recording and signalling
function.
If the meter housing is “sealed for life“ in such a manner that it cannot be opened without
permanent, clearly visible and apparent deformation or damage of meter housing or its parts,
recording function for meter housing opening is not necessary.
For each of the indicated events, Event Log shall make a record with a time stamp when this
event occurred.
2.1.16.1 DETECTION OF STRONG MAGNETIC FIELD
Meter shall have realised strong magnetic field detection function which can influence its
regular operation.
Upon detecting magnetic field that can influence its regular operation, time and date of
detection of magnetic field is recorded in the Event Log.
This function shall be realized upon the request of electricity distributor.
2.1.17. DATA STABILITY AND MEMORISING
Master data about the meter (year of manufacture, type label and serial number) shall not be
changeable. In addition to this, electricity data as well as data on maximum 15-minute power
shall not be changeable. These data are located in the part of permanent meter memory and
their integrity is not dependent on period when meter was not supplied (basic and stand-by).
All other data may be, via communication module (communicator) and IR port, altered
according to the current tariff system and upon the order of authorised persons.
Meter shall record and register (memorise) states of all tariff registers during the accounting
period (first or last day of the month) and at an exactly defined moment (programmable locally
or remotely).
2.1.18. COUNTDOWN
Meter shall have the reduction blockade of achieved individual tariff register values.
2.1.19. DATA STORAGE PERIOD
Accounting data (active and reactive energy and maximum mean power with date and time of
achievement, registered according to tariffs) shall be stored for at least 12 last accounting
periods (usually 12 months). After the new cycle starts, space shall be provided for the new
memory block, with the deletion of the last (the oldest) in the sequence of registers.
Total registered electricity cannot be deleted.
2.2.
ADDITIONAL FUNCTIONS
2.2.1. COMMUNICATION WITH THE METER
Meter shall have communication between the meter and different devices (hand terminals,
communication modules, registers, data concentrators, etc.). Communication shall be
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executed via interfaces, with the usage of data model, application layer and identification
structure according to DLMS/COSEM.
Meter shall have DLMS/COSEM certificate issued based on the verification with the latest
version of testing software (at least version 2.0).
Electrical interface is galvanically insulated from the metering part of the meter.
Communication part of the meter is executed to enable communication with the meter via all
meter communication interfaces, without impact on the measuring part of the meter.
External communication is executed via special communication module, situated in the
corresponding space (point 1.2.1).
All electrical connections of communication module with the meter is achieved under PLUG IN
principle (connector to connector or connector on a short cable / cables) , whereas the total
consumption of the meter and communication module does not exceed the requirement from
point 1.1.5.
Communication module shall not logically depend from the meter, i.e. replacement of old and
installation of new communication module is reduced to simple physical replacement, while
software in the concentrator/AMM Centre performs logic replacement.
Communication module uses the protocol defined according to DLMS/COSEM.
Meter shall have the following interfaces:
1. Optical interface: infrared (IR) port with physical characteristics in accordance with
SRPS EN 62056-21.
2. Electrical interface no.1 used for connection with communication module for remote
reading (cellular modem, etc.)
Implemented communication protocol is DLMS/COSEM
3. Electrical interface no.2, used for HAN (Home Area Network) connection of
modem/module (depending on the manufacture).
It is realized upon the electricity distributor's request.
Electrical interface number 2 and other additional specific interfaces can be realised:

by separate connector on the meter itself (eg. auxiliary contacts) or

by separate connector at the communication module for remote reading (cellular
modem, etc), or

by relevant module for extension of external interfaces. In that case the mentioned
module is delivered with the meter.
2.2.1.1 CELLULAR COMMUNICATION
At the request of the Procuring Entity, the meter may be equipped with cellular
communication module which is connected to the meter via specific electrical interface,
whereas the requests from items 1.1.8 (dimensions) and 1.2.1 (housing) are fulfilled.
Characteristics of cellular communication module are given in the Chapter Technical
Characteristics and Functional Requirements for cellular modem items 1, 2.1. and 2.1.1.
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2.3.
CONTROL OUTPUT
Meter has at least one control output (independent relay) for signalling of current tariff.
Control output is galvanically separated as a relay, with minimum technical characteristics
230V, 100mA, whose connections are executed on meter terminal.
Activation of this output is primarily done automatically in accordance with the current tariff
programme (low tariff signalling). However, the manner of activation of control output can be
programmed.
2.4.
ELECTRICITY QUALITY METERING
2.4.1. UNDER AND OVER VOLTAGES
Meter registers under-voltage/overvoltage occurrence event and termination of the latter.
Events are entered into a special event log (electricity quality log) with the date/time of event,
with the capacity of at least 10 entries.
Under-voltage and overvoltage thresholds may be adjusted. Initially: under-voltage = -20% Un,
overvoltage = +15% Un.
2.4.2. SUPPLY INTERRUPTION REGISTRATION
Meter registers supply interruptions in accordance with SRPS ЕN 50160.
Meter registers the number and total duration of short-term supply interruptions (supply
interruptions shorter than 3 minutes) and long-term supply interruptions (supply interruptions
longer than 3 minutes), recorded in the electricity quality log. Meter records corresponding
codes into electricity quality log for each supply interruption.
2.5.
SELF-CHECK
Meter has a self-check function implemented. The purpose of this function is to verify proper
execution of basic meter functions.
Meter performs self-check during network connection, i.e. after every supply restoration
(power – up).
Self – check must verify the following:

Memory integrity of the meter

Meter statuses and alarms
In addition to these, the following checks may be performed: connection check towards
external communication module, voltage presence, etc.
Errors discovered by Self-check procedure are entered into the Event Log.
2.6.
DATA SECURITY
For the purpose of data security, locally accessed data have to be protected by access right
verification with at least two access levels.
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
The first protection level is protection against unauthorised data reading via optical
port and it is realised through software package installed on the handheld
device/laptop, presenting itself to the meter, enabling data transfer and reading.

The second level of protection is protection against local unauthorised changes of
meter parameters. These actions over meter are enabled either after removal of
terminal cover (violation of distribution company seal) either only after verification of
user type of software package installed on the handheld device/laptop, as well as meter
password.
Each change of parameters shall be registered in the standard Event Log with the date and
time of change.
Registers storing accounting data may not be changed.
Remote parameterisation of the meter shall be enabled only after entering the corresponding
password, whereas, AMM Centre software records permanently the data about the user, time
and type of action.
Communication security
The meter must fully support DLMS Security as described in the DLMS/COSEM Green Book, 7th
ed., section 9.2 ( layer 7 of OSI model)
In addition, meter must encrypt data using Advanced Encryption Standard (AES) at least at one
of:
● Layer 2 (IEEE 802.15.4g or IEEE P1901.2)
● Layer 3 (IP Security [IPsec])
In this context, the meter must store and manage the keys in a secure way
The meter must raise an alarm if a meter's key is changed for more than x time per hour. (x to
be defined as changeable parameter)
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREEPHASE METERS OF ACTIVE AND REACTIVE ELECTRICITY FOR DIRECT
CONNECTION
DIRECT C/I METER WITH CONSUMPTION MANAGEMENT
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1. TECHNICAL CHARACTERISTICS OF THREE-PHASE METER OF ACTIVE AND
REACTIVE ELECTRICITY FOR DIRECT CONNECTION (THREE-PHASE DIRECT C/I
METER WITH CONSUMPTION MANAGEMENT)
1.1.
GENERAL TECHNICAL CHARACTERISTICS
1.1.1. OPERATION MODE - CONSTRUCTION:
Meter shall be electronic (static) for three-phase four-wire direct connection with three
metering systems and operation in all four quadrants.
1.1.2. RATED (REFERENCE) VOLTAGE:
3 x 230/400 (-20%, +15%) V.
1.1.3. RATED CURRENT:
5 (≥ 60) А
1.1.4. RATED FREQUENCY:
50 Hz.
1.1.5. AUXILIARY CONSUMPTION OF THE METER:
Auxiliary mean power of each voltage circuit under reference voltage, reference temperature
of 23°C and reference frequency shall not exceed the value of 3 W and 15 VA (SRPS EN 6205361 standard).
Auxiliary consumption of each meter current circuit under basic current, reference frequency
and reference temperature of 23°C shall not exceed the value of 4 VA for the meter of class 1
(SRPS EN 62053-21 standard).
1.1.6. MINIMUM RATED ACCURACY CLASS:
For active energy and power
SRPS EN 62053-21 standard
1
SRPS EN 50470-3 standard
B
For reactive energy
SRPS EN 62053-23 standard
3
1.1.7. ANTICIPATED OPERATION LIFE:
minimum 15 years.
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1.1.8. SIZE (HOUSING, TERMINAL AND COVERS):
Dimensions (main measures) have to be done according to Figure 1.
All measures are given in mm.
b1
b2
150± 1 ≤ 180
C
h1
h2
h3
h47
≤ 150
≤ 230
≤ 265
≤ 330
≥40
Figure 9 - General meter draft
Dimension h4 has to fulfil the indicated condition for all conductor introductions, regardless of
the shape of the cover and it is measured from the lowest part of the terminal (end of the
switching module when it is installed) to lower part of its cover vertically below the conductor
introductions on terminal.
7
Procuring Entity retains the right to, in accordance with its needs, also define other values for
minimum dimension of h4
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1.1.9. TERMINAL
Meter lines in the terminal for direct connection are coupled with clamps with copper rail and
one or two screws, or capsular clamps according to the standard SRPS EN 62052 – 11.
Each clamp screw shall have the size and corresponding travel to, during maximum moment of
re-screwing the screw defined by manufacturer, fully and reliably fasten the conductor and
secure reliable and safe mechanical and electrical connection of current rail with the
conductor, without additional interventions on the conductor (bending, cross-section increase,
etc.).
Auxiliary and control terminals are executed under the ‘PLUG IN’ principle or through
corresponding clamps.
1.1.10. DISPLAY
Metered values and characteristic codes are represented on LC display. Presentation of
metered values and characteristic codes shall be easily readable even in badly lit environment,
as well as under direct lighting.
Display may be executed as segment, “dot matrix” and other, when the data presentation is
provided in accordance with the request.
LC display operates in automatic and manual display regime. Transition between automatic
and manual display operation regime is executed in a simple manner, e.g. by pressing the
key/keys. Default display regime is automatic, to which the display returns from manual display
after corresponding idle period (keys are not pressed).
Under automatic regime, values of metered and registered values are shown cyclically. Initially,
only accounting elements and current date and time are cyclically changed in the period of
minimum 5 to 20 sec on meter display.
Under manual display regime (value display regime based on selection), access should be
enabled to the standard data menu (accounting data, current power, voltages, currents, etc).
If display elements are blinking, this shall have the frequency of about 1 Hz.
Presentation of metered values covers minimum 8 (eight) digits, while there is minimum 6 (six)
whole digits, and minimum 2 (two) decimal digits.
Display of maximum power (maxigraph) has minimum 5 (five) digits, while at least 2 (two)
digits are used for display of decimal digits, and the remaining for whole digits.
Minimum 5 (five) digits are anticipated for display of characteristic codes.
Display of metered values and characteristic codes shall be clearly separated from one another.
Characteristic codes are in accordance with SRPS EN 62056-61 (OBIS).
Figures for value display shall at least be:

for metered values
7mm

for characteristic codes
5mm
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Corresponding symbols are turned off (‘fade out’) during absence of individual phase voltages.
Minimum following information have to be displayed:

Metered values

Units of metered values

Characteristic code in accordance with SRPS EN 62056-61 (OBIS)

Indication of phase presence

Indication of energy flow direction

Indication of current tariff
The approach to calculation elements for the previous calculation periods (minimum for 3
(three) periods) is realized in a very simple manner, by which the values are grouped according
to calculation period and chronologically listed, starting from the last calculation period and
then the previous ones.
1.1.11. KEYS
Meter has at least one easily accessible key for menu scrolling. Key, i.e. keys enable menu
scrolling functions, selection of desired menu, return to the previous menu level, return to
automatic operation regime, as well as reconnection of bistable switch under meter operation
regime ‘conditional switch reclosing’.
1.1.12. NUMBER OF TARIFFS
Meter has the possibility of storing metered values in min. 4 (four) tariff registers.
1.1.13. IMPULSE (TEST) TERMINALS
Optical impulse output (via LE diode) is mandatory. In case that in meter is realised electrical
impulse ouput, it is with galvanic insulation, passive and executed on a corresponding terminal
connection.
1.1.14. CHARACTERISTICS OF IMPULSE TERMINALS
Characteristics of impulse terminals of the meter are realised according to the standard SRPS
EN 62053 – 31 i.e. SRPS EN 62052 – 11.
1.1.15. METER CONSTANT
Meter constant is expressed by the number of impulses per energy unit (imp/kWh or kVArh),
amounting to:
Optical
–
1000 imp/KWh (imp/kVArh).
In case that in meter is realised electrical impulse output, electrical impusle output constant is
Electrical
–
500 imp/KWh (imp/kVArh)
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1.1.16. TEMPERATURE RANGE AND CLIMATIC CONDITIONS
Meter functions under the standard temperature range for climatic area in which JP EPS
customers are located.
Operating temperature is within the range from – 25°C to + 55°C.
Meter functions under the conditions of relative humidity of 95% in the period of 24 hours.
1.2.
OTHER TECHNICAL CHARACTERISTICS
1.2.1. METER HOUSING – MATERIALS, SHAPE AND FORM OF DEVICES
All meter housing parts, including the terminal shall be made of material resistant to
mechanical impact, humidity, UV radiation and self-extinguishable characteristics in
accordance with the requirements indicated by SRPS EN 62052–11 standard.
Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN
62052 – 11standard).
Meters shall use the space to the best possible extent in the course of transport and storage
and they shall also be stored as compact whole. Buckles and openings serving for meter
fastening to the base of installation cubicles shall be manufactured so that the meter can be
fastened well after mounting.
Meter which anticipates installation of external communication module in meter housing
should contain space for communication module installation (point 2.2.1). This space shall not
overlap with the space anticipated for other purposes (meter wiring, switching modules for
remote disconnection/connection of the customer, tariff control terminals, etc.) and shall not
disturb direct access to the terminal and auxiliary contacts. This space shall be anticipated
either under the terminal cover or below a special cover, but not below metering part cover
(replacement of communication module shall be done without affecting the state seal).
Total dimensions (main measures) of the meter as well as meter with installed communication
and/or external switching module shall be done in accordance with dimensions from item
1.1.8.
1.2.2. IRREGULAR CONNECTION AND NEUTRAL CONDUCTOR DISCONNECTION
1.2.2.1 IRREGULAR CONNECTION
Phase conductor ‘input-output’ connection sequence shall not have an impact on accuracy and
regular metering.
In case of the phase and neutral conductor crossing, the meter continues to operate, but not
necessarily within specified accuracy class, and without time restriction. After the
reestablishment of nominal mode, the meter shall continue regular operation within the
specified accuracy class.
1.2.2.2 NEUTRAL CONDUCTOR DISCONNECTION
In case of neutral conductor disconnection before the meter (‘neutral’ disappearance), the
meter shall continue operating, without obligation for this to be within the rated accuracy
class, without time restriction. After re-establishment of nominal mode, the meter shall
continue proper operation within the rated accuracy class.
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1.2.2.3 DISCONNECTION OF ONE OR TWO PHASES
Meter shall operate properly within the rated accuracy class boundaries in case of
disconnection of one or two phases.
1.2.3. ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS
Meter shall meet norms required by regulations from this field under SRPS EN 62052 – 11 and
SRPS EN 62053 – 21 standards, i.e. SRPS EN 50470-1 and SRPS EN 50470-3 (for meters under
MID Directive).
1.2.4. METER LABELS
Basic meter data, given in the following table (items 1 – 11) shall completely be labelled on the
meter in accordance with SRPS EN 62052 – 11 standard i.e. SRPS EN 50470-1 for meters
according to MID Directive.
In addition to these data, meter shall have the following data from the table (items 12 – 15).
Data shall be inerasable, and located on the front side of the meter.
Bar code with the type of the meter from item 16 is optional, and it may be included in the
label of the bar code in item 15.
Connection diagram with terminal labels (item 17 from the following table) may be located on
some of the covers.
№
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
15.
16.
17.
Type of label
Serial number
Name or brand of the manufacturer
Type label
Rated accuracy class
Year of manufacture
Type approval label (official label of the competent authority)
Reference voltage
Rated frequency
Basic and maximum current
Constants of output impulses
Class II insulation level label
Communication protocol
Accounting value code label shown on LC display
Protection class label
Label in the form of a barcode with the meter serial number. Serial number in
the barcode form shall be the same as the serial number under № 1 of this
table, i.e. included with no ambiguity.
Label in the form of a barcode with the meter type. Type label in the barcode
form shall be the same as the type label under № 3 of this table, i.e. mark the
meter type in the same way.
Connection diagram with labels (numbers) of contact points
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1.2.5. SEALING
Meter is constructed to provide a corresponding protection level against dust and humidity
penetration. According to SRPS EN 60529 meters are manufactured to provide the protection
level of at least IP 51.
2. METER FUNCTIONS
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS
2.1.1. ACTIVE ENERGY
The meter measures, registers and displays active energy within the rated accuracy class.
Meter measures active energy (register label 1.8.x in accordance with SRPS EN 62056-61
(OBIS)).
In addition to that, in manual display operating mode it shows the value of register 2.8.x
(register label in accordance with SRPS EN 62056-61 (OBIS)).
2.1.2. REACTIVE ENERGY
The meter measures, registers and displays reactive energy within the rated accuracy class
boundaries.
The meter measures imported reactive energy (register labels 3.8.x in accordance with SRPS
EN 62056-61 (OBIS)).
In addition to that, in manual display operating mode it shows the value 4.8.x of the register
(register label in accordance with SRPS EN 62056-61 (OBIS)).
2.1.3. MAXIMUM POWER
The meter measures, registers and displays maximum mean active power under all tariffs
(register mark 1.6.x in accordance with SRPS EN 62056-61 (OBIS)). Power integration period is
initially 15 minutes. This value is programmable and display of this value is easily accessible in
manual display operating mode and remotely. Manual maxigraph reset is not possible.
2.1.4. INSTANTANEOUS ACTIVE POWER
The meter measures and displays on request current active power on LC display.
2.1.5. PROFILES OF METERED AND REGISTERED VALUES
Meter shall have the possibility to record at least 2 profiles of metering or registered values.
Each profile should support the recording of at least 5 (five) selected values (channels).
Sampling period inside each profile can be independently set.
Change of all recording and registering parameters of metering and registered values may be
done locally (via optical port) and remotely (via external communication).
Initially, meter records the following profiles:
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2.1.5.1 LOAD PROFILE
Meter records and registers the load profile (mean active power value). Integration period is
initially 15 minutes. In the load profile, together with corresponding block of registered mean
active power value, the data which clearly defines when the block is recorded is also
memorised.
Total capacity for load profile storage shall enable memorising of at least 4320 power metering
records.
2.1.5.2 PROFILE OF HOURLY CONSUMPTION VALUES
Meter records and registers hourly consumption values each 60 minutes. Hourly value
recording and registering time is initially at the full hour.
Hourly consumption values can be displayed absolutely (register values) or relatively (register
increments).
Memory for the storage of profiles of hourly values of meter registers has the capacity of at
least 24 entries, under FIFO principle.
2.1.6. EVENT LOG
Meter memorises events related to metering, adjustment and handling into the special
memory registers (organised under FIFO principle). A record in the memory is generated for
each event memorising the type of event, time stamp and meter status when the event
occurred.
Each of those memory registers is separate Event log for the type of event (events related to
the electricity quality, metering integrity, consumption management etc.) It is possible to
integrate events into one unique Event log.
Meter registers at least 200 events.
Event coding as well as the type of events entered in the Event Log should be organised under
the recommendations given in IDIS or equivalent specification.
Event Log is not erasable via any external intervention.
2.1.7. VOLTAGE METERING
Meter measures and displays effective voltage value on request.
2.1.8. CURRENT METERING
Meter measures and displays effective current value on request.
2.1.9. PHASE PRESENCE
Meter indicates phase voltage presence on the connected conductors. Phase indication
function provides information on certain phase presence.
2.1.10. TIME AND DATE
Meter displays time and date from internal switching clock.
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2.1.11. INTERNAL CLOCK
Accuracy and other features of internal clock shall be realised in accordance with SRPS EN
62052-21 and SRPS EN 62054-21 standards. Setting and adjustment of time and other internal
clock features shall be realised in the same manner as in the case of energy value
parameterisation and via the same communication ports.
Internal clock supply shall be realised as basic and stand-by. Basic supply comes from the
power grid.
Stand-by supply provides data storing of real time.
Meter possesses real time calendar.
2.1.12. STANDBY SUPPLY
Stand-by supply of internal clock shall be realised via battery or super capacitor, where the
super capacitor provides data storing for minimum 7 days.
Battery operating life is minimum 10 years.
If battery operating life is shorter than the seal validity period of the Measures and Precious
Metals Directorate, battery change has to be realized in such a way not to require removal of
the Measures and Precious Metals Directorate seal. In this case battery access shall be
protected by a special seal (electricity distributor seal).
Battery change shall be realised without the loss of meter data during the time anticipated for
battery change. During the process of battery change, time does not have to be displayed.
In addition to internal clock, battery/ super capacitor may supply a corresponding part of
meter memory: e.g. part of the memory for the storage of communication parameters, etc.,
but not master or accounting data.
Battery state testing function shall be realised inside the meter. If irregular battery state is
detected (failure, if the battery is empty or if it does not exist), the function of clear display of
irregular state is realized.
2.1.13. DAYLIGHT SAVING TIME – DST
Meter shall possess automatic daylight saving time function, according to the calendar of
Central European Time – CET.
2.1.14. CURRENT TARIFF
Meter shall have continuous display of current active tariff register, regardless of its display
mode.
2.1.15. LOCAL TARIFF REGISTER MANAGEMENT
Local tariff register management shall be realised via internal clock.
Tariff programme shall anticipate the possibility of defining four different seasons, at least
three different days within the season and two different days for holidays.
Tariffs may be changed during one day for at least eight times.
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2.1.16. METERING INTEGRITY
Meters shall have metering integrity violation (terminal cover opening, meter housing opening,
parameter change, strong magnetic field impact on the meter, etc.) recording and signalling
function.
If the meter housing is “sealed for life“ in such a manner that it cannot be opened without
permanent, clearly visible and apparent deformation or damage of meter housing or its parts,
recording function for meter housing opening is not necessary.
For each of the indicated events, Event Log shall make a record with a time stamp when this
event occurred.
2.1.16.1 DETECTION OF STRONG MAGNETIC FIELD
Meter shall have realised strong magnetic field detection function which can influence its
regular operation.
Upon detecting magnetic field that can influence its regular operation, time and date of
detection of magnetic field is recorded in the Event Log.
This function shall be realized upon the request of electricity distributor.
2.1.17. DATA STABILITY AND MEMORISING
Master data about the meter (year of manufacture, type label and serial number) shall not be
changeable. In addition to this, electricity data as well as data on maximum 15-minute power
shall not be changeable. These data are located in the part of permanent meter memory and
their integrity is not dependent on period when meter was not supplied (basic and stand-by).
All other data may be, via communication module (communicator) and IR port, altered
according to the current tariff system and upon the order of authorised persons.
Meter shall record and register (memorise) states of all tariff registers during the accounting
period (first or last day of the month) and at an exactly defined moment (programmable locally
or remotely).
2.1.18. COUNTDOWN
Meter shall have the reduction blockade of achieved individual tariff register values.
2.1.19. DATA STORAGE PERIOD
Accounting data (active and reactive energy and maximum mean power with date and time of
achievement, registered according to tariffs) shall be stored for at least 12 last accounting
periods (usually 12 months). After the new cycle starts, space shall be provided for the new
memory block, with the deletion of the last (the oldest) in the sequence of registers.
Total registered electricity cannot be deleted.
2.2.
ADDITIONAL FUNCTIONS
2.2.1. COMMUNICATION WITH THE METER
Meter shall have communication between the meter and different devices (hand terminals,
communication modules, registers, data concentrators, etc.). Communication shall be
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executed via interfaces, with the usage of data model, application layer and identification
structure according to DLMS/COSEM.
Meter shall have DLMS/COSEM certificate issued based on the verification with the latest
version of testing software (at least version 2.0).
Electrical interface is galvanically insulated from the metering part of the meter.
Communication part of the meter is executed to enable communication with the meter via all
meter communication interfaces, without impact on the measuring part of the meter.
External communication is executed via special communication module, situated in the
corresponding space (point 1.2.1).
All electrical connections of communication module with the meter is achieved under PLUG IN
principle (connector to connector or connector on a short cable / cables), whereas the total
consumption of the meter and communication module does not exceed the requirement from
point 1.1.5.
Communication module shall not logically depend from the meter, i.e. replacement of old and
installation of new communication module is reduced to simple physical replacement, while
software in the concentrator/AMM Centre performs logic replacement.
Communication module uses the protocol defined according to DLMS/COSEM.
Meter shall have the following interfaces:
1. Optical interface: infrared (IR) port with physical characteristics in accordance with
SRPS EN 62056-21.
2. Electrical interface no.1 used for connection with communication module for remote
reading (cellular modem, etc.)
Implemented communication protocol is DLMS/COSEM
3. Electrical interface no.2 used for management of switching module for remote
disconnection/connection of customers, in case that it is realized by the external switch
module (item 1.2 of the Chapter Functional Requirements for switching module
(bistable switch)).
In case of integrated switching module electrical interface no 2 is not mandatory.
It is realized upon the electricity distributor's request.
4. Electrical interface no.3, used for HAN (Home Area Network) connection of
modem/module (depending on the manufacture).
It is realized upon the electricity distributor's request.
Electrical interface number 2, electrical interface no.3 and other additional specific
interfaces can be realised:

by separate connector on the meter itself (e.g. auxiliary contacts) or

by separate connector at the communication module for remote reading
(cellular modem, etc.), or

by relevant module for extension of external interfaces. In that case the
mentioned module is delivered with the meter.
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2.2.1.1 CELLULAR COMMUNICATION
At the request of the Procuring Entity, the meter may be equipped with cellular
communication module which is connected to the meter via specific electrical interface,
whereas the requests from items 1.1.8 (dimensions) and 1.2.1 (housing) are fulfilled.
Characteristics of cellular communication module are given in the Chapter Technical
Characteristics and Functional Requirements for cellular modem items 1, 2.1 and 2.1.1.
2.3.
CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT
Meter has the possibility of consumption management, by means of a special switching
module (bistable switch) executing remote disconnection/connection of customers and
limiting of permitted maximum active power.
That function is realized at the request of electricity distributor.
Switching module may be realized as:

Integrated switching module (bistable switch). Characteristics of integrated switching
module are given in the item 1.1 of the Chapter Functional Requirements for switching
module (bistable switch).

External switching module (bistable switch). Characteristics of external switching
module are given in the item 1.2 of the Chapter Functional Requirements for switching
module (bistable switch).
In the case of meter with external switching module, meter functions are not conditioned by
connecting external switching module. Exceptions are only the options of consumption
management-remote disconnection/connection of customers and limiting of permitted
maximum power.
In the course of meter parameterisation it should be possible to define the category (group) to
which the meter belongs, in terms of consumption management function realisation in the
case of simultaneous disconnection/connection of switching modules with the larger number
of users.
Switch reclosing is programmable and there are two switch operation regimes:
2.3.1. “CONDITIONAL SWITCH RECLOSING”
After receiving instructions for reconnection/expiry of penalty time, it is necessary to confirm
switch reclosing locally via key/keys. The meter (e.g. on display) indicates a corresponding
notification that the condition necessary for connection has been achieved, and that key
confirmation is expected.
2.3.2. “AUTOMATIC SWITCH RECLOSING”
After receiving instructions for reconnection/expiry of penalty time, the switch is automatically
reconnected.
2.3.3. CONTROL OUTPUT
Meter has at least one control output (independent relay) for signalling of current tariff.
Control output is galvanically separated as a relay, with minimum technical characteristics
230V, 100mA, whose connections are executed on meter terminal.
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Activation of this output is primarily done automatically in accordance with the current tariff
programme (low tariff signalling). However, the manner of activation of control output can be
programmed.
2.3.4. LIMITING OF PERMITTED MAXIMUM POWER
Meter has software possibility of limiting power with which the customer can load the power
network, by entering limiting value (power limit), time tolerance period of such load (overload
time) and penalty time of customer disconnection with corresponding registers in the meter
memory. Meter has the possibility of entering two power limit levels – one value for ‘normal’
level, in accordance with the contracted value, and other, lower value, activated upon AMM
Centre command, in case of electricity reductions within the system.
Values of power limit, permitted overload time and penalty time may be set remotely and
locally.
Power limit is the value of contracted active power maximum contracted between the
customer and electricity distributor.
Permitted overload time is the contracted time contracted between the customer and
electricity distributor and it defines minimum power limit exceeding time after which switching
module is activated.
Penalty time is the contracted time between the customer and electricity distributor and it
defines the time after customer disconnection due to power limit exceedence, during which it
is not possible to reconnect the customer (programmable).
When the meter detects power limit exceedence, after the permitted overload time has
expired, the customer will be disconnected from the network.
After the expiry of ‘penalty time’ reconnection is done in accordance with active switch
operation regime (conditional or automatic switch reconnection).
It is desirable to have the mechanism within AMI system or the meter itself that would inform
the customer on the status of management consumption (for example that the limit is
exceeded and the customer shall be disconnected from the network, i.e. there was a
disconnection since the limit has been exceeded, i.e. that the conditions for reconnection were
met etc.).
Special Event Log records entries for at least 10 previous disconnections, i.e. reconnections of
the switching module, with the time stamp and switching module status.
2.3.5. REMOTE DISCONNECTION/CONNECTION OF THE CUSTOMER (ELECTRICITY SUPPLY
INTERRUPTION)
Switching module for remote disconnection/connection of the customer may be activated via
AMM Centre command (unsettled financial liabilities of the customer against electricity
distributor).
Only phase disconnection shall be done during remote disconnection, while reconnection is
executed in accordance with active switch operation regime (conditional or automatic switch
closing).
Special Event Log records entries for at least 10 previous disconnections, i.e. reconnections of
the switching module, with the time stamp and switching module status.
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2.4.
ELECTRICITY QUALITY METERING
2.4.1. UNDER AND OVER VOLTAGES
Meter registers under-voltage/overvoltage occurrence event and termination of the latter.
Events are entered into a special event log (electricity quality log) with the date/time of event,
with the capacity of at least 10 entries.
Under-voltage and overvoltage thresholds may be adjusted. Initially: under-voltage = -20% Un,
overvoltage = +15% Un.
2.4.2. SUPPLY INTERRUPTION REGISTRATION
Meter registers supply interruptions in accordance with SRPS ЕN 50160.
Meter registers the number and total duration of short-term supply interruptions (supply
interruptions shorter than 3 minutes) and long-term supply interruptions (supply interruptions
longer than 3 minutes), recorded in the electricity quality log. Meter records corresponding
codes into electricity quality log for each supply interruption.
2.5.
SELF-CHECK
Meter has a self-check function implemented. The purpose of this function is to verify proper
execution of basic meter functions.
Meter performs self-check during network connection, i.e. after every supply restoration
(power – up).
Self – check must verify the following:

Memory integrity of the meter

Meter statuses and alarms
In addition to these, the following checks may be performed: connection check towards
external communication module, voltage presence, etc.
Errors discovered by Self-check procedure are entered into the Event Log.
2.6.
DATA SECURITY
Local security
For the purpose of data security, locally accessed data have to be protected by access right
verification with at least two access levels.

The first protection level is protection against unauthorised data reading via optical
port and it is realised through software package installed on the handheld
device/laptop, presenting itself to the meter, enabling data transfer and reading.

The second level of protection is protection against local unauthorised changes of
meter parameters. These actions over meter are enabled either after removal of
terminal cover (violation of distribution company seal) either only after verification of
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user type of software package installed on the handheld device/laptop, as well as meter
password.
Each change of parameters shall be registered in the standard Event Log with the date and
time of change.
Registers storing accounting data may not be changed.
Remote parameterisation of the meter shall be enabled only after entering the corresponding
password, whereas, AMM Centre software records permanently the data about the user, time
and type of action.
Communication security
The meter must fully support DLMS Security as described in the DLMS/COSEM Green Book, 7th
ed., section 9.2 ( layer 7 of OSI model)
In addition, meter must encrypt data using Advanced Encryption Standard (AES) at least at one
of:
● Layer 2 (IEEE 802.15.4g or IEEE P1901.2)
● Layer 3 (IP Security [IPsec])
In this context, the meter must store and manage the keys in a secure way
The meter must raise an alarm if a meter's key is changed for more than x time per hour. (x to
be defined as changeable parameter)
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREEPHASE METERS OF ACTIVE AND REACTIVE ELECTRICITY
CT CONNECTED C/I METER
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1. TECHNICAL CHARACTERISTICS FOR THREE-PHASE METERS OF ACTIVE AND
REACTIVE ELECTRICITY FOR SEMI-INDIRECT CONNECTION (THREE-PHASE CT
CONNECTED C/I METER)
1.1.
GENERAL TECHNICAL CHARACTERISTICS
1.1.1. OPERATION MODE - CONSTRUCTION:
Meter shall be electronic (static) for three-phase four-wire semi-indirect connection with three
metering systems and operating in all four quadrants.
1.1.2. RATED (REFERENCE) VOLTAGE:
3 x 230/400 (-20%, +15%)V.
1.1.3. RATED CURRENT:
5 (6) А.
1.1.4. RATED FREQUENCY:
50 Hz.
1.1.5. AUXILIARY CONSUMPTION OF THE METER:
Auxiliary mean power of each voltage circuit under reference voltage, reference temperature
of 23°C and reference frequency shall not exceed the value of 3 W and 15 VA (SRPS EN 6205361 standard).
Auxiliary consumption of each meter current circuit under basic current, reference frequency
and reference temperature of 23°C shall not exceed the value of 4 VA (SRPS EN 62053-61
standard).
1.1.6. MINIMUM ACCURACY CLASS:
For active energy and power
SRPS EN 62053-21 standard
1
SRPS EN 50470-3 standard
B
For reactive energy
SRPS EN 62053-23 standard
3
1.1.7. ANTICIPATED OPERATION LIFE:
minimum 15 years.
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1.1.8. SIZE (HOUSING, TERMINAL AND COVERS):
Dimensions (main measures) have to be done according to Figure 1.
All measures are given in mm.
b1
b2
150± 1 ≤ 180
C
h1
h2
h3
h48
≤ 150
≤ 260
≤ 280
≤ 380
≥40
Figure 10 - General meter draft
Dimension h4 has to fulfil the indicated condition for all conductor introductions, regardless of
the shape of the cover and it is measured from the lowest part of the terminal to lower part of
its cover vertically below the conductor introductions on terminal.
8
Procuring Entity retains the right to, in accordance with its needs, also define other values for
minimum dimension of h4
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1.1.9. TERMINAL
Meter lines in the terminal for direct connection are coupled with clamps with copper rail and
one or two screws, or capsular clamps according to the standard SRPS EN 62052 – 11.
Each clamp screw shall have the size and corresponding travel to, during maximum moment of
re-screwing the screw defined by manufacturer, fully and reliably fasten the conductor and
secure reliable and secure mechanical and electrical connection of current rail with the
conductor, without additional interventions on the conductor (bending, cross-section increase,
etc.).
Auxiliary and control terminals are executed under the ‘PLUG IN’ principle or through
corresponding clamps.
1.1.10. DISPLAY
Metered values and characteristic codes are represented on LC display. Presentation of
metered values and characteristic codes shall be easily readable even in badly lit environment,
as well as under direct lighting.
Display may be executed as segment, “dot matrix” and other, when the data presentation is
provided in accordance with the request.
LC display operates in automatic and manual display regime. Transition between automatic
and manual display operation regime is executed in a simple manner, e.g. by pressing the
key/keys. Default display regime is automatic, to which the display returns from manual display
after corresponding idle period (keys are not pressed).
Under automatic regime, values of metered and registered values are shown cyclically. Initially,
only accounting elements and current date and time are cyclically changed in the period of
minimum 5 to 20 sec on meter display.
Under manual display regime (value display regime based on selection), access should be
enabled to the standard data menu (accounting data, current power, voltages, currents, etc).
If display elements are blinking, this shall have the frequency of about 1 Hz.
Presentation of metered values covers minimum 8 (eight) digits, while there is minimum 6 (six)
whole digits, and minimum 2(two) decimal digits.
Display of maximum power (maxigraph) has minimum 5 (five) digits, while at least 2 (two)
digits are used for display of decimal digits, and the remaining for whole digits.
Minimum 5 (five) digits are anticipated for display of characteristic codes.
Display of metered values and characteristic codes shall be clearly separated from one another.
Characteristic codes are in accordance with SRPS EN 62056-61 (OBIS).
Figures for value display shall at least be:

For metered values
7 mm

For characteristic codes
5 mm
Corresponding symbols are turned off (‘fade out’) during absence of individual phase voltages,
i.e. in accordance with current direction of energy flow.
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Minimum following information have to be displayed:

Metered values

Units of metered values

Characteristic code in accordance with SRPS EN 62056-61 (OBIS)

Indication of phase presence

Indication of energy flow direction

Indication of current tariff
The approach for calculation elements for previous calculation periods (minimum for 3 (three)
period) is realized in a very simple manner, by which the values grouped according to
calculation period are chronologically listed, starting from the last calculation period and then
the previous ones.
1.1.11. KEYS
Meter has at least one easily accessible key for menu scrolling. Key, i.e. keys enable menu
scrolling functions, selection of desired menu, return to the previous menu level, as well as
return to automatic operation regime.
1.1.12. NUMBER OF TARIFFS
Meter has the possibility of storing metered values in min. 4 (four) tariff registers.
1.1.13. IMPULSE (TEST) TERMINALS
Meter has at least two impulse terminals. One shall be optical (via LE diode), the other
electrical, with galvanic insulation, passive and executed on a corresponding terminal
connection.
1.1.14. CHARACTERISTICS OF IMPULSE TERMINALS
Characteristics of impulse terminals of the meter are realised according to the standard SRPS
EN 62053 – 31 i.e. SRPS EN 62052 – 11.
1.1.15. METER CONSTANT
Meter constant is expressed by the number of impulses per energy unit (imp/kWh or kVArh),
amounting to:
Electrical
–
5000 imp/KWh (imp/kVArh)
Optical
–
10000 imp/KWh (imp/kVArh)
1.1.16. TEMPERATURE RANGE AND CLIMATIC CONDITIONS
Meter functions under the standard temperature range for climatic area in which JP EPS
customers are located.
Operating temperature is within the range from – 25°C to + 55°C.
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Meter functions under the conditions of relative humidity from 95% in the period of 24 hours.
1.2.
OTHER TECHNICAL CHARACTERISTICS
1.2.1. METER HOUSING – MATERIALS, SHAPE AND FORM OF DEVICES
All meter housing parts, including the terminal shall be made of material resistant to
mechanical impact, humidity, UV radiation and self-extinguishing characteristics in accordance
with the requirements indicated by SRPS EN 62052–11 standard.
Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN
62052 – 11).
Meters shall use the space to the best possible extent in the course of transport and storage
and they shall also be stored as compact whole. Buckles and openings serving for meter
fastening to the base of installation cubicles shall be manufactured so that the meter can be
fastened well after mounting.
Meter which anticipates installation of external communication module in meter housing
should contain space for communication module installation (point 2.2.1). This space shall not
overlap with the space anticipated for other purposes (meter wiring, tariff control terminals,
etc.) and not disturb direct access to the terminal and auxiliary contacts. This space shall be
anticipated either under the terminal cover or below a special cover, but not below metering
part cover (replacement of communication module shall be done without affecting the state
seal).
Total dimensions (main measures) of the meter as well as meter with installed external
communication module shall be done in accordance with dimensions from item 1.1.8.
1.2.2. IRREGULAR CONNECTION AND NEUTRAL CONDUCTOR DISCONNECTION
1.2.2.1 IRREGULAR CONNECTION
In case of the detection of phase and neutral conductor crossing, the meter continues to
operate, but not necessarily within specified accuracy class, and without time restriction. After
the reestablishment of nominal mode, the meter shall continue regular operation within the
rated accuracy class.
1.2.2.2 NEUTRAL CONDUCTOR DISCONNECTION
In case of neutral conductor disconnection before the meter (‘neutral’ disappearance), the
meter shall continue operating, without obligation for this to be within the rated accuracy
class, without time restriction. After re-establishment of nominal regime, the meter shall
continue operation within the rated accuracy class.
1.2.2.3 DISCONNECTION OF ONE OR TWO PHASES
Meter shall operate properly within the rated accuracy class boundaries in case of
disconnection of one or two phases (simultaneous disconnection of voltage and current in that
measuring system).
1.2.3. ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS
Meter shall meet norms required by regulations from this field under SRPS EN 62052 – 11 and
SRPS EN 62053 – 21 standards, i.e. EN 50470-1 and EN 50470-3 (for meters under MID
Directive).
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1.2.4. METER LABELS
Basic meter data, given in the following table (items 1 – 11) shall completely be labelled on the
meter in accordance with SRPS EN 62052 – 11 standard i.e. SRPS EN 50470-1 (for meters
according to MID Directive).
In addition to these data, meter shall have the following data from the table (items 12 – 15).
Data shall be inerasable, and located on the front side of the meter.
Bar code with the type of the meter from item 16 is optional, and it may be included in the
form of the bar code in item 15.
Connection diagram with terminal labels (item 17 from the following table) may be located on
some of the covers.
№
Type of label
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
12.
13.
14.
Serial number
Name and brand of the manufacturer
Type label
Rated accuracy class
Year of manufacture
Type approval label (official label of the competent authority)
Reference voltage
Rated frequency
Basic and maximum current
Constants of output impulses
Class II insulation level label
Communication protocol
Accounting value code label shown on LC display
Protection class label
Label in the form of a barcode with the meter serial number. Serial number in
the barcode form shall be the same as the serial number under № 1 of this
table, that is included with no ambiguity.
Label in the form of a barcode with the meter type. Type label in the barcode
form shall be the same as the type label under № 3 of this table, i.e. mark the
type of meter in the same way.
Connection diagram with labels (numbers) of contact points
15.
16.
17.
1.2.5. SEALING
Meter is constructed to provide a corresponding protection level against dust and humidity
penetration. According to SRPS EN 60529 meters are manufactured to provide the protection
level of at least IP 51.
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2. METER FUNCTIONS
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS
Meter shall measure and register in all four energy quadrants.
2.1.1. ACTIVE ENERGY
The meter measures, registers and displays active energy within the rated accuracy class.
Meter measures imported and exported active energy (register labels 1.8.x and 2.8 x in
accordance with SRPS EN 62056-61 (OBIS)).
2.1.2. REACTIVE ENERGY
The meter measures, registers and displays reactive energy within the rated accuracy class.
The meter measures imported and exported reactive energy (register labels 3.8.x and 4.8x in
accordance with SRPS EN 62056-61 (OBIS)).
2.1.3. MAXIMUM POWER
The meter measures, registers and displays maximum mean active power under all tariffs and
in both directions (register labels 1.6.x and 2.6 x in accordance with SRPS EN 62056-61 (OBIS)).
Power integration period is initially 15 minutes. This value is programmable and display of this
value is easily accessible in manual display operating mode and remotely. Manual maxi graph
reset is not possible.
2.1.4. INSTANTANEOUS ACTIVE POWER
The meter measures and displays on request current active power on LC display.
2.1.5. PROFILES OF METERED AND REGISTERED VALUES
Meter shall have the possibility to record at least 2 (at the request of electricity distributor
additional 2) profiles of metering or registered values. Each profile should support the
recording of at least 5 selected values (channels). Sampling period inside each profile can be
independently set.
Change of all recording and registering parameters of metering and registered values may be
done locally (via optical port) and remotely (via external communication).
Initially, meter records the following profiles:
2.1.5.1 LOAD PROFILE
Meter records and registers the load profile (mean active power value). Integration period is
initially 15 minutes. In the load profile, together with corresponding block of registered mean
active power value, the data which clearly defines when the block is recorded is also
memorised.
Total capacity for load profile storage shall enable memorising of at least 4320 power metering
records.
2.1.5.2 PROFILE OF HOURLY CONSUMPTION VALUES
Meter records and registers hourly consumption values each 60 minutes. Hourly value
recording and registering time is initially at the full hour.
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Hourly consumption values can be displayed absolutely (register values) or relatively (register
increments).
Memory for the storage of profiles of hourly values of meter registers has the capacity of at
least 24 entries, under FIFO principle.
2.1.6. EVENT LOG
Meter memorises events related to metering, adjustment and handling into the special
memory registers (organised under FIFO principle). A record in the memory is generated for
each event memorising the type of event, time stamp and meter status when the event
occurred.
Each of those memory registers is separate Event log for the type of event (events related to
the electricity quality, metering integrity, consumption management etc.) It is possible to
integrate events into one unique Event log.
Meter registers at least 200 events.
Event coding as well as the type of events entered in the Event Log should be organised under
the recommendations given in IDIS or equivalent specification.
Event Log is not erasable via any external intervention.
2.1.7. VOLTAGE METERING
Meter measures and displays effective voltage value on request.
2.1.8. CURRENT METERING
Meter measures and displays effective current value on request.
2.1.9. PHASE PRESENCE
Meter displays phase voltage presence on the connected conductors. Phase display function
provides information on certain phase presence.
2.1.10. TIME AND DATE
Meter displays time and date from internal switching clock.
2.1.11. INTERNAL CLOCK
Accuracy and other features of internal clock shall be realised in accordance with SRPS EN
62052-21 and SRPS EN 62054-21 standards. Setting and adjustment of time and other internal
clock features shall be realised in the same manner as in the case of energy value
parameterisation and via the same communication ports.
Internal clock supply shall be realised as basic and stand-by. Basic supply comes from the
power grid.
Stand-by supply provides data storing of real time.
Meter possesses real time calendar.
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2.1.12. STANDBY SUPPLY
Stand-by supply of internal clock shall be realised via battery or super capacitor, where the
super capacitor provides data storing for minimum 7 days.
Battery operating life is minimum 10 years.
If battery operating life is shorter than the seal validity period of the Measures and Precious
Metals Directorate, battery change has to be realized in such a way not to require removal of
the Measures and Precious Metals Directorate seal. In this case battery access shall be
protected by a special seal (electricity distributor seal).
Battery change shall be realised without the loss of meter data during the time anticipated for
battery change. During battery change process, clock on the display is not conditioned.
In addition to internal clock, battery/ super capacitor may supply a corresponding part of
meter memory: e.g. part of the memory for the storage of communication parameters, etc.,
but not master or accounting data.
Battery state testing function shall be realised inside the meter. If irregular battery state is
detected (failure, if the battery is empty or if it does not exist), the function of clear display of
irregular state is realized and (preferably) entered into Event Log.
2.1.13. DAYLIGHT SAVING TIME – DST
Meter shall possess automatic daylight saving time function, according to the calendar of
Central European Time – CET.
2.1.14. CURRENT TARIFF
Meter shall have continuous display of current active tariff register, regardless of its display
mode.
2.1.15. LOCAL TARIFF REGISTER MANAGEMENT
Local tariff register management shall be realised via internal clock.
Tariff programme shall anticipate the possibility of defining four different seasons, at least
three different days within the season and two different days for holidays.
Tariffs may be changed during one day for at least eight times.
2.1.16. METERING INTEGRITY
Meters shall have metering integrity violation (terminal cover opening, meter housing opening,
parameter change, strong magnetic field impact on the meter, etc.) recording and signalling
function.
If the meter housing is “sealed for life“ in such a manner that it cannot be opened without
permanent, clearly visible and apparent deformation or damage of meter housing or its parts,
recording function for meter housing opening is not necessary.
For each of the indicated events, Event Log shall make a record with a time stamp when this
event occurred.
2.1.16.1 DETECTION OF STRONG MAGNETIC FIELD
Meter shall have realised strong magnetic field detection function which can influence its
regular operation.
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Upon detecting magnetic field that can influence its regular operation, time and date of
detection of magnetic field is recorded in the Event Log.
This function shall be realised upon the request of electricity distributor.
2.1.17. DATA STABILITY AND MEMORISING
Master data about the meter (year of manufacture, type label and serial number) shall not be
changeable. In addition to this, electricity data as well as data on maximum 15-minute power
shall not be changeable. These data are located in the part of permanent meter memory and
their integrity is not dependent on the period when meter was not supplied (basic and standby). All other data may be, via communication module (communicator) and IR port, altered
according to the current tariff system and upon the order of authorised persons.
Meter shall record and register (memorise) states of all tariff registers during the accounting
period (first or the last day of the month) and at an exactly defined moment (programmable
locally or remotely).
2.1.18. COUNTDOWN
Meter shall have the reduction blockade of achieved individual tariff registers.
2.1.19. DATA STORAGE PERIOD
Accounting data (active and reactive imported and exported energy and maximum mean
power with date and time of achievement, registered according to tariffs) shall be stored for at
least 12 last accounting periods (usually 12 months). After the new cycle starts, space shall be
provided for the new memory block, with the deletion of the first (the oldest) in the sequence
of registers.
Total registered electricity cannot be deleted.
2.2.
ADDITIONAL FUNCTIONS
2.2.1. COMMUNICATION WITH THE METER
Meter shall have communication between the meter and different devices (hand terminals,
communication modules, registers, data concentrators, etc.). Communication shall be
executed via interfaces, with the usage of data model, application layer and identification
structure according to DLMS/COSEM.
Meter shall have DLMS/COSEM certificate issued based on the verification with the latest
version of testing software (at least version 2.0).
Electrical interface is galvanically insulated from the metering part of the meter.
Communication part of the meter is executed to enable communication with the meter via all
meter communication interfaces, without impact on the measuring part of the meter.
External communication is executed via special communication module, situated in the
corresponding space (point 1.2.1).
All electrical connections of communication module with the meter is achieved under PLUG IN
principle (connector to connector or connector on a short cable / cables), whereas the total
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consumption of the meter and communication module does not exceed the requirement from
point 1.1.5.
Communication module shall not logically depend from the meter, i.e. replacement of old and
installation of new communication module is reduced to simple physical replacement, while
software in the concentrator/AMM Centre performs logic replacement.
Communication module uses the protocol defined according to DLMS/COSEM.
Meter shall have the following interfaces:
1. Optical interface: infrared IR port with physical characteristics in accordance with
SRPS EN 62056-21.
2. Electrical interface no.1, used for connection with communication module for
remote reading (cellular modem, etc.),
Implemented communication protocol is DLMS/COSEM
3. Electrical interface no.2 used for meter connection with HAN (Home Area Network)
connection of modem/module (depending on the manufacture).
It is realized upon the request of electricity distributor.
Electrical interface no.2 and other specific interfaces can be realised:

by separate connector on the meter itself (e.g. auxiliary contacts) or

by separate connector at the communication module for remote reading (cellular
modem, etc.), or

by relevant module for extension of external interfaces. In that case the mentioned
module is delivered with the meter.
2.2.1.1 CELLULAR COMMUNICATION
At the request of the Procuring Entity, the meter may be equipped with cellular
communication module which is connected to the meter via specific electrical interface,
whereas the requests from items 1.1.8 (dimensions) and 1.2.1 (housing) are fulfilled.
Characteristics of cellular communication module are given in the Chapter Technical
Characteristics and functional requests for cellular modem items 1, 2.1 and 2.1.1.
2.3.
CONTROL OUTPUT
Meter has at least one control output (independent relay) for signalling of current tariff.
Control output is galvanically separated as a relay, with minimum technical characteristics
230V, 100mA, whose connections are executed on meter terminal.
Activation of this output is primarily done automatically in accordance with the current tariff
programme (low tariff signalling). However, the manner of activation of control output can be
programmed.
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2.4.
ELECTRICITY QUALITY METERING
2.4.1. UNDER AND OVER VOLTAGES
Meter registers under-voltage/overvoltage occurrence event and termination of the latter.
Events are entered into a special Event Log (electricity quality log) with the date/time of event,
with the capacity of at least 10 entries.
Under-voltage and overvoltage thresholds may be adjusted. Initially: under-voltage = -20% Un,
overvoltage = +15% Un.
2.4.2. SUPPLY INTERRUPTION REGISTRATION
Meter registers supply interruptions in accordance with SRPS ЕN 50160.
Meter registers the number and total duration of short-term supply interruptions (supply
interruptions shorter than 3 minutes) and long-term supply interruptions (supply interruptions
longer than 3 minutes), recorded in the electricity quality log. Meter records corresponding
codes into electricity quality log for each supply interruption.
2.4.3. POWER FACTOR METERING (cosφ)
The meter measures and registers power factor.
2.5.
SELF-CHECK
Meter should have a self-check function implemented. The purpose of this function is to verify
proper execution of basic meter functions.
Meter performs self-check during network connection, i.e. after every supply restoration
(power – up).
Self – check must verify the following:

Memory integrity of the meter

Meter statuses and alarms
In addition to these, the following checks may be performed: connection check towards
external communication module, voltage presence, etc.
Errors discovered by Self-check procedure are entered into the Event Log.
2.6.
DATA SECURITY
Local security
For the purpose of data security, locally accessed data have to be protected by access right
verification with at least two access levels.

The first protection level is protection against unauthorised data reading via optical
port and it is realised through software package installed on the handheld
device/laptop, presenting itself to the meter, enabling data transfer and reading.

The second level of protection is protection against local unauthorised changes of
meter parameters. These actions over meter are enabled either after removal of
terminal cover (violation of distribution company seal) either only after verification of
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user type of software package installed on the handheld device/laptop, as well as meter
password.
Each change of parameters shall be registered in the standard Event Log with the date and
time of change.
Registers storing accounting data may not be changed.
Remote parameterisation of the meter shall be enabled only after entering the corresponding
password, whereas, AMM Centre software records permanently the data about the user, time
and type of action.
Communication security
The meter must fully support DLMS Security as described in the DLMS/COSEM Green Book, 7th
ed., section 9.2 ( layer 7 of OSI model)
In addition, meter must encrypt data using Advanced Encryption Standard (AES) at least at one
of:
● Layer 2 (IEEE 802.15.4g or IEEE P1901.2)
● Layer 3 (IP Security [IPsec])
In this context, the meter must store and manage the keys in a secure way
The meter must raise an alarm if a meter's key is changed for more than x time per hour. (x to
be defined as changeable parameter)
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TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR
THREE-PHASE METERS OF ACTIVE AND REACTIVE ELECTRICITY
CT VT CONNECTED C/I METER
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1. TECHNICAL CHARACTERISTICS FOR THREE-PHASE METERS OF ACTIVE AND
REACTIVE ELECTRICITY FOR INDIRECT CONNECTION (THREE-PHASE CT VT
CONNECTED C/I METER)
1.1.
GENERAL TECHNICAL CHARACTERISTICS
1.1.1. OPERATION MODE - CONSTRUCTION:
Meter shall be electronic (static) for three-phase four-wire indirect connection, i.e. three-phase
three-wire connection with three metering systems and operating in all four quadrants.
1.1.2. RATED (REFERENCE) VOLTAGE:
Under three system metering
3 x 100/√3V
Under two system metering (Aaron connection)
3 x 100V
1.1.3. RATED CURRENT:
5 (6) А
1.1.4. RATED FREQUENCY:
50 Hz.
1.1.5. AUXILIARY CONSUMPTION OF THE METER:
Auxiliary mean power of each voltage circuit under reference voltage, reference temperature
of 23°C and reference frequency shall not exceed the value of 3 W and 15 VA (SRPS 62053-61
standard).
Auxiliary consumption of each meter current circuit under basic current, reference frequency
and reference temperature of 23°C shall not exceed the value of 1 VA.
1.1.6. MINIMUM RATED ACCURACY CLASS:
Depending on the electricity distributor’s needs, minimum rated accuracy class of the meter is:
For active energy and power (IMG ACC 0.5S)
SRPS EN 62053-22 standard
0.5S
SRPS EN 50470-3 standard
C
For reactive energy
SRPS EN 62053-23 standard
3
or
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For active energy and power (IMG ACC 0.2S)
SRPS EN 62053-22 standard
0.2S
For reactive energy
SRPS EN 62053-23 standard
2
1.1.7. ANTICIPATED OPERATION LIFE:
minimum 15 years
1.1.8. SIZE (HOUSING, TERMINAL AND COVERS):
Dimensions (main measures) have to be done according to Figure 1.
All measures are given in mm.
b1
b2
150± 1 ≤ 180
C
h1
h2
h3
h49
≤ 150
≤ 260
≤ 280
≤ 380
≥40
9
Procuring Entity retains the right to, in accordance with its needs, also define other values for
minimum dimension of h4
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Figure 11 - General meter draft
Dimension h4 has to fulfil the indicated condition for all conductor introductions, regardless of
the shape of the cover and it is measured from the lowest part of the terminal to lower part of
its cover vertically below the conductor introductions on terminal.
1.1.9. TERMINAL
Meter lines in the terminal for direct connection are coupled with clamps with copper rail and
one or two screws, or capsular clamps according to the standard SRPS EN 62052 – 11.
Each clamp screw shall have the size and corresponding travel to, during maximum moment of
re-screwing the screw defined by manufacturer, fully and reliably fasten the conductor and
secure reliable and secure mechanical and electrical connection of current rail with the
conductor, without additional interventions on the conductor (bending, cross-section increase,
etc.).
Auxiliary and control terminals are executed under the ‘PLUG IN’ principle or through
corresponding clamps.
1.1.10. DISPLAY
Metered values and characteristic codes are represented on LC display. Presentation of
metered values and characteristic codes shall be easily readable even in badly lit environment,
as well as under direct lighting.
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Display may be executed as segment, “dot matrix” and other, when the data presentation is
provided in accordance with the request.
LC display operates in automatic and manual display regime. Transition between automatic
and manual display operation regime is executed in a simple manner, e.g. by pressing the
key/keys. Default display regime is automatic, to which the display returns from manual display
after corresponding idle period (keys are not pressed).
Under automatic regime, values of metered and registered values are shown cyclically. Initially,
only accounting elements and current date and time are cyclically changed, by which the
period of display is from 5 to 20 sec.
Under manual display regime (value display regime based on selection), access should be
enabled to the standard data menu (accounting data, current power, voltages, currents, etc.).
If display elements are blinking, this shall have the frequency of about 1 Hz.
Presentation of metered values covers minimum 8 (eight) digits, while there is minimum 5
(five) whole digits, and minimum 3 (three) decimal digits.
Display of maximum power (maxigraph) has minimum 5 (five) digits, while at least 3 (three)
digits are used for display of decimal digits, and the remaining for whole digits.
Minimum 5 (five) digits are anticipated for display of characteristic codes.
Display of metered values and characteristic codes shall be clearly separated from one another.
Characteristic codes are in accordance with SRPS EN 62056-61 (OBIS).
Figures for value display shall at least be:

For metered values
7mm

For characteristic codes
5mm
Corresponding symbols are turned off (‘fade out’) during absence of individual phase voltages,
i.e. in accordance with current direction of energy flow.
Minimum following information have to be displayed:

Metered values

Units of metered values

Characteristic code in accordance with SRPS EN 62056-61 (OBIS)

Indication of phase presence

Indication of energy flow direction

Indication of current tariff
The approach for calculation elements for previous calculation periods (minimum for 3 (three)
period) is realized in a very simple manner, by which the values grouped according to
calculation period are chronologically listed, starting from the last calculation period and then
the previous ones.
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1.1.11. KEYS
Meter has at least one easily accessible key for menu scrolling. Key, i.e. keys enable menu
scrolling functions, selection of desired menu, return to the previous menu level, as well as
return to automatic operation regime.
1.1.12. NUMBER OF TARIFFS
Meter has the possibility of storing metered values in min. 4 (four) tariff registers.
1.1.13. IMPULSE (TEST) TERMINALS
Meter has at least two impulse terminals. One shall be optical (via LE diode), the other
electrical, with galvanic insulation, passive and executed on a corresponding terminal
connection.
1.1.14. CHARACTERISTICS OF IMPULSE TERMINALS
Characteristics of impulse terminals of the meter are realised according to the standard SRPS
EN 62053 – 31 i.e. SRPS EN 62052 – 11.
1.1.15. METER CONSTANT
Meter constant is expressed by the number of impulses per energy unit (imp/kWh or kVArh),
amounting to:
Electrical – 20000 imp/KWh (imp/kVArh)
Optical – 40000 imp/KWh (imp/kVArh)
1.1.16. TEMPERATURE RANGE AND CLIMATIC CONDITIONS
Meter functions under the standard temperature range for climatic area in which JP EPS
customers are located.
Operating temperature is within the range from – 25°C to + 55°C.
Meter functions under the conditions of relative humidity from 95% in the period of 24 hours.
1.2.
OTHER TECHNICAL CHARACTERISTICS
1.2.1. METER HOUSING – MATERIALS, SHAPE AND FORM OF DEVICES
All meter housing parts, including the terminal shall be made of material resistant to
mechanical impact, humidity, UV radiation and self-extinguishing characteristics in accordance
with the requirements indicated by SRPS EN 62052–11 standard.
Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN
62052 – 11 standard).
Meters shall use the space to the best possible extent in the course of transport and storage
and they shall also be stored as compact whole. Buckles and openings serving for meter
fastening to the base of installation cubicles shall be manufactured so that the meter can be
fastened well after mounting.
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Meter which anticipates installation of external communication module within meter housing
should contain space for communication module installation (point 2.2.1). This space shall not
overlap with the space anticipated for other purposes (meter wiring, tariff control terminals,
etc.) and not disturb direct access to the terminal and auxiliary contacts. This space shall be
anticipated either under the terminal cover or below a special cover, but not below metering
part cover (replacement of communication module shall be done without affecting the state
seal).
Total dimensions (main measures) of the meter as well as meter with installed external
communication module shall be done in accordance with dimensions from item 1.1.8.
1.2.2. DISCONNECTION OF ONE OR TWO PHASES
Meter for three-system measurement shall operate properly within the rated accuracy class in
case of disconnection of one or two phases (simultaneous disconnection of voltage and current
in that measurement system).
1.2.3. ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS
Meter shall meet norms required by regulations from this field under SRPS EN 62052 – 11 and
SRPS EN 62053 – 22 standards, i.e. SRPS EN 50470-1 and SRPS EN 50470-3 (for meters under
MID Directive).
1.2.4. METER LABELS
Basic meter data, given in the following table (items 1 – 11) shall completely be labelled on the
meter in accordance with SRPS EN 62052 – 11 standard i.e. SRPS EN 50470-1 (for meters under
MID Directive).
In addition to these data, meter shall have the following data from the table (items 12 – 15).
Data shall be inerasable, and located on the front side of the meter.
Bar code with the type of the meter from item 16 is optional, and it may be included in the
form of the bar code in item 15.
Connection diagram with terminal labels (item 17 from the following table) may be located on
some of the covers.
№
1.
2.
3.
4.
5.
6.
7.
8.
9.
10.
11.
Type of label
Serial number
Name and brand of the manufacturer
Type label
Rated accuracy class
Year of manufacture
Type approval label (official label of the competent authority)
Reference voltage
Rated frequency
Basic and maximum current
Constants of output impulses
Class II insulation level label
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12.
13.
14.
15.
16.
17.
Communication protocol
Accounting value code label shown on LC display
Protection class label
Label in the form of a barcode with the meter serial number. Serial number in
the barcode form shall be the same as the serial number under № 1 of this
table, i.e. included with no ambiguity.
Label in the form of a barcode with the meter type. Type label in the barcode
form shall be the same as the type label under № 3 of this table, i.e. mark the
type of meter in the same way.
Connection diagram with labels (numbers) of contact points
1.2.5. SEALING
Meter is constructed to provide a corresponding protection level against dust and humidity
penetration. According to SRPS EN 60529 meters are manufactured to provide the protection
level of at least IP 51.
2. METER FUNCTIONS
2.1.
METERING, REGISTRATION AND DISPLAY FUNCTIONS
Meter measures and registers in all four energy quadrants.
2.1.1. ACTIVE ENERGY
The meter measures, registers and displays active energy within the rated accuracy class.
Meter measures imported and exported active energy (register labels 1.8.x and 2.8 x in
accordance with SRPS EN 62056-61 (OBIS)).
Under Aaron connection (two system metering), meter regularly measures and registers active
energy in a manner to use algebra in order to add values of active energy from those two
systems, and then determines whether it belongs to register 1.8x or 2.8 x.
2.1.2. REACTIVE ENERGY
The meter measures, registers and displays reactive energy within the rated accuracy class
boundaries.
The meter measures imported and exported reactive energy (register labels 3.8.x and 4.8x in
accordance with SRPS EN 62056-61 (OBIS)).
Under Aaron connection (two system metering), meter regularly measures and registers active
energy in a manner to use algebra in order to add values of active energy from those two
systems, and then determines whether it belongs to register 3.8.x or 4.8 x.
2.1.3. MAXIMUM POWER
The meter measures, registers and displays maximum mean active power under all tariffs and
in both directions (register labels 1.6.x and 2.6 x in accordance with SRPS EN 62056-61 (OBIS)).
Power integration period is initially 15 minutes. This value is programmable and display of this
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value is easily accessible in manual display operating mode and remotely. Manual maxigraph
reset is not possible.
2.1.4. INSTANTANEOUS ACTIVE POWER
The meter measures and displays on request current active power on LC display.
2.1.5. PROFILES OF METERED AND REGISTERED VALUES
Meter shall have the possibility to record at least 2 (two) (profiles of metering or registered
values. Each profile should support the recording of at least 5 selected values (channels).
Sampling period inside each profile can be independently set.
Change of all recording and registering parameters of metering and registered values may be
done locally (via optical port) and remotely (via external communication).
Initially, meter records the following profiles:
2.1.5.1 LOAD PROFILE
Meter records and registers the load profile (mean active power value). Integration period is
initially 15 minutes. In the load profile, together with corresponding block of registered mean
active power value, the data which clearly defines when the block is recorded is also
memorised.
Total capacity for load profile storage shall enable memorising of at least 4320 power metering
records.
2.1.5.2 PROFILE OF HOURLY CONSUMPTION VALUES
Meter records and registers hourly consumption values each 60 minutes. Hourly value
recording and registering time is initially at the full hour.
Hourly consumption values can be displayed absolutely (register values) or relatively (register
increments).
Memory for the storage of profiles of hourly values of meter registers has the capacity of at
least 24 entries, under FIFO principle.
2.1.6. EVENT LOG
Meter memorises events related to metering, adjustment and handling into the special
memory registers (organised under FIFO principle). A record in the memory is generated for
each event memorising the type of event, time stamp and meter status when the event
occurred.
Each of those memory registers is separate Event log for the type of event (events related to
the electricity quality, metering integrity, consumption management etc.) It is possible to
integrate events into one unique Event log.
Meter registers at least 200 events.
Event coding as well as the type of events entered in the Event Log should be organised under
the recommendations given in IDIS or equivalent specification.
Event Log is not erasable via any external intervention.
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2.1.7. VOLTAGE METERING
Meter measures and displays effective voltage value on request.
2.1.8. CURRENT METERING
Meter measures and displays effective current value on request.
2.1.9. PHASE PRESENCE
Meter indicates phase voltage presence on the connected conductors. Phase indication
function provides information on certain phase presence.
2.1.10. TIME AND DATE
Meter displays time and date from internal switching clock.
2.1.11. INTERNAL CLOCK
Accuracy and other features of internal clock shall be realised in accordance with SRPS EN
62052-21 and SRPS EN 62054-21 standards. Setting and adjustment of time and other internal
clock features shall be realised in the same manner as in the case of energy value
parameterisation and via the same communication ports.
Internal clock supply shall be realised as basic and stand-by. Basic supply comes from the
power grid.
Stand-by supply provides data storing of real time.
Meter possesses real time calendar.
2.1.12. STANDBY SUPPLY
Stand-by supply of internal clock shall be realised via battery or super capacitor, where the
super capacitor provides data storing for minimum 7 days.
Battery operating life is minimum 10 years.
If battery operating life is shorter than the seal validity period of the Measures and Precious
Metals Directorate, battery change has to be realized in such a way not to require removal of
the Measures and Precious Metals Directorate seal. In this case battery access shall be
protected by a special seal (electricity distributor seal).
Battery change shall be realised without the loss of meter data during the time anticipated for
battery change. During battery change process, clock on the display is not conditioned.
In addition to internal clock, battery/supercapacitor may supply a corresponding part of meter
memory: e.g. part of the memory for the storage of communication parameters, etc., but not
master or accounting data.
Battery state testing function shall be realised inside the meter. If irregular battery state is
detected (failure, if the battery is empty or if it does not exist), the function of clear display of
irregular state is realized and (preferably) entered into Event Log.
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2.1.13. DAYLIGHT SAVING TIME – DST
Meter shall possess automatic daylight saving time function, according to the calendar of
Central European Time – CET.
2.1.14. CURRENT TARIFF
Meter shall have continuous display of current active tariff register, regardless of its display
mode.
2.1.15. LOCAL TARIFF REGISTER MANAGEMENT
Local tariff register management shall be realised via internal clock.
Tariff programme shall anticipate the possibility of defining four different seasons, at least
three different days within the season and two different days for holidays.
Tariffs may be changed during one day for at least eight times.
2.1.16. METERING INTEGRITY
Meters shall have metering integrity violation (terminal cover opening, meter housing opening,
parameter change, strong magnetic field impact on the meter, etc.) recording and signalling
function.
If the meter housing is “sealed for life“ in such a manner that it cannot be opened without
permanent, clearly visible and apparent deformation or damage of meter housing or its parts,
recording function for meter housing opening is not necessary.
For each of the indicated events, Event Log shall make a record with a time stamp when this
event occurred.
2.1.16.1. DETECTION OF STRONG MAGNETIC FIELD
Meter shall have realised strong magnetic field detection function which can influence its
regular operation.
Upon detecting magnetic field that can influence its regular operation, time and date of
detection of magnetic field is recorded in the Event Log.
This function shall be realised at the request of electricity distributor.
2.1.17. DATA STABILITY AND MEMORISING
Master data about the meter (year of manufacture, type label and serial number) shall not be
changeable. In addition to this, electricity data as well as data on maximum 15-minute power
shall not be changeable. These data are located in the part of permanent meter memory and
their integrity is not dependent on period when meter was not supplied (basic and stand-by).
All other data may be, via communication module (communicator) and IR port, altered
according to the current tariff system and upon the order of authorised persons.
Meter shall record and register (memorise) states of all tariff registers during the accounting
period (first or last day of the month) and at an exactly defined moment (programmable locally
or remotely).
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2.1.18. COUNTDOWN
Meter shall have the reduction blockade of achieved individual tariff register states.
2.1.19. DATA STORAGE PERIOD
Accounting data (active and reactive imported and exported energy and maximum mean
power with date and time of achievement, registered according to tariffs) shall be stored for at
least 12 last accounting periods (usually 12 months). After the new cycle starts, space shall be
provided for the new memory block, with the deletion of the first (the oldest) in the sequence
of registers.
Total registered electricity cannot be deleted.
2.2.
ADDITIONAL FUNCTIONS
2.2.1. COMMUNICATION WITH THE METER
Meter shall have communication between the meter and different devices (hand terminals,
communication modules, registers, data concentrators, etc.). Communication shall be
executed via interfaces, with the usage of data model, application layer and identification
structure according to DLMS/COSEM.
Meter shall have DLMS/COSEM certificate issued based on the verification with the latest
version of testing software (at least version 2.0).
Electrical interface is galvanically insulated from the metering part of the meter.
Communication part of the meter is executed to enable communication with the meter via all
meter communication interfaces, without impact on the measuring part of the meter.
External communication is executed via special communication module, situated in the
corresponding space (point 1.2.1).
All electrical connections of communication module with the meter is achieved under PLUG IN
principle (connector to connector or connector on a short cable / cables), whereas the total
consumption of the meter and communication module does not exceed the requirement from
point 1.1.5.
Communication module shall not logically depend from the meter, i.e. replacement of old and
installation of new communication module is reduced to simple physical replacement, while
software in the concentrator/AMM Centre performs logic replacement.
Communication module uses the protocol defined according to DLMS/COSEM
Meter shall have the following interfaces:
1. Optical interface: infrared IR port with physical characteristics in accordance with
SRPS EN 62056-21.
2. Electrical interface no.1, used for connection with communication module for
remote reading (cellular modem, etc.),
Implemented communication protocol is DLMS/COSEM
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3. Electrical interface no.2 used for meter connection with HAN (Home Area Network)
connection of modem/module (depending on the manufacture).
It is realized upon the request of electricity distributor.
Electrical interface no.2 and other specific interfaces can be realised:

by separate connector on the meter itself (e.g. auxiliary contacts) or

by separate connector at the communication module for remote reading (cellular
modem, etc.), or

by relevant module for extension of external interfaces. In that case the mentioned
module is exported with the meter.
2.2.1.1. CELLULAR COMMUNICATION
At the request of the Procuring Entity, the meter may be equipped with cellular
communication module which is connected to the meter via specific electrical interface,
whereas the requests from items 1.1.8 (dimensions) and 1.2.1 (housing) are fulfilled.
Characteristics of cellular communication module are given in the Chapter Technical
Characteristics and functional requests for cellular modem, items 1, 2.1 and 2.1.1.
2.3.
ELECTRICITY QUALITY METERING
2.3.1. UNDER AND OVER VOLTAGES
Meter registers under-voltage/overvoltage occurrence event and termination of the latter.
Events are entered into a special event log (electricity quality log) with the date/time of event,
with the capacity of at least 10 entries.
Under-voltage and overvoltage thresholds may be adjusted. Initially: under-voltage = -20% Un,
overvoltage = +15% Un.
2.3.2. SUPPLY INTERRUPTION REGISTRATION
Meter registers supply interruptions in accordance with SRPS ЕN 50160.
Meter registers the number and total duration of short-term supply interruptions (supply
interruptions shorter than 3 minutes) and long-term supply interruptions (supply interruptions
longer than 3 minutes), recorded in the electricity quality log. Meter records corresponding
codes into electricity quality log for each supply interruption.
2.3.3. INDICATION OF TOTAL HARMONIC DISTORTION (THD) FACTOR
The meter has the function to indicate total harmonic distortion factor (THD) or has the
function to generate events in the Event Log in case when previously defined value of THD is
exceeded.
2.3.4. POWER FACTOR METERING (cosφ)
The meter measures and registers power factor.
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2.4.
SELF-CHECK
Meter should have a self-check function implemented. The purpose of this function is to verify
proper execution of basic meter functions.
Meter performs self-check during network connection, i.e. after every supply restoration
(power – up).
Self – check must verify the following:

Memory integrity of the meter

Meter statuses and alarms
In addition to these, the following checks may be performed: connection check towards
external communication module, voltage presence, etc.
Errors discovered by Self-check procedure are entered into the Event Log.
2.5.
DATA SECURITY
Local security
For the purpose of data security, locally accessed data have to be protected by access right
verification with at least two access levels.

The first protection level is protection against unauthorised data reading via optical
port and it is realised through software package installed on the handheld
device/laptop, presenting itself to the meter, enabling data transfer and reading.

The second level of protection is protection against local unauthorised changes of
meter parameters. These actions over meter are enabled either after removal of
terminal cover (violation of distribution company seal) either only after verification of
user type of software package installed on the handheld device/laptop, as well as meter
password.
Each change of parameters shall be registered in the standard Event Log with the date and
time of change.
Registers storing accounting data may not be changed.
Remote parameterisation of the meter shall be enabled only after entering the corresponding
password, whereas, AMM Centre software records permanently the data about the user, time
and type of action.
Communication security
The meter must fully support DLMS Security as described in the DLMS/COSEM Green Book, 7th
ed., section 9.2 ( layer 7 of OSI model)
In addition, meter must encrypt data using Advanced Encryption Standard (AES) at least at one
of:
● Layer 2 (IEEE 802.15.4g or IEEE P1901.2)
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● Layer 3 (IP Security [IPsec])
In this context, the meter must store and manage the keys in a secure way
The meter must raise an alarm if a meter's key is changed for more than x time per hour. (x to
be defined as changeable parameter)
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ADDITIONAL METER FUNCTIONS FOR CONNECTION OF ELECTRICITY
GENERATION FACILITIES
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1. ADDITIONAL METER FUNCTIONS FOR CONNECTION OF ELECTRICITY
GENERATION FACILITIES
According to the additional requests of electricity distributor, for placement to the connection
point of electricity generation facilities on distribution network, meter fulfils all above stated
requests, with additional extension of the following functions. In accordance with electricity
distributor’s needs, mandatory and optional scope of extended functions is defined according
to the meter type.
1.1. MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR METERS WITH DIRECT
CONNECTION
According to the specific request of electricity distributor, due to the specific manner of
electricity measuring on connection points of the electricity generation facilities, functions of
the meters for direct connection (direct metering groups) are mandatory extended with the
following functions.
1.1.1. ACTIVE ENERGY
Meter measures, registers and displays active energy within rated accuracy class range.
Meter measures consumed and delivered active energy (register mark 1.8.х and 2.8.x
according to SRPS EN 62056-61 (OBIS)).
1.1.2. REACTIVE ENERGY
Meter measures, registers and displays reactive energy within rated accuracy class range.
Meter measures consumed and delivered reactive energy (register mark 3.8.х and 4.8.x
according to SRPS EN 62056-61 (OBIS)).
1.1.3. MAXIMUM ACTIVE POWER
Meter measures, registers and displays maximum mean active power under all tariffs and in
both directions (register mark 1.6.x and 2.6.x in accordance with SRPS EN 62056-61 (OBIS)).
Power integration period is initially 15 minutes. This value is programmable with the following
values and display of this value is easily accessible under manual display operation regime and
remotely. Manual maxi graph reset is not possible.
1.1.4. MAXIMUM REACTIVE POWER
Meter measures, registers and displays maximum mean reactive power under all tariffs and in
both directions (register mark 3.6.x and 4.6.x in accordance with SRPS EN 62056-61 (OBIS)).
Power integration period is initially 15 minutes. This value is programmable with the following
values and display of this value is easily accessible under manual display operation regime and
remotely. Manual maxi graph reset is not possible.
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1.2.
MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR CT METERS
According to the specific request of electricity distributor, due to the specific manner of
electricity measuring on connection points of the electricity generation facilities, functions of
the meters for semi-indirect connection (semi-indirect metering groups) are mandatory
extended with the following functions.
1.2.1. MAXIMUM REACTIVE POWER
Meter measures, registers and displays maximum mean reactive power under all tariffs and in
both directions (register mark 3.6.x and 4.6.x in accordance with SRPS EN 62056-61 (OBIS)).
Power integration period is initially 15 minutes. This value is programmable with the following
values and display of this value is easily accessible under manual display operation regime and
remotely. Manual maxigraph reset is not possible.
1.3.
MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR CT VT METERS
According to the specific request of electricity distributor, due to the specific manner of
electricity measuring on connection points of the electricity generation facilities, functions of
the meters for indirect connection (indirect metering groups) are mandatory extended with
the following functions.
1.3.1. MAXIMUM REACTIVE POWER
Meter measures, registers and displays maximum mean reactive power under all tariffs and in
both directions (register mark 3.6.x and 4.6.x in accordance with SRPS EN 62056-61 (OBIS)).
Power integration period is initially 15 minutes. This value is programmable with the following
values and display of this value is easily accessible under manual display operation regime and
remotely. Manual maxigraph reset is not possible.
2. OPTIONAL SCOPE OF ADDITIONAL FUNCTIONS
According to the additional request of electricity distributor and in addition to above stated
mandatory scopes of extended functions, additional extensions of existing functions are
optionally realized for all electricity meters on connection points of electricity generation
facilities.
2.1.
SEALING
According to the additional request of electricity distributor and SRPS EN 60529 meters are
manufactured to provide the protection level of at least IP 52.
2.2.
PROFILES OF METERED AND REGISTERED VALUES
According to the additional request of electricity distributor, meter records and registers the
load profiles of active and reactive power values, in both directions. Integration period is
initially 15 minutes. Corresponding time stamp is recorded in the load profile with
corresponding block of registered active power value.
Total capacity for load profile storage shall enable memorizing of at least 4320 power metering
records.
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2.3.
MAXIMUM APPARENT POWER
According to the additional request of electricity distributor, meter measures, registers and
displays maximum mean apparent power under all tariffs and in both directions (register mark
9.6.x and 10.6.x in accordance with SRPS EN 62056-61 (OBIS)).
Power integration period is initially 15 minutes. This value is programmable with the following
values and display of this value is easily accessible under manual display operation regime and
remotely. Manual maxi graph reset is not possible.
2.4.
MINIMUM POWER FACTOR
According to the additional request of electricity distributor, meter measures, registers and
displays minimum power factor under all tariffs and in both directions (register mark 13.3.x
and 84.3.x in accordance with SRPS EN 62056-61 (OBIS)).
When calculating register 13.3.х, positive active energy values are used.
Power integration period is initially 15 minutes. This value is programmable with the following
values and display of this value is easily accessible under manual display operation regime and
remotely. Manual maxigraph reset is not possible.
2.5.
DATA STORAGE PERIOD
According to the specific additional request of electricity distributor, accounting data (imported
and exported active and reactive electricity; maximum values of imported and exported active
and reactive mean power with date and time of achievement, registered according to tariffs;
maximum values of imported and exported apparent mean power with date and time of
achievement or minimum values of power factor in both directions, with date and time of
achievement) shall be stored for at least 12 last accounting periods (usually 12 months). After
the new cycle starts, space shall be provided for the new memory block, with the deletion of
the last (the oldest) in the sequence of registers.
Total registered electricity cannot be deleted.
3. OPTIONAL SCOPE OF ADDITIONAL FUNCTIONS FOR CT METERS
According to the specific request of electricity distributor, due to the specific manner of
electricity measuring on connection points of the electricity generation facilities, functions of
the meters for semi-indirect connection (CT meters) are optionally extended with the following
functions.
3.1.
RATED ACCURACY CLASS
According to the specific request of electricity distributor, rated accuracy class of semi-indirect
meter for connection of electricity generation facilities is:

0.5S for active energy and active power.

Minimum 3 for reactive energy and power.
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FUNCTIONAL REQUIREMENTS OF METER DATA MANAGEMENT AND
REPOSITORY SYSTEM (MDM/R)
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1.
METER DATA MANAGEMENT AND REPOSITORY SYSTEM
Advanced metering system (AMS) includes the advanced metering infrastructure (AMI),
functions of advanced metering management system (AMM), functions of meter data
management and repository system (MDM/R), as well as accounting and collection functions
of consumed electricity. AMI represents an infrastructure within which data on meter reading
(MR) labelled with exact date and time collected and transferred on daily basis to the advanced
metering control computer (AMCC) within advanced metering management system (AMM)
and further on to the centralised MDM/R system.
AMI (Advanced Metering Infrastructure) system
AMM (Advanced Metering Management) system
AMCC
AMRC
LAN
Households
Concentrator
Industry
WAN
Advanced meters
Electricity buyers
AMCC
AMS (Advanced Metering System) system
Customer support
(Information;
accounting and
collection)
WAN
MDM/R system
(Meter Data Repository)
Electricity delivery
WAN
Metering display
«Firewall»
Regulatory agency
Figure 12–AMS - Advanced Metering System
1.1.
ABBREVIATIONS
Table 1 – Overview of used abbreviations
API
AM
AMCD
AMR
AMRC
AMI
AMM
AMCC
CET
CIM
CIS
Application Program Interface
Asset Management
Advanced Metering Communication Device
Automated Meter Reading
Advanced Metering Regional Collector
Advanced Metering Infrastructure
Automated/Advanced Metering Management
Advanced Metering Control Computer
Central Europe Time
Common Information Model
Customer Information System
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MDM system
(Meter Data
Management)
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COSEM
CPP
DLMS UA
DMS
ISS ELU
IDR
IEC
FTP
LC
LP
LMS
MAM
MDM/R
MM
MR
MS
NO
OMS
POS
POD
RF
RPP
SMS
TOU
VEE
WM
Companion Specification for Energy Metering
Critical Peak Pricing
Device Language Message Specification User Association
Distribution Management System
Information subsystem of electric utility
Interval Data Recorder
International Electro-technical Commission
File Transfer Protocol
Load Control
Load Profile
Load Management System
Meter Asset Management
Meter Data Management and Repository
Meter Maintenance
Meter Reading
Metering System
Network Operations
Outage Management System
Point Of Sale
Point Of Delivery
Radio Frequency
Rate of Price Period
Advanced Metering System
Time Of Use
Validation, Editing and Estimation
Work Management
DEFINITIONS OF TERMS AND EXPRESSIONS
Terms and expressions used in this document have the following meaning:
AMCC
AMI
API
Control computer within advanced metering management system
(AMM), used for takeover or receipt, as well as temporary storage of
data on meter reading before they are transferred to MDM/R system.
Furthermore, information saved on AMCC computer are available either
as ‘log’ documents on maintenance and problems in the
telecommunication part or as general reports on total availability of
AMM system to other information subsystems within electric utility.
Designates advanced metering infrastructure including advanced
meters, advanced meter communication device (AMCD), local area
network (LAN), advanced metering regional collectors (AMRC),
advanced metering control computer and wide area network (WAN), as
well as the corresponding hardware and software for connection into
unique functional whole, in accordance with the given technical
specification. AMI system does not include MDM/R system.
Designates application programme interface used for access to services
supported by other modules via procedure connection.
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Accounting data
Designates metering data processed by VEE and ready for use for
collection purposes.
CPP
Is related to specific price structure, which is most frequently termed
‘critical peak pricing’. Electricity price is changeable under this structure.
Such phenomenon most frequently occurs when wholesale electricity
prices are very high due to supply restrictions. One or more considered
periods of a certain tariff rate is used for electricity consumption
monitoring of the customer during the period with critical price
structure.
Customer
Term related to electricity consumption of individual and grouped
residential facilities, where additional metering compared to the
approved power is not necessary.
Daily
reading Designates 24-hour period for metering data collection, whereas it may
period
be altered due to daylight saving time changes. Daily reading period
starts on midnight, i.e. 00.00hrs every day,
Firmographic/
Term related to basic data of customer profile, either business or
Demographic
individual customer, respectively. Firmographic data are relevant for
business processes and they are included in business transactions,
implying automatic electronic data exchange between business or
commercial partners.
GUI
Related to graphic user interface, whereas it is the most frequently used
type of computer interface within modern operating systems.
Interested party
Represents legal entities having authorisation to access certain data
from MDM/R system.
kWh
Measure for active electricity.
CIS
Term related to central information subsystem of electric utility used for
customer data storage and processing.
Metered
Represents the value generated by the meter, representing cumulative
consumption
electricity consumption at the point of delivery at a certain moment.
MDM/R
Meter data management and repository system used to process data on
metered consumption aimed at obtaining accounting data and data
storage for further use.
MMD
Represents a basic part of MDM/R system, containing basic connection
between meter data obtained by AMCC computer and points of delivery
(POD) of electricity.
POD
Represents point of delivery of electricity to the customer, i.e. point of
delivery on which delivered electricity is metered or calculated. Index
(POD) is awarded by AMM system and it represents a unique indicator,
whereas it identifies the place of delivery, with one or more advanced
meters, on which electricity consumption represents the basis for
payment.
RPP
Represents electricity distribution system access tariff for customers
based on consumed kWh.
TOU
Represents the time period for electricity sale based on established tariff
for a certain time of day, day of the week and/or season of the year. For
the purpose of collection, meter data are grouped according to tariff
rate times, in accordance with adopted price structure, whereas,
consumption recording is enabled during a certain time period of the
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VEE
WAN
1.2.
day, week or year.
Represents analysis in terms of validation, editing and estimation of
meter data, aimed at identification of incorrect and missing data, as well
as data generation for the calculation of consumed electricity. After
applied VEE analysis, meter data gaps are exactly determined, and these
gaps are filled based on past trends or by averaging recorded
measurements, recorded during a similar period.
Represent a wide area network, providing communication up to MDM/R
system, as well as other information systems/subsystems.
APPLIED STANDARDS
The following standards were used in the course of development of this document:
IEC 60050-300
International Electro-technical 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
IEC 61968-3
Application integration at electric utilities – System interfaces for
distribution management
Part 3: Interface for network operations
IEC 61968-9
Application integration at electric utilities – System interfaces for
distribution management
Part 9: Interface for meter reading and control
IEC 61968-11
Application integration at electric utilities – System interfaces for
distribution management
Part 11: Common Information Model (CIM) Extensions for Distribution
IEC 61970-301
Energy management system application program interface (EMS-API)
Part 301: Common information model (CIM) base
IEC 62051:1999
Electricity metering – Glossary of terms
IEC 62051-1
Electricity metering – Data exchange for meter reading, tariff and load
control
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
Electricity metering – Data exchange for meter reading, tariff and load
control
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1.3.
PURPOSE
This document describes functional requirements to be supported by MDM/R system. The
purpose of the document is to familiarise the target group with the requirements for MDM/R
system, as well as to provide additional clarifications which should assist in the defining of
wholesome functional requirements of applied systems. This document stipulates and defines
many requirements to be met by MDM/R system, but it does not stipulate the entire
implementation or operational methodology. It identifies elements necessary for data transfer
to and from MDM/R system. The entire specification shall be used for data transfer to and
from all interested parties, including implemented AMM system and electric distribution
network operator.
1.4.
SCOPE
This document describes functional requirements of Meter Data Management and Repository
System. Various parts of this document refer to the current business processes and integration
requirements, while detailed requirements will be fully described in other documents.
1.5.
MDM/R SYSTEM OVERVIEW
MDM/R system provides common infrastructure for data receipt on metered consumption
from implemented AMM system within one electric utility, calculated consumed electricity (i.e.
provides data necessary to the system for calculation and collection of electricity), stores and
manages data and it provides access to subject data to all interested parties.
Depending on the size of demand area of individual corporate enterprises, the scope of MDM
system will be in the range from 300.000 to 1.000.000 units (meters). The system is sufficiently
flexible to allow easy upgrade and thereby cover the changes within PE EPS, whether due to
the change of the number of customers, or due to the changes in the organization of corporate
enterprises, i.e. PE EPS.
The use of appropriate middleware will enable the connection of MDM system with other
business systems and AMM centres, which will be potentially implemented in the following
stages of the Project implementation.
MDM/R system was anticipated to use WAN for connection with all entities within electric
utility, as well as with all interested parties.
MDM system will be implemented within the existing telecommunications and computer
structure in corporate enterprises within PE EPS, in a manner that undisturbed and reliable
system operation is fully enabled (redundancy, uninterruptible supply, backup of data and
settings and like).
If communication routes going outside of the computer or telecommunications structure of
corporate enterprises are used, data encryption is mandatory.
AMM system is expected to gather data according to the sequence/request, and deliver them
to MDM/R system on request, by using the common protocol SRPS EN 61970/61968 and data
transfer structure.
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Generally, MDM/R system provides:











1.6.
Data acceptance and upload on metered consumption sent by AMCC.
Acceptance and upload of other data send by AMCC, primarily related to voltage drops
and deviation, indication of voltage outages and various other warnings.
Validation, editing and estimation of received meter data.
Data storage, management and maintenance.
Expandability in terms of full integration with other ISS ELU.
Revision of changed data.
Traceability of data within the entire MDM/R system.
Security in access management to all functions and data.
Calculation of consumed electricity for each point of delivery based on different price
structures, including hourly and other specified tariff rate periods.
Data based on the sequence defined in advance or on request.
Receipt and management of information for support exchanged between points of
delivery, advanced meters, electric utility and interested third parties within MMD
subsystem.
GENERAL FUNCTIONAL REQUIREMENTS
This document was defined under the following context:









MDM/R system shall operate under Central European Time (CET).
Restricted data validation shall be done by AMM system, before data are sent further
on to the MDM/R system.
All functionalities related to validation, editing and estimation (VEE) shall be centralised
on the level of a unique MDM/R system within one electric utility.
Data transfer from MDM/R system to the Billing System, as well as to other information
subsystems within electric utility, shall be implemented through the (push) procedure
(according to sequence) or the (pull) procedure (on request). In case that some electric
utilities do not possess Billing system and/or other information system without 24-hour
– 365-day availability, then in addition to the basic (push) procedure, there should be a
(pull) procedure submitting data when these systems are available.
Electric utility shall retain the existing interface towards electricity customers.
It is necessary to anticipate possible outsourcing of management and maintenance of
the billing system by some electric utilities to some other legal entities.
It is necessary to anticipate possible outsourcing of management and maintenance of
AMM system by some electric utilities to other legal entities. In this case, full set of
authorisations needs to be defined, such as, who is authorised to send data to MDM/R
system, which needs to be contacted in case of possible problems, etc.
It is necessary to anticipate that electric utility, i.e. Billing System and not MDM/R
system are responsible towards electricity customer for possible lack of accounting
data.
Hourly load profiles (LP) specified by other information sub-stems should be used for
VEE analysis needs, in case when there are no sufficient data.
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







2.
MDM/R system shall initially be filled with all necessary data (identifiers of points of
delivery of all customers within the demand area), in order to enable the performance
of VEE analysis of connected AMM system.
During initial system filling with necessary data, electric utility shall submit all its historic
data, necessary to fill MDM/R system data base.
Electric utility should anticipate the usage of one or more advance metering control
computers (AMCC), whereas electric utility may have more than one active computer
(AMCC).
In initial implementation phase, MDM/R shall receive, process and manage data on
metered electricity consumption for all customers having advanced meters installed,
read by AMM system, while data obtained for electricity customers with classical
meters, read via handheld devices will be received from the Electricity Billing System,
for the purpose of using the existing interface.
Furthermore, in initial implementation phase, MDM/R system shall receive, process and
manage data on metered electricity consumption from industrial electricity customers
having advanced meters installed read by AMM system, and metering based on the
approved power (including a larger metering data set), while data received for
industrial customers with classical meters, read via handheld devices shall be obtained
from Electricity Billing System.
In initial implementation phase of MDM/R system, access of interested parties to
MDM/R system will not be enabled.
Later implementation phases of MDM/R system may include the following
functionality:
 Support aimed at sub-measurements collection (along the metering structure
depth).
 Support aimed at measurements collection (voltage, power, etc.) within electric
distribution network.
 Support aimed at distributed production integration.
 Integration with other metering devices (gas, water, etc.).
 Future functionalities in terms of loss factor calculation and information update on
electricity customers.
 Business information on customers.
MDM/R system shall be subject to regular revisions and further improvements.
DETAILED FUNCTIONAL REQUIREMENTS
This part of the document describes functional requirements of MDM/R system. Target
functionality of the system is divided in four main fields, as shown on Figure 2. All these fields
exactly reflect the roles within MDM/R system, as described in this specification.
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MD
MDM/R
MDM/R
Metered consumption
data receipt
Load
management
Data
publication
MDM/R
Main directory
MDM/R System
Figure 13 – General functionalities of MDM/R system
2.1.
OVERVIEW OF FUNCTIONALITIES
This document describes detailed functionality of MDM/R system, as well as mutual relation
with other information subsystem within electric utility, as shown on Figure 3.
MDM/R system
AMM centre (AMI)
Data management (MDM/R)
Data receipt (MD)
Advanced Metering
Control Computer
(AMCC)
Metering data
repository
(MDR)
Administration
(MAS)
AMM Centre
Operator
(AMМ OPS)
Metering data
interface
(MDEI)
VEE analysis
(VEE)
Operator interface
(MOI)
ISS EDC
Customer
Information
System
(CIS)
Metering data
grouping
(MDA)
ISS EDC
Information on
network resources
Customer information
System
(CIS)
MDR DB
Accounting and
Collection
System
Initial import of metering data
Data publication (MD)
Accounting and
Collection System
interface
(MBDI)
Information on
metering points
Initial import of MMD data
Additional
notification
interface
(MDRI)
MMD
MMD interface
(MMDI)
Public notification
interface
(MPRI)
Interested
parties
Buyers
Public
MMD DB
Figure 14 – Detailed functionality of MDM/R system
2.2.
REGULATORY AGENCY REQUIREMENTS
MDM/R system has to meet all current state laws, rules, instruction, guidelines and
regulations, including all requirements of all regulatory bodies, agencies and boards.
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In order to achieve maximum security, MDM/R system shall meet all current laws and
regulations related to metering data and/or data transfer to and from electricity customer,
including all laws and regulations applied to metering, security, privacy and
telecommunications.
2.3.
UNIQUE POINT OF DELIVERY (POD) ID NUMBER
MDM/R system shall identify in a unique way all points in which electricity delivery to
customers is executed, i.e. points of delivery in which metering is executed via meters or
calculation aimed at substitution of the missing measurements. Unique point of delivery ID
shall be awarded by AMM system and it shall represent a unique identifier serving for
identification of the point on which calculation of consumed electricity is performed, whereas,
consumption information may be collected from several advanced meters. Unique point of
delivery ID should not be an ‘intelligent’ number and it should not include ED subscription
number of the customer.
Therefore, if electric utility registers several points of delivery at the same time, unique point
of delivery ID should not be generated sequentially, in order to avoid possible overlapping in
terms of identifier generation. AMM system should establish internal connections between
unique point of delivery ID on one hand and meter ID and other parameters on the other hand.
Unique metering point ID may be physical or virtual (in case of calculation of total consumption
from several points of delivery). Unique point of delivery ID shall be used in all communications
executed by MDM/R system, related to the target point, both in terms of metered
consumption or calculated value.
MDM/R system should be capable to group several unique POD IDs together according to POD
classification. Furthermore, MDM/R system should be capable to perform the grouping of
reports on metered consumption and consumption calculation according to individual PODs or
grouped PODs. Each metering point may belong to none, one or several PODs within POD
classification. Unique POD ID should be defined to provide uniformity at the level of electric
utility. Moreover, in time it is also necessary to provide the privacy and consistency of data
access. Registration process of unique POD IDs itself and data synchronisation between
MDM/R system, AMM system and Customer Information System (CIS) at the level of electric
utility, will be the subject of a detailed programme to be developed in the course of designing
and it will depend on the final implementation of the selected MDM/R system solution. Initial
registration process of unique POD IDs, as well as the on-going maintenance process, will also
be the subject of a separate detailed programme to be developed during the designing
process.
After meter dismantling and replacement with other advanced meter, unique POD ID should
remain the same. Possible customer change on such point of delivery shall not have an impact
on unique POD ID. MDM/R system shall maintain all relations related to unique POD ID,
continuing further access to its historic data even after withdrawal of unique POD ID. There will
be no metering data for withdrawn POD ID, whereby the system will report that this point has
been deactivated.
2.4.
DATA ENTRY INTO MDM/R SYSTEM
This document identifies elements which need to be transferred to and from MDM/R system.
Data transfer request should be executed consistently to and from MDM/R system,
information subsystems within electric utility and other interested parties.
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Data entered into MDM/R system include:
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Data on metered consumption and reports from AMM system.
Data from Customer Information System.
Information related to tariffs and price structures.
Data transferred from Billing System.
Data on network resources on which points of delivery have been implemented.
Data from MDM/R system required by other information subsystems within electric
utility and other interested parties.
Reports and confirmations.
Adopted standards for data transfer via different interfaces should provide full support for the
functioning of data transfer process to and from MDM/R system, including all information
necessary to meet specification defined in this document. Subject standards adopted for data
transfer towards MDM/R system should provide self-check functionality of submitted data.
MDM/R system should support data transfer between advanced meters and devices not
having meter functionalities, in order to enable the functionality level defined under this
specification. In addition to this, all data transfers should meet strict security conditions
indicated in this specification.
MDM/R system identifies the following data elements to be transferred via those interfaces.
2.4.1.
TRANSFER OF RECEIVED METER DATA FROM AMM SYSTEM
MDM/R system should receive and process data on metered consumption and other data from
subordinated AMM system. Received meter data to be transferred to MDM/R system from
each advanced metering control computer (AMCC) include the following:

Data on metered consumption for households, having no requirements in terms of
required load on hourly level; data on consumption should be transferred at the end of
daily accounting interval.
 Data on metered consumption for industrial customers, having no requirements in
terms of required load; data on consumption should be transferred either as 15 or 60minute data at the end of the daily accounting interval.
MDM/R system shall be capable to receive and process data on metered consumption for each
daily accounting interval. MDM/R system should be scalable in terms that it should support all
requirements related to performance and forecasted load growth, where it is realistic to
expect the stabilisation of reading interval on the hourly level.
It may be expected that the size of data transferred by advanced metering control computer
(AMCC) is restricted to the maximum number of entries. Transfer in terms of data size shall be
restricted in terms of prevention of too long or re-emission of data during the transfer of large
data amounts containing errors.
Moreover, it is necessary for all data transferred via this data transfer method to be related to
the same calendar day. Finally, it is expected that all of these transferred parameters, at least
contain identification information in the heading defining data upload priority for MDM/R
system for several subordinated devices, when simultaneous data transfer is requested.
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Data transfer priorities
MDM/R system will save all meter data versions received from advanced metering control
computer (AMCC). For the purpose of adaptation enabling MDM/R system to perform urgent
data processing in accordance with critical situations, when several requests need to be
processed at the same moment, it is necessary to include data processing procedure according
to priority. MDM/R system should support processing priority determination procedure
regarding data to be submitted from AMM system. Priority should be based on time and date
of meter data creation.
MDM/R system should be capable to enable receipt and storage of all data on metered
consumption every day for the previous daily reading period. Considering that meter data do
not have to be transferred under one transmission (session), MDM/R system should be able to
accept data transmissions more frequently. In order to have successful data transmission, it is
necessary for all process clocks on all computers within subject subsystems to be synchronised
in terms of time.
In addition to realised interfaces based on Web services, electric utility should allocate
(reserve) space on FTP server within MDM/R system, for possible necessary data exchanges
with other information subsystems.
Syntax validation
MDM/R system should validate the syntax of every message containing data on metered
consumption received from AMM system. In the course of syntax validation, MDM/R system
should establish that the data structure is in accordance with implemented standards, as well
as that the value of ‘control amount’ of the message is identical with the value received
through calculation within MDM/R system. MDM/R system should execute the calculation of
‘control amounts’ over all received data messages, compare the value of calculation results
with original ‘control sum’, and in case that these values are identical, it should conclude that
the message was not damaged and forward it to further processing.
Semantics validation
MDM/R system should validate the semantics of every message containing data on metered
consumption received from AMM system. For the purpose of system operation efficiency
increase, it is necessary to verify whether information in the message heading correlates with
information located in other information subsystems of electric utility. Additionally, MDM/R
system should constantly verify whether advanced meters sending data on metered
consumption are activated.
Manual entry
MDM/R system should provide the possibility of manual entry of meter data and other data in
some situations, such as, e.g. the situation when current measurements are available, but the
advanced meters no longer communicated within AMM system, whereby these measurements
are not submitted to MDM/R system for further processing. In such situations, AMM system
services or other information subsystems within electric utility are expected to find a way to
transfer data, e.g. manually, into MDM/R system. Manually entered meter data shall be in the
same format as the ones automatically entered into MDM/R system by AMM system, whereby,
the same validation of message content is performed, as in the case of automatically
transferred messages.
MDM/R system should be capable to process any additionally added archive measurement and
this functionality should be set as default in other improvements of the Billing System within
electric utility.
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Confirmation
After every data sent by AMM system is received and processed in order to be validated by
MDM/R system, MDM/R system shall send a message to AMM system in order to confirm the
successful receipt of the message or possible problem in the transfer.
Data validation prior to (VEE) analysis
When transferred meter data are successfully received by MDM/R system and after all syntax
and semantic validations are performed, MDM/R system should upload the subject data into
the data base. MDM/R system should archive them, to avoid possible deletion of successfully
uploaded data.
MDM/R system should continue the initiated validation process of data stored into the data
base, regardless of the fact that it continues with the receipt of other data.
MDM/R system should perform, without restrictions, the following data validations uploaded
into MDM/R system:

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





2.4.2.
During every data transfer, it verifies whether combination ‘Unique POD ID/meter ID’ is
valid and whether they are concurrent with data in MDM subsystem.
It validates whether exact time is distributed on all advanced meters, as well as other
devices within AMM system.
It validates whether MDM/R system received meter data by 5.00 hrs.
It compares whether unique POD IDs from which data on metered consumption have
been received are identical with data on this point of delivery, received from other
information subsystems in electricity distribution companies.
The level of complete availability of advanced meters is validated within AMM system,
which should not be below 98%.
It confirms whether all meter data obtained by advanced metering control computer
(AMCC) have the accuracy of 0.01 kWh.
It validates at what hour has the point of delivery supply been interrupted and when
the supply was restored. As the consequence of outage, MDM/R system should detect
the difference between the moment when the load was zero and the moment when to
load has not been transmitted, all on the basis of data submitted by AMM system.
It validates abnormal changes in metered data consumption.
SUBMISSION OF REPORTS TO MDM/R SYSTEM BY AMM SYSTEM
AMM system should submit various reports to MDM/R system, defined based on functional
specification for AMM system. MDM/R system should archive submitted reports, whereas,
they should be indexed to enable rapid search by MDM/R system operator and their display.
Subject reports should at least be indexed according to date and type of report.
MDM/R system should be capable to receive all reports indicated in AMM system specification,
but the final list of necessary reports shall be determined according to business requirements
of electric utility.
Based on submitted reports, it is not necessary for MDM/R system to process data from these
reports for the purpose of offering support to VEE analysis. Transmitted messages by AMM
system to MDM/R system should contain special quality codes for the needs of VEE analysis, in
addition to data on metered consumption.
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Reports stored within MDM/R system should not be distributed further to other information
subsystems within electric utility.
2.4.3.
DATA EXCHANGE BETWEEN THE BILLING SYSTEM/ISS ELU AND MDM/R SYSTEM
MDM/R system should be capable to receive and process the following transfers:

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


New unique POD ID for the update needs (MMD).
ED subscription number.
Data on network resource, where metering point is realised.
Request for meter data reading.
Request related to data for electricity calculation.
MMD update
MDM/R system should receive and process incremental changes of data contained in MMD.
These data represent data sent by information subsystems within electric utility to MMD
subsystem, whereas, they contain identified changes in various time-dependent attributes,
related to points of sale of electricity.
Additional requests towards MDM/R system
MDM/R system should receive and process additional queries from information subsystem
within electric utility, Accounting and Collection Subsystem, as well as authorised interested
parties, which may be generated by specified parameters in the form of a list, whereas, these
parameters may include the following:
Unique POD ID




2.5.
Consumption grouping during certain time intervals: hourly or tariff periods.
Grouping of consumption during a certain time period.
MMD data.
Type of demographic/firmographic data.
TIME FLOW OF DATA EXCHANGE
Figure 4 shows time flow of data exchange between MDM/R system and other target
information subsystems, whereas, the displayed periods are only given for information
purposes, since they in real practice have to be defined according to technological
requirements of individual electricity distribution companies.
Meter data uploaded daily into the MDM/R system are mainly data from the previous daily
reading period. It is possible that during one day, meter data from some other previous days to
be uploaded, when e.g. there were some communication problems with AMM system, and
that is when simultaneous transfer of data for several days is being performed, for which
meter data were missing. For the purpose of efficient data transfer, missing data are usually
transferred with high priority, in order to complete as soon as possible MDM/R system data
with the missing data, for the purpose of final processing completion of target meter data. In
cases, when instead of missing accounting data, estimated values are sent to Billing System, it
is possible to perform missing data transfer under lower priority.
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Daily reading period N+1
Daily reading period N
Daily reading period N-1
05:00
ED updates data in MMD for the reading
period during ‘N’ days
Data on metered consumption during day ‘N’ forwarded from AMCC to
MDM/R from 05.00 hrs during ‘N+1’ day
00:00
06:00
01:00
Defined CPP periods for reading period
during ‘N’ days
Data on metered consumption during day ‘N’
Verified (semantically, syntaxically, prior to VEE) and stored into MDM/R
Sent confirmations on data validation to AMI system
Further data processing on
metered consumption
07:00
Data on metered consumption during day ‘N’ verified via validation and
estimation
Reports on deficiencies forwarded to ED
Further validation and
estimation of data
Report analysis by ED
ED requires detailed profiles of missing
data read during day ‘N’
Profile
receipt
ED edits consumption data
08:00
Preliminary data on
consumption during
day ‘N’ available to
the buyer
Preliminary data on
consumption during
day ‘N’ available to
ED
Figure 15 – Time flow of data exchange
Besides uploading meter data every day, MDM/R system performs various changes (semantic
and syntax) over these data, together with validation, editing and grouping into corresponding
accounting data. In the course of defining of time frames for collection, processing (VEE)
analysis and submission of data to other information subsystems, it should be noted that due
to various checks and additional requests, such frame may be extended to several days,
whereas, it should not be longer than four days, i.e. from the moment of load data receipt to
the submission of valid accounting data.
For the needs of load data processing during the on-going accounting daily period, no new data
or any kind of changes of data already within MDM subsystem will be considered in case when
they are not received by MDM/R system by the end of the previous daily reading period. This is
because data for daily reading period may be transferred to MDM/R system any time after the
finalisation of each daily reading period, and MDM/R system should provide to MMD system
accurate data, so that it can process the data successfully. MDM/R system should have a
replacement system implemented (with confirmation), in case that other information
subsystems in electric utility send data corrections for invalid data within MMD subsystem.
In case that customers need to have access to load data or accounting data for the previous
accounting period, then other information subsystems within electric utility need to have
access to subject data at the same time they are available to customers, so that possible
remarks of the customers may be accommodated. Data obtained based on meter data, which
have not undergone validation, and which have been estimated or changed based on this,
should be labelled to offer proper information on the level of their authenticity.
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MDM/R system should enable access via API to meter data and accounting data, when they
become available after (VEE) analysis, to other information subsystems, both in electric utility
and outside.
2.6.
DATA SUBMISSION BY MDM/R SYSTEM
MDM/R system shall submit data on other information subsystems in different ways, as
explained in the following text.
2.6.1.
DATA SUBMITTED TO BILLING SYSTEM
There are two types of information transferred between MDM/R and Billing System:


Automated data on electricity accounting transferred under the sequence defined in
advance, and
Specific data on electricity accounting transmitted as a response to the request.
In the defining of the requirements in terms of automated data transfer between systems, it is
necessary to anticipate submission of grouped accounting data in addition to standardised
daily sequence and submission according to accounting period, in accordance with the
operation technology of electric utility.
All data on electricity accounting to be submitted to the Billing System will be archived by the
System.
During data exchange between the systems, it is necessary to anticipate the high level of
flexibility realised through ‘cancel/calculate’ procedure, considering that MDM/R system may
submit accounting data either under daily sequence or under accounting period, for each
metering point. In case when Billing System requires accounting data, before they are
submitted according to the schedule, the System may generate the request for their
submission.
MDM/R system should be capable to group several metering points according to established
classification of metering points, as described under section 2.3. MDM/R system should be able
to group accounting data in the form of a report, either for some metering point or group of
metering points, for the purpose of offering hourly accounting data for metering points with
different classification, and for the purpose of support to various business processes within
electric utility.
In the course of MDM/R system implementation phase, it should provide accounting data to
the Billing System for each metering point containing an advanced meter, registered within
MMD subsystem. MDM/R system should at least be capable to receive the following tariff
rates and scenarios:



Hourly (for households and industry).
Tariff plan.
Excessively taken over power and energy.
In case when there is no consumption on some metering point, according to the adopted tariff
plan, MDM/R system will submit a zero value for metered consumption to Billing System. It
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should also be noted that zero value represents a valid consumption reading which has
undergone the validation process and that it does not represent missing data.
In later MDM/R system implementation phases, it should enable functionality in terms of
submission of the following accounting data for:




2.6.2.
Required consumption,
Metering along the depth of electric distribution network,
Metering according to hierarchy of metering structures, and
Distributed production.
REQUESTS OF INTERESTED PARTIES AND OTHER ISS ELU
MDM/R system should respond to the requests obtained from interested parties and other ISS
ELU, whether they are defined under a regular procedure or additionally. These requests
should be responded to on the basis of previously defined parameters within MDM/R system,
and in the case of complicated requests, an optimum should be found between realistic needs
for such information and costs of providing such information.
Some of the requests include:


Request for historic data (data on consumption and/or accounting data) for a certain
metering point or groups of metering points for a certain time interval, either on hourly
level or according to the tariff period.
Request for data grouping related to the group of predefined firmographic or
demographic parameters.
MDM/R system should respond to the requests from authorised interested parties. Access
authorisation to meter data and accounting data should be under the control of electric utility
or other entity, identified as primary authority for data access approval.
MDM/R system should be capable to restrict execution of additional data requests during
critical periods (large) data processing. Such MDM/R system functionality should be provided
enabling its execution of additional requests with the delay, or to provide data access by using
the procedure not influencing operational processing.
2.6.3.
MESSAGES
MDM/R system should send error messages to other information subsystems within electric
utility in accordance with the desired service and performance levels during error and anomaly
recognition related to system operation. Verifications generating messages include the
following:
During meter data receipt



Identification check of meter and metering point.
Number of intervals for each metering point should be identical to the number
indicated during data transfer.
Interval size for each metering point.
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 Time validation at the metering point.
 Zero consumption on active metering point.
 Failed metering data transfer from any metering point during the last 3 (three) months.
Exceptions identified during (VEE) analysis
MDM/R system should report any problem to other information subsystems within electric
utility, related to read data on consumption or possible inadequate data estimations. Other
information subsystems within electric utility are expected to investigate and resolve any
problem occurring throughout (VEE) analysis. If data quality is such that estimated value
cannot be taken into consideration, the request for new reading (either coming from AMM
system or other ISS ELU) will provide data to be additionally entered into MDM/R system.
2.6.4.
REPORT GENERATION
The control procedure of system itself should be implemented within MDM/R system. MDM/R
system should automatically generate reports on identification of operation abnormalities of
system itself. MDM/R system should have several procedures serving to identify immediately
the cause of any anomalies. If necessary, MDM/R system should generate and transmit
reports, whereas, it is not only limited to:
Non-critical reporting




Confirmation of successful load data transfer by advanced metering control computer
(AMCC).
Confirmation of all executed data changes in the data base occurring due to addition,
migration or change of any of the metering points or meters.
Reports related to meter data.
Unsuccessful meter data upload.
Critical reporting
Critical events include any operational problem having an impact on meter data receipt during
daily reading period or on timeliness of accounting data sending. MDM/R system immediately
identifies and reports a critical event.
Operational problems included into any reporting on critical events, without restrictions
include the following:




Unsuccessful meter data receipt.
Disagreement between meter ID and metering point ID.
Lack of storage capacities within data base or on disk.
Computer network problems.
MDM/R system should be able to define the priority of critical events according to the order of
precedence.
2.6.5.
USER INTERFACE
MDM/R system should enable MDM/R system operator and/or external user, insight into
possible changes of received meter data.
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MDM/R system operator interface
MDM/R system should have an internal user interface enabling supervision, change and
management of processes and data within the system. Some of the information MDM/R
system needs to provide within the user interface include information about: meter data
upload, data transfer waiting for upload (with low priority), on-going data transfer, data
transfer during which problems occurred in semantic and syntax validation, etc.
If data transfer is completed unsuccessfully, MDM/R system will send and internal message, if
necessary, it may notify AMM system operator about the failure. MDM/R system will make a
report aimed at accurate description of the problem cause. This information will be available to
MDM/R system operator through the user interface, whereas, it is necessary to enable easy
sorting and search of error reports.
External user interface
MDM/R system should have an external user interface, which should be capable of adapting to
access rights of the currently logged-in user, enabling preview and/or meter data change by
some user within other information subsystems within electric utility or some other entity
identified as possessing primary authorisations for data access. Meter data review and change
by some user within ISS ELU or some other external entity shall be restricted, considering that
primary authorities have been identified within AMM system for unique POD IDs and meter
IDs. These external possibilities related to value change will be used as the support during
editing under (VEE) analysis.
2.6.6.
PRESENTATION OF INFORMATION
Public notification
MDM/R system should be capable of presenting data and reports, in a restricted form, in the
manner most easily accessible by the public; e.g. supporting access procedures, such as WEB
presentations or interactive voice response (IVC).
User information
Concrete user data have to be available for direct presentation by MDM/R system or some
other user within ISS ELU. In case that such data are directly presented by MDM/R system, the
system will include the standard security access via username and password for the target
metering point, regardless of the fact that the user possesses all data related to the target
metering point. These security procedures will also be applied during the usage of interactive
voice responses (IVR) and in the case of WEB access.
2.7.
DATA MANAGEMENT
The following sections describe MDM/R system requirements in terms of data management.
2.7.1.
DATA GROUPING
Key information of MDM/R system is grouping of gathered meter data for the following
purposes: billing, reporting and analysis. Compared to accounting data, MDM/R system will
group confirmed meter data according to tariff periods, established on daily basis, at the level
of electric utility.
Compared to data grouping, MDM/R system should perform the following:
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





2.7.2.
Support to dynamic business environment via automatic procedures (over MMD
subsystem) and interactive interface (for MDM/R system operator) for the defining of
new grouping requests.
Support to complex grouping including addition and subtraction functions, taking into
account not to have metering points and data from them twice in the final result.
Application of multiplier over meter data, when grouping of accounting data is carried
out over network resources (metering points).
Support to the usage of virtual metering points, on which there are meters installed,
and over which addition and/or subtraction functions are executed from other
metering points.
Enable execution of previously defined meter data grouping, frequently collected, as
well as storage of such data in a suitable form, in order to avoid data re-grouping under
every regular request.
Store data versions used for grouping, based on which it is possible to have insight into
MDM/R system. If data version for metering point is updated, MDM/R system should
validate data based on data versions stored in every pre-grouped format. If an older
version of read data is in question, MDM/R system shall label them as outdated and
request re-grouping of the latest data.
DATA VERSIONS
MDM/R system should provide access to meter data by using the corresponding data version.
Data versions within MDM/R system will represent quality business concepts based on data.
MDM/R system should manage business rules used for the defining of contexts of
corresponding data versions. Every time meter data are altered, MDM/R system should update
only data related to that metering point and certain date of the year. Furthermore, MDM/R
system should be able to store and memorise data automatically, and to take over meter data
based on the certain data version.
MDM/R system should provide version award, both in case of original meter data and in case
of derived data (e.g. accounting data). MDM/R system should provide identification of
relations between derived data versions in basic meter data versions.
It should be noted that versions of qualitative data do not represent a special group of data
uploaded together with data, but they represent qualitative versions of business concepts in
relation to the data, for the purpose of access control of the latter. When basic data referenced
by certain data version, change their version (i.e. version now indicated to different load data,
either for the entire interval or for some part of the interval), then this change will be
monitored in terms of providing possible data revision. In the course of version monitoring, it is
necessary to realise data access control via usage of internal services capable to apply such
business policy.
2.7.3.
DATA MONITORING
MDM/R system should be able to monitor read meter data during data processing for the
purpose of processing event entries. Minimally, MDM/R system should monitor how, when
and why has meter data change been made and identify persons, or processes, who made the
change.
MDM/R system shall make such information available in the form supporting the revision
process, starting from the meter data receipt to the final generation of accounting data. For
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example, if an invoice with a calculation is disputable, MDM/R system will be able to identify
raw meter data used for such calculation based on which the invoice was issued. In this sense,
it is necessary to record meter data versions used for creation of accounting data sent to Billing
System and other ISS ELU, for the purpose of keeping the records on change for revision needs.
Furthermore, it is possible to include records on the time of executed changes, user who made
the changes, as well as the data on the change. MDM/R system should provide the procedure
enabling identification of changed or estimated meter data, thus enabling the user to enter the
comment describing the reason for the change.
MDM/R system should enable the usage of real meter data during revision, when they are
available in the system, instead of data replaced or estimated, used for generation of
accounting reports. All newly-arriving data will be processed through VEE analysis.
2.7.4.
VALIDATION, EDITING AND ESTIMATION (VEE)
All meter data received by MDM/R system will be subject to VEE analysis. Automatic process of
VEE analysis should be realised within MDM/R system.
VEE analysis process performs analysis of current meter data for the purpose of finding
possible anomalies, and in the case that anomalies are discovered, error report is generated, as
well as the request for data correction within MDM/R system with the estimated value. For the
purpose of providing data for calculation to other ISS ELU, MDM/R system should be capable to
determine the priority for VEE analysis according to metering points having in mind specific
requirements for calculation and billing.
In the course of VEE analysis within MDM/R system, it is necessary to possess the entire
documents related to algorithm implementation used for the validation and estimation of
meter data, whereas, applied algorithms have to be explained on real examples, with clearly
defined data flows and definitions. MDM/R system shall use subject algorithms for future
revisions and improvement of the analysis procedure. MDM/R system shall provide application
of other algorithms of meter data estimation and validation, in terms of covering various
metering points.
Validation
MDM/R system should continuously validate meter data in search for possible anomalies.
Various rules should be enabled within MDM/R system for meter data validation coming from
certain metering points or groups of metering points. Applied validation algorithms should not
disturb the existing business processes within electric utility.
Data estimation and editing
MDM/R system should be able to apply various techniques (estimations) of meter data
estimation, in cases when data are not available and when based on them data for accounting
of consumed electricity may not be determined. Estimation method has to be automated.
MDM/R system will provide the application of adapted estimation techniques of
uncoordinated meter data of individual commercial and industrial customers or for the groups
of metering points requiring special rules, which in normal circumstances would not be subject
to estimation.
MDM/R system should enable meter data change, either by MDM/R system operator or by
authorised external users, whereas implemented change procedure may differ. Review and
change of meter data by ISS ELU or some other external entity shall be restricted for certain
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metering points, as well as for certain meter IDs, for which an external identity has been
identified as primary authority for such data.
2.7.5.
CORRECT TIME DISTRIBUTION
MDM/R system, as well as implemented AMM system, should operate in a unique time zone,
i.e. in Central European Zone. AMM system will perform correct time distribution within its
system, while MDM/R system will do the same within its own system. Existing GPS receivers
within ISS ELU will be used for correct time distribution needs.
2.8.
2.8.1.
FUNCTIONAL REQUIREMENTS IN TERMS OF DATA STORAGE
DATA STORAGE (ММD)
MMD subsystem within MDM/R system will maintain all relations between data on metering
points, meters, network resources, ISS ELU, AMM operators and other authorised parties. It
should enable the data access right management within MDM/R system, aimed at privacy
protection insurance.
In initial phase of MDM/R system implementation, electric utility will continue to use all
implemented customer interfaces, used to maintain customer data. Electric utility will primarily
be in obligation to establish all mentioned relations within MMD subsystem via existing
interfaces. It is necessary to implement processes and/or procedures which will be capable to
enable electric utility to provide timely and accurate data correction within MMD subsystem
via existing interfaces. Unique metering point identifier should be awarded by advanced
metering control computer (AMCC), and as such be stored in MMD subsystem, within which
relations towards other data will be established. All metering points on which electricity
delivery to energy customers is carried out will be identified in this manner, either metered by
advanced meters or calculated based on data from one or more advanced meters.
MMD subsystem will receive all data changes from other subsystems within MDM/R system,
and these data will be received and processed in a unique manner. MDM/R system should
uniquely process all data from MMD subsystem, either for AMM system application needs or
for application within ISS ELU, for each metering point. Each target ISS ELU or AMM system
within electric utility, designated as the primary data source is responsible for metering point
data change. During metering point data change, submitted by the primary source, MDM/R
system will update them within MMD subsystem, and forward the changes to other
(interested) ISS ELU within electric utility or outside. MDM/R system should confirm the receipt
of corrections within MMD subsystem, except for correction which it is not able to perform. If
data correction origin is not the primary system in charge for data change, MDM/R system will
perform data change and notify the system who sent the data change that this is not executed,
based on defined data authorisation, as well as the primary system that change of data was
attempted for which it is authorised.
MDM/R system should submit the confirmation of executed data changes within MMD
subsystem and submit reports on executed changes to other ISS ELU. Furthermore, in addition
to the submission of messages on executed changes to other subsystems, it has to be able to
forward the changes themselves. E.g. MDM/R system receives changes within MMD subsystem
by (CIS), applies all changes, as well as forwards changes towards AMM system, and notifies
other interested parties (CIS, MDM/R, AMM) for the purpose of maintaining synchronism
between them.
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2.8.2.
REFERENCE DATA
MDM/R system should receive and process incremental changes of metering point data
received by other ISS ELU. Before it makes the change within MMD subsystem, MDM/R system
will verify data submission source. MDM/R system should be under obligation to report each
unauthorised data change attempt related to metering point, constantly verifying who is
authorised to provide such data.
MDM/R system should be capable to receive notifications on addition of the new metering
point, new meter (either classic or advanced), meter dismantling, as well as change of
information related to the metering point by other ISS ELU, for the purpose of MMD subsystem
update. Such additional information will be forwarded by MMD subsystem back to AMM
system operator. This communication will enable MMD subsystem to contain valid
information, which will enable authenticity of meter data upload from AMM system. MDM/R
system will enable confirmation of any additional deletion and data change within MMD
subsystem, executed via implemented user interface or direct data submission by other ISS
ELU. Electric utility will be responsible for providing data on metering points, meters, network
topology, customer data, as well as other reference data, for the purpose of their full
synchronisation.
2.8.3.
METER DATA
MDM/R system should receive and store meter data from AMM system in the following form:


data on consumption register reading at least once a day, and/or
data on consumption register reading for each reading interval.
MDM/R system should store meter data, meter data reading interval, and accounting data
(obtained by grouping of meter data). In addition to this, MDM/R system should optionally
support the storage of other data, such as: voltage, current, power factor, request in terms of
consumption, power restriction, etc. MDM/R system should support different consumption
reading interval durations for different metering points or groups of metering points, as one of
the requests which will occur in later phases of MDM/R system implementation.
MDM/R system should minimally support meter data reading for the following interval
durations: 60 minutes, 30 minutes, 15 minutes, 10 minutes and 5 minutes. MDM/R system
should also be capable to support various types of intervals depending on received tariff
packages for different types of electricity customers. MDM/R system should preserve only
hourly data on metering points for customers in the category of households, at the level of
daily reading interval, while for customers from the category of commercial or industrial
electricity customers – intervals of one hour and 15 minutes, respectively. In case that meter
data have been collected for 15-minute interval for a certain metering point, which need to be
processed based on the specified request of the certain tariff period, then it is necessary to
transform all data into hourly meter data and send them to MDM/R system after that.
MDM/R system should support changes in interval size during the time in which meter data
have been collected for any metering point. Reasons which may cause the interval size change
include the following:

Changes of interval size for one or more classes of metering points (e.g. from one hour
interval to 15-minute interval).
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
2.8.4.
Seasonal changes of tariff periods.
ARCHIVE DATA AND DATA RESTORATION
Requirements in terms of data archiving should fully be compliant with the business processes
within individual electricity distribution companies, primarily related to frequency and scope of
data for archiving, as well as the length of the necessary time of data upload from archive.
MDM/R system should provide the possibility of data archiving and registration, in terms of
providing long-term storage, disposal and distribution of meter data, business rules and related
reference data.
MDM/R system should be capable to generate reports on deactivated metering points, i.e. on
which meters have been dismantled, but for which there are still historic meter data. This and
similar requests indicate that key data will not be archived, but they will be available in another
subsystem at any time (e.g. unique metering point ID). Moreover, other data will be archived
after a certain period, in accordance with the configuration which needs to meet business
requirements in a wider context. During the archiving methodology change within MDM/R
system, it is realistic to expect that data restoration processes will have advantage over applied
archiving procedures.
MDM/R system should enable that there is no impact of restored data, additionally processed,
on MDM/R system operation. Besides that, MDM/R system should provide that current data
version within MDM/R system is not affected by the restored data.
Implemented data archiving processes should enable corresponding data grouping of certain
data versions, in terms of accounting data calculation. Additionally, it is necessary to support
restoration of archive calculations done according to adopted algorithms, in order to enable
revision of accounting calculations in the past.
Data storage time periods
Accounting data and meter data used by ISS ELU and electricity suppliers to customers, as the
basis for calculation will be stored for a certain time period for revision needs and addition
submission to other ISS ELU and external electricity suppliers. An archiving procedure should
be implemented enabling efficient data storage for the time period of at least 6 years, and
subsequent transfer to storage media providing permanent storage.
In the planning of MDM/R system storage resources, attention should be paid to provide
sufficient storage capacity enabling metering data storage for at least one year after its
deactivation.
2.8.5.
HISTORICAL DATA
MDM/R system should be able to store data for on-line availability. In addition to this, MDM/R
system has to be able to store data for off-line availability, for the purpose of providing
historical reserve. MDM/R system should be able to provide all these data for the purpose of
submission to all interested parties.
On-line availability of meter data and ancillary accounting data should be provided for at least
24 months.
Off-line availability will primarily be used for the purpose of revision, but also for historical
analysis of consumption trends.
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2.8.6.
SECURITY
Security within MDM/R system may be divided into two fields: external control of MDM/R
system access and internal control of data access and functionalities within MDM/R system.
MDM/R system should provide corresponding measures aimed at achieving the necessary data
confidentiality security and protection, by controlling the access to data and functions
depending on user authorisations, as well as data sensitivity.
For example:






Customers may only see data related to their own consumption.
Suppliers may only see data related to their clients.
Billing System may have access to accounting data.
ISS ELU may only inspect data on consumption it is using.
Some data users will not be able to see all data from MMD subsystem.
Only authorised users may change data from MMD subsystem.
External access control
Firewall and applied security measures should enable full information protection within
MDM/R system. Protection should be such to disable transfer of original information to and
from MDM/R system and to prevent external unauthorised access to MDM/R system functions
and possible unauthorised data change.
In case of third party access to MDM/R system, the encryption of the data transferred outside
of the computer or telecommunications network of a corporate enterprise, is mandatory.
Internal data access control
MDM/R system should provide such data access and target functionality which should ensure
that only authorised users can use the system, within the scope of their authorisations
according to the security level. Records should be kept about the users having system access,
with specification of privileges for each user, as well as system access records (identification of
successful and unsuccessful attempts).
When user privileges are changed, MDM/R system should register the security level change,
time of the change and who executed the change.
Access flexibility
MDM/R system should provide a non-destructive procedure for inclusion of electricity
customers into data access concept within implemented system architecture, whereby,
customer information are integrated within MMD subsystem, where it needs to have at least
one metering point.
Roles and groups of system users
MDM/R system should implement a security procedure on all access levels through the usage
of users, groups of user, as well as their roles. Security procedure shall support the possibility
of allocating users within specific or standard groups, whereby, roles are defined in the way
enabling the application to individuals or groups of users. Subject roles should define access
levels to MDM/R system.
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2.8.7.
USER AUTHORISATION
MDM/R system should enable access only to those users which need to access certain data,
with certain access level defined for this purpose. In terms of this, it is necessary to implement
a special process enabling user authorisation, both for local and remote access. MDM/R system
should verify the corresponding data authorisation submitted to certain users, and further data
transfer should be continued only after positive identification confirmation.
User authorisation procedure should enable support to different access levels for different
users and groups of users, via interactive commands or specified procedures. MDM/R system
should support the possibility of allocating different functionalities to users based on their
authorisation, i.e. access level.
User registration process should provide identification of interested parties to be receiving
data from MDM/R system or transferring data into it. Moreover, rigorous access control is
necessary during every user connection to MDM/R system, based on previously executed user
authorisation and defining of access rights. This process should be completely automated
within MDM/R system.
2.8.8.
RELIABILITY
MDM/R system is expected to satisfy all specific requirements related to efficiency and
effectiveness, considering the importance of collected meter data for the functioning of
business processes within electric utility.
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FUNCTIONAL REQUIREMENTS - PRINCIPLES OF END-TO-END SECURITY
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End-To-End AMI security infrastructure should provide ICT base for protection of data and
functions in all segments of AMI network – from the meter to the end users. Although there
are a lot of specifics in AMI implementation, security infrastructure implementation is very
similar to implementations in other highly secured ICT infrastructure (banking…), and standard
security elements and solutions should be used. This documents gives initial functional
requests for such functionality, solutions implemented may differ.
General requirements:



Secure Manufacturing and Software Development: Device manufacturers are expected
to prove that secure hardware manufacturing techniques and secure software
development lifecycle techniques are used to produce the network equipment and
software/firmware.
Secure Firmware Distribution and Configuration Management: All devices must be
capable of being upgraded and reconfigured remotely.
Cryptography and key management
Encryption is used to protect sensitive data in transit or even to protect specific type of data in
storage. It is also used within authentication and authorization requests.
End-to-end security architecture
Figure 16 – General end-to-end security architecture
At the head end there is AMM which interfaces with meters and data concentrators/routers
(DC/R). Firewalls are recommended between portions of the system. The AMM can be placed
behind a firewall and allow traffic on specific port to pass through. The AMM needs to be able
to access its database as well as the enterprise management system and the meter data
management (MDM) application. These applications may be behind additional firewalls, or
they may be on the same network as the AMM itself, provided that the AMM has full two-way
access to the appropriate ports for data transfer. This initial communication is done using
TCP/IP.
DC/R sit between the IP Wide Area Network (WAN) and the low voltage Power Line (PL)
network (FAN – Field area network). The DC/R protects the PL network from IP network attacks
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Messages are encrypted using 128-bit AES keys. The command messages are signed using ECC
public/private keys.
All communications between devices including DC/R, smart meters and other possible vendor’s
devices are encrypted to hide all message contents. Encrypted communications ensure that
third-parties cannot eavesdrop on the network to compromise security, gain unauthorized
access to devices, nor gain access to customers’ private data.
Security on the meter and data concentrators/routers
Smart meters and data concentrator/routers (DC/R) form a mesh network based on radio
frequency (RF) or power-line communications (PLC) technologies. Every meter joining the mesh
network needs to get authenticated before being allowed access to the AMI infrastructure.
Strong authentication of nodes can be achieved by taking full advantage of a set of open
standards such as IEEE 802.1x, Extensible Authentication Protocol (EAP), and RADIUS. The
design recommendation is to use link-layer encryption in the mesh (AES on IEEE 802.15.4g or
IEEE P1901.2).
Smart meters and DC/Rs that contain cryptographic keys for authentication, encryption,
integrity, or other cryptographic operations require a cryptographic key management system
(CKMS) that must provide for the adequate protection of cryptographic materials, as well as
sufficient key diversity. A smart meter and DC/R should not be subject to a break-once breakeverywhere scenario, due to the use of one secret or private key or a common credential
across the entire electric infrastructure. Each device must have unique credentials or key
material such that compromise of one device does not impact other deployed devices. The
CKMS must also support an appropriate lifecycle of periodic rekeying and revocation. Key
exchange scenario must be defined according to vendor’s specification.
Public key cryptography is to be used in addition to symmetric key cryptography to secure the
communication between the Head-end and the meter. Asymmetric cryptography is used to provide
digital signatures for command verification and symmetric cryptography is used to provide data
confidentiality for the messages.
Additionally, data concentrator has to have additional security levels, such are intermediate meters
keys and data protection. Every device is shipped from the factory preconfigured with a readyto-use secure key infrastructure. Secure key infrastructure includes:
Meter unique keys
Each meter is factory configured with a private key, which is used to validate digitally signed
commands received from the Collection Engine and to authenticate the meter to the Collection
Engine during initial meter registration. Provides secure partitioned access to each individual
meter. Eliminates unauthorized access and ensures that in the unlikely event an individual
meter is compromised your entire grid would not become accessible to the attacker.
Meter read-only keys (optional)
Employees and software systems can be limited to read-only access if this is all they require to
do their jobs. Protects against unauthorized or accidental configuration changes and insider
threats.
Data concentrator/router unique keys
Each DC/R is assigned a unique private key during the manufacturing process. The key provides
secure partitioned access to each individual DC/R.
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Security on the WAN
The WAN provides network connectivity to the utility’s control center over either a service
provider network (cellular or fiber) or over a utility-owned network. It is recommended to use
network-layer encryption (AES with IPSec) in the WAN. Network and link-layer encryption can
be supplemented by use of application-layer techniques that verify message integrity and
proof of origin (digitally signed firmware images or digitally signed commands as part of C12.22
or DLMS/COSEM).
Additional level of security is added to remote update of firmware. Firmware can be updated
only by server that has certificate that was generated during initial installation of firmware.
Security on public WAN provider (GPRS/LTE, fiber)
The public WAN provider network (GPRS/LTE or fiber) protocol aims at protecting the network
against unauthorized use and the privacy of the users. The goal of the public WAN provider
service provider is to ensure that the subscriber is the real subscriber and provide the
subscriber with the service without having its privacy compromised, with data confidentiality
assurance.
Security in AMM center
Physical Security Environment
The protection of critical security parameters, such as keying material and authentication data,
is necessary to maintain the security provided by cryptography. To protect against
unauthorized access, modification, or substitution of this data, as well as device tampering,
cryptographic modules must include features that provide physical security and must be
validated as FIPS 140-2 cryptographic modules.
In AMM center, different security components can be implemented. We will mention just the
most important of them.
Signing and Encryption Server
The Signing and Encryption Server is responsible for securing command messages being sent
from the AMM to the meters. The keys must be very tightly controlled to ensure that the
system is not compromised. The private signing key of the Collection Engine is never exposed
in raw form. To protect the keys, the Signing and Encryption Server includes an integral
hardware security module (HSM). The HSM is FIPS 140-2 level 3 compliant.
Cryptographic Key Management System (CKMS)
Subsystem S1, Certification Authorities as Basis of Public Key Infrastructure. Public Key
Infrastructure (PKI) introduces digital identity within the system. Each involved person or
device has its own certificate for authentication and authorization purposes. The system
produces certificates that are stored on a different type of smart electronic documents – Smart
Employee Cards (SEC) - (card type or SIM card type) and security access modules for devices.
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Subsystem S2, Resource and identity certificates management performs production,
personalization, issuing and managing of Smart Employee Cards (SEC) - (card type or SIM card
type) and security access modules.
Subsystem S3, Symmetric key production. Products of the S3 system are raw key values. The
key generation process must ensure that all generated keys are unique and with a unique
identification no matter in which particular encryption device they would be later used. The
subsystem architecture and design must guarantee proper key management by tracking all
actions with the keys, starting from their generation until the end of their life.
Subsystem S4, Key distribution. The component that strongly interacts with PKI CAs and
symmetrical key generation system. Its product is a final encapsulated key which, in addition to
the key content also contains certificates; it can only be used in the device it is created for, and
only by authorized person.
AAA Server
An AAA server is a server program that handles user requests for access to computer resources
and, for an enterprise, provides authentication, authorization, and accounting (AAA) services.
The AAA server typically interacts with network access and gateway servers and with
databases and directories containing user information. The current standard by which devices
or applications communicate with an AAA server is the Remote Authentication Dial-In User
Service (RADIUS).
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FUNCTIONAL REQUIREMENTS - PRINCIPLES OF INTEGRATION
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The following basic integration requirements are listed below:
-
MDM/AMM systems should communicate with external systems using standardized
protocols and data formats
Service Oriented Architecture (SOA) is recommended
It is recommended to use an ESB integration component
Consider complementary EDA (Event driven architecture) systems which implemented
advanced capabilities for event processing.
Integration with the following systems must be implemented:
-
Current AMR systems in operation (import/export of data acquired from existing
meters)
Billing system
Meter asset management
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FUNCTIONAL REQUIREMENTS - GENERAL
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For AMM and MDM system the following performance parameters should be measured,
logged and subject to testing:
1. Time of master station inspecting the terminal important information
2. Response time of system controlling operation (time from remote command issuing to terminal
responding)
3. Response time of calling and setting routine data
4. Response time of calling historical data
5. Time for system responding to the event at client side
6. Response time of routine data query
7. Response time of fuzzy query
8. Response time of 90% interfaces switch
9. Time for automatic switching and function recovery of on line hot standby dual machine
10. Time for real data transmission in computer remote network communication
Reliability index:
1. Accuracy rate of remote control
2. Yearly availability rate of master station
3. Time of system fault recovery
Success rate index data acquisition
1. Success rate of primary acquisition
2. Success rate of period acquisition
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CHANGES TO THE DOCUMENT
Below please find the list of changes to the document made after it was adopted by the PE EPS
Expert Council in Belgrade on 12 November 2013.
In addition to eliminating the perceived typos, the document has undergone some changes in
terms of its logical organization:
The Consultant - Cesi (Deepview) has in order to allow the widest possible competition of
domestic and foreign manufacturers of industrial meters, mitigated some of the requirements
in the sense that the design of individual functionalities (e.g. display elements arrangement,
etc.) is no longer specified.
List of major changes
Following the already made changes to the industrial meters with direct type connection, the
general characteristics of single-phase and three-phase meters were aligned with equivalent
general characteristics of industrial meters with direct type connection:
• For all meters, connector requirements were clearly defined.
• Additional requirements were explained in terms of data structure indicated on the
display, without limiting the display design.
• Mandatory and optional pulse outputs for the direct connection meter were defined.
• Minimum number of load profiles is now 2.
• Hourly consumption value profile was renamed and further described.
• In the case where the meter cover is “sealed for life”, meter cover opening detection is
not required.
• Meter communication requirements were additionally clarified.
• Previous consumers management output was redefined as the control output for tariff
signaling.
• Request for external control of tariff registers was eliminated.
• Meter firmware update function description was simplified.
• Data security requirements were more precisely defined.
• New chapter regarding Security has been added
• New chapter regarding Integration has been added
• New chapter regarding router/gateway approach has been added
• New chapter regarding high-level architecture has been added
• Requirements regarding Cellular communication have been added/revised
• Requirement regarding AMM system have been added/revised
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