FUNCTIONAL REQUIREMENTS AND TECHNICAL SPECIFICATIONS OF AMI/MDM SYSTEM

Transcription

1 PE ELECTRIC POWER INDUSTRY OF SERBIA Expert Team for Advanced Networks Under the Order II 950/2 12 from FUNCTIONAL REQUIREMENTS AND TECHNICAL SPECIFICATIONS OF AMI/MDM SYSTEM Version 2.0 Adopted by Expert Council of JP EPS, Belgrade,

2 TABLE OF CONTENTS ABBREVIATIONS..7 FOREWORD INTRODUCTION OBJECTIVES, PRINCIPLES AND FUNCTIONS OF THE SYSTEM SYSTEM CONTEXT LOAD ANALYSIS LOAD MANAGEMENT OUTAGE MANAGEMENT SYSTEM (OMS) ELECTRIC DISTRIBUTION NETWORK CONTROL NETWORK PLANNING CUSTOMER INFORMATION SYSTEM (CIS) POINT OF DELIVERY MAINTENANCE WORK MANAGEMENT SYSTEM STRUCTURE AMI ELECTRONIC MULTIFUNCTIONAL METER CONCENTRATOR AMM CENTRE MDM SYSTEM ARCHITECTURE SELECTION OF COMMUNICATION TECHNOLOGIES SYSTEM PERFORMANCE SELECTION OF FUTURE COMMUNICATION TECHNOLOGIES PROPOSAL OF SYSTEM IMPLEMENTATION STRATEGY AT PE EPS CONCLUSION ANNEX 1 AMI OVERVIEW OF BASIC DATA AND COMMANDS ANNEX 2 CALCULATION OF DATA AMOUNT ANNEX 3. APPLIED STANDARDS ANNEX 4: LITERATURE: FUNCTIONAL REQUIREMENTS AND TECHNICAL SPECIFICATIONS OF AMI SYSTEM FUNCTIONAL REQUIREMENTS FOR AMM CENTRE DESCRIPTION AND GENERAL REQUIREMENTS FOR AMM CENTRE IN AMI CONTEXT AMM CENTRE FUNCTIONS Page 2

3 2.1 ADMINISTRATION FUNCTIONS AMM CENTRE DATA COLLECTION/READING AND MEMORISING FUNCTIONS REPORTING FUNCTIONS OF AMM CENTRE DATA AND INFORMATION EXCHANGE FUNCTIONS WITH MDM SYSTEM AND OTHER ISS OF ELECTRIC UTILITY TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR LOW VOLTAGE CONCENTRATOR TECHNICAL CHARACTERISTICS OF LOW VOLTAGE CONCENTRATOR CONCENTRATOR ROLE AND FUNCTIONS CONCENTRATOR ROLE GENERAL DESCRIPTION OF CONCENTRATOR FUNCTIONS TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR GPRS MODEM BASIC CHARACTERISTICS OF GPRS MODEM REQUIREMENTS FOR GPRS MODEM GENERAL REQUIREMENTS FOR GPRS MODEM TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR PLC MODEM BASIC TECHNICAL CHARACTERISTICS OF S FSK PLC МОDЕМ BASIC REQUIREMENTS FOR S FSK PLC COMMUNICATION ILLISTRATION OF MUTUAL RELATION OF PLC COMMUNICATION STANDARDS GENERAL REQUIREMENTS FOR PLC МОDЕМ FUNCTIONAL REQUIREMENTS FOR SWITCHING MODULE (BISTABLE SWITCH) SWITCHING MODULE (BISTABLE SWITCH) INTEGRATED SWITCHING MODULE (BISTABLE SWITCH) EXTERNAL SWITCHING MODULE (BISTABLE SWITCH) TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR SINGLE PHASE ELECTRICITY METERS GENERAL TECHNICAL CHARACTERISTICS OTHER TECHNICAL CHARACTERISTICS METER FUNCTIONS METERING, REGISTRATION AND DISPLAY FUNCTIONS ADDITIONAL FUNCTIONS CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT ELECTRICITY METERING QUALITY METER FIRMWARE UPGRADE SELF CHECK МULTI UTILITY METERING Page 3

4 2.8. DATA SECURITY TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE PHASE ELECTRICITY METERS GENERAL TECHNICAL CHARACTERISTICS ОTHER TECHNICAL CHARACTERISTICS METER FUNCTIONS METERING, REGISTRATION AND DISPLAY FUNCTIONS ADDITIONAL FUNCTIONS CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT ЕLECTRICITY QUALITY METERING METER FIRMWARE UPGRADE SELF CHECK МULTI UTILITY METERING DATA SECURITY TECHNICAL CHARACTERISTICS FOR DIRECT CONNECTION (ТHREE PHASE DIRECT METERING GROUP) GENERAL TECHNICAL CHARACTERISTICS ОTHER TECHNICAL CHARACTERISTICS METER FUNCTIONS METERING, REGISTRATION AND DISPLAY FUNCTIONS ADDITIONAL FUNCTIONS CONSUMPTION AND ELECTRICAL DEVICES MANAGEMENT ЕLECTRICITY QUALITY METERING METER FIRMWARE UPGRADE SELF CHECK МULTI UTILITY METERING DATA SECURITY TECHNICAL CHARACTERISTICS OF METERS FOR SEMI INDIRECT CONNECTION (ТHREE PHASE SEMI INDIRECT METERING GROUP) GENERAL TECHNICAL CHARACTERISTICS ОTHER TECHNICAL CHARACTERISTICS METER FUNCTIONS METERING, REGISTRATION AND DISPLAY FUNCTIONS ADDITIONAL FUNCTIONS ELECTRICAL DEVICES MANAGEMENT ЕLECTRICITY QUALITY METERING Page 4

5 2.5. METER FIRMWARE UPGRADE SELF CHECK МULTI UTILITY METERING DATA SECURITY TECHNICAL CHARACTERISTICS OF METERS FOR INDIRECT CONNECTION (ТHREE PHASE INDIRECT METERING GROUP) GENERAL TECHNICAL CHARACTERISTICS ОTHER TECHNICAL CHARACTERISTICS METER FUNCTIONS METERING, REGISTRATION AND DISPLAY FUNCTIONS ADDITIONAL FUNCTIONS ЕLECTRICITY QUALITY METERING METER FIRMWARE UPGRADE SELF CHECK DATA SECURITY ADDITIONAL METER FUNCTIONS FOR CONNECTION OF ELECTRICITY GENERATON FACILITIES MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR METERS WITH DIRECT CONNECTION (DIRECT METERING GROUPS) MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR METERS WITH SEMI INDIRECT CONNECTION (SEMI INDIRECT METERING GROUPS) MAXIMUM REACTIVE POWER MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR METERS WITH INDIRECT CONNECTION (INDIRECT METERING GROUPS) MAXIMUM REACTIVE POWER OPTIONAL SCOPE OF ADDITIONAL FUNCTIONS SEALING PROFILES OF METERED AND REGISTERED VALUES MAXIMUM APPARENT POWER MINIMUM POWER FACTOR DATA STORAGE PERIOD OPTIONAL SCOPE OF ADDITIONAL FUNCTIONS FOR METERS WITH SEMI INDIRECT CONNECTION (SEMI INDIRECT METERING GROUPS) LIST OF MANDATORY TESTINGS (АТTESTS) ACCORDING TO THE RELEVANT STANDARDS LIST OF MANDATORY TESTINGS (АТTESTS) FOR SINGLE PHASE AND THREE PHASE METERS Page 5

6 LIST OF MANDATORY TESTINGS (АТTESTS) FOR DIRECT AND SEMI INDIRECT METERING GROUPS LIST OF MANDATORY TESTINGS (АТTESTS) FOR INDIRECT METERING GROUPS ACCURACY CLASS 0.5S AND 0.2S LIST OF FUNCTIONAL METER TESTINGS FUNCTIONAL REQUIREMENTS OF METER DATA MANAGEMENT AND REPOSITORY SYSTEM (MDM/R) METER DATA MANAGEMENT AND REPOSITORY SYSTEM (MDM/R) ABBREVIATIONS DEFINITIONS OF TERMS AND EXPRESSIONS APPLIED STANDARDS PURPOSE SCOPE MDM/R SYSTEM OVERVIEW GENERAL FUNCTIONAL REQUIREMENTS DETAILED FUNCTIONAL REQUIREMENTS OVERVIEW OF FUNCTIONALITIES REGULATORY AGENCY REQUIREMENTS UNIQUE POINT OF DELIVERY (POD) ID NUMBER DATA ENTRY INTO MDM/R SYSTEM TIME FLOW OF DATA EXCHANGE DATA SUBMISSION BY MDM/R SYSTEM Data management Functional requirements in terms of data storage AMENDMENTS TO DOCUMENTS: Page 6

7 ABBREVIATIONS Table 1 Overview of used abbreviations AMCD AMR AMRC AMI AMM AMCC CET CIM CIS COSEM DLMS IEC MDM/R OMS RF Advanced Metering Communication Device Automated Meter Reading Advanced Metering Regional Collector Advanced Metering Infrastructure Automated/Advanced Metering Management Advanced Metering Control Computer Central European Time Common Information Model Customer Information System Companion Specification for Energy Metering Device Language Message Specification International Electrotechnical Commission Meter Data Management and Repository Outage Management System Radio Frequency Page 7

8 FOREWORD In accordance with the task stipulated by the Decision of General Manager of JP EPS no. 950/2 12 dated , Expert team for the adjustment of current Functional requirements and technical specifications of AMI/MDM system with new technical solution has, after: Assessment of current situation in Europe in the field of standardization of relevant communication technologies, Analysis of the experience of leading European electricity distributors that achieved significant steps in the field of introducing AMI/MDM system, Analysis of the comments and suggestions of local and foreign reputable meter manufacturers, Analysis of feedback by EPS subsidiaries, Analysis of the reason for previous meter procurements failure and Analysis of remarks by consultants CESI, modified the document Functional requirements and technical specifications of AMI/MDM system. Then, inter alia, the following was done: - Spotted mistakes and inaccuracies in certain descriptions were removed, - Logical reorganization of document with the reduced number of technical descriptions of meter was made, - Chapters that describe technical and functional requirements for integrated and external PLC modems were introduced, - Chapters that describe technical and functional requirements for integrated and external switching module were introduced, - Chapters that describe additional technical and functional requirements for meter planned for installation in facilities for electricity generation were introduced, - The list of mandatory meter testing according to requirements under relevant meter standards was made and - The list of functional testing of meter during technical acceptance was made. Thereby, and in accordance with clear definition of the task from Decision, the Expert team did not amend foreseen protocols, concepts and other important elements of the system, defined by the document adopted by the Expert Council of JP EPS in Belgrade on Belgrade, December Page 8

9 1. INTRODUCTION Adopted by Expert Council of JP EPS April 29, 2010, Belgrade, Advanced system for metering and management of electricity consumption, reading of electricity meters (hereinafter: meters), data processing and storage (Smart Metering System hereinafter referred to as: the System ) includes advanced metering infrastructure (AMI), automated metering management and meter data management and repository (MDM/R). AMI is the infrastructure under which data stored in meters marked by exact date and time are periodically remotely collected by means of a concentrator (AMRC) and transferred to the advance metering control computer (AMCC) within AMM Centre, and further on to the centralized MDM system. Remote data collection can also be realized in direct communication between meters equipped by corresponding communication modules (AMCD) and AMCC. AMR/AMM systems have been characterized with very rapid development in the current decade. After initial attempts in the beginning of this decade, and by considering standardized trends in the EU and the USA, it is clear that full inter operability of meters and other AMI components of different manufacturers will soon be achieved. This will enable mass replacement of older generation meters (roll out) and transition of electrical utilities (ELU) subsidiaries to a new business level and implementation of Smart Grids concept. Figure 1 Smart Metering system The System will be implemented in accordance with the relevant standards. Under circumstances of continuous development of technologies and accompanying standards, the proposed solution has been aligned with the latest developments in this field. Basic part of the material includes technical and functional specification. The task of introductory texts is to explain more closely the objectives, principles, context, requirements, approach to system implementation and everything having an impact on the contents of the technical specification. Page 9

10 . 2. OBJECTIVES, PRINCIPLES AND FUNCTIONS OF THE SYSTEM General objective of System introduction is improvement of energy efficiency and stimulation of more rational energy usage in accordance with the European objective 20/20/20, i.e. 20% more of renewable energy sources, 20% less of CO 2 emission and 20% increase of energy efficiency in EU by 2020, all under the broader Smart Grids platform. The most important implementation objectives of the System include the following: reduction of reading costs and increase of the number of read electricity meters; increase of metering accuracy and reduction of the number of complaints; acceleration of invoice issuing and reduction of collection period; increase of customer analytics, possibility of remote disconnection of customers and increase of collection rate; reduction of non technical losses; implementation of technological platform for application of complex tariff system; improvement of network and load management (better usage of existing capacities and postponement of investments into electric power system); improvement of network development planning; reduction of maintenance costs; shortening of interruption duration time and distribution network reliability increase; Implementation of the basis for Smart Grids. Fulfillment of these objectives will bring multiple advantages, enabling rapid return of invested assets, in some areas even in 6 months. The System is based on the following principles: interoperability 1 ; reliability; scalability; flexibility; 1 Interoperability is the capacity of the device of at least three manufacturers to exchange and use information automatically within the System by recognising their scope, format and meaning. Page 10

11 modularity; automatic recognition and introduction of components into the System ( plug and play ); bidirectional communication; data security; unification and standardization of functions and controls of the System. The system possesses the following functions: remote reading of all metered (registered) values with elements of the System; remote change of parameters of System components; remote connection/disconnection of customers; storage and archiving of remotely read data; review, graphic presentation and analysis of data; automatic detection of newly installed meters in the System; automatic reconfiguration of the path and finding of optimal repeater routes; possibility of access of others users to memorized data; possibility of usage of pre paid meters; possibility of data collection from other types of metering devices such as gas meters, water meters, heat meters, etc. (multi metering); possibility of connection with HAN (Home Area Network). Page 11

12 3. SYSTEM CONTEXT Adopted by Expert Council of JP EPS April 29, 2010, Belgrade, Context of AMI/MDM system from the aspect of directly affected business functions of electric utilities (reference architecture) reflects eight logic/abstract components (potentially realized as information subsystems), as follows: [17] Outage management (OMS) Network planning [1] Customer account information [2] Configuration and installation [3] Control and signalling [4] Buyer information [5] Special consumption reading [6] Signals for required consumption [7] Connection/Disconnection [8] Mounting, Dismantling, Repair, etc [9] Load curves, metering archive [10] Tariff policy [11] Metering point state [12] Consumption data records [13] Consumption data [14] Request for metering point repair [15] Consumption reading request [16] Outages and verification of restoration [17] Supply reliability and quality [18] Readings, events and signals [19] Special reading [19] [20] Parameters and tariffs [21] Information exchange [22] Exchange of records Metering point [2] Metering point maintenance and asset management [8] [12] [14] Management of works [5] AMI [18] [9] [3] [20] Data acquisition AMM Centre Management and reconfiguration [11] Network management [9] [3] [18] [6] [10] [7] [16] [13] Load analysis Load management system Load management MDM/R system Customer Support and Billing Electricity delivery [12] [4] [12] [1] [9] [14] ммм Figure 2 Smart Metering system in the context of business functions of electricity distribution companies 3.1 LOAD ANALYSIS Load management system is used for load management control for the purpose of improving electricity distribution system operation reliability, with the execution of different analyses. The most frequently used analyses are as follows: load forecast, security analysis, simulation of various scenarios of load management command issuing, as well as other energy calculations. This abstract component is mostly used within the domain of operational planning and optimization Page 12

13 3.2 LOAD MANAGEMENT Adopted by Expert Council of JP EPS April 29, 2010, Belgrade, Consumption reading system is frequently used as the communication gateway for the needs of load management in case of individual devices of customers, supplied through special installations. Advanced meters, equipped by switches, enable remote connection/disconnection of customers as well as the power limiter function. Load management may be implemented from emergency reasons (code red) or economic reasons. 3.3 OUTAGE MANAGEMENT SYSTEM (OMS) OMS is used by the distribution system operator for the purpose of detecting and monitoring of outages within the electric distribution network, as well as outage verification and/or supply restoration. OMS is a very complex system considering that it is functionally connected with different domains and their business sub functions. The most important of all domains and business sub functions are: fault management under the network management, simulation of management actions within operational planning and optimization, work management and supervision under maintenance and construction. Due to time sensitive nature of outage detection, i.e. due to the need to have a reaction as quick as possible, there is potential need for interface implementation towards AMM Centre for the purpose of generating additional reading requests. Based on these readings on request, OMS automatically detects the status of network resources in terms of voltage presence and submits them to other subsystems for further analysis. The above interface for the needs of additional request for load data reading may be used by the dispatcher in cases when the customer supply status has to be verified after supply restoration, before the dispatcher sends a crew to the field for further manipulations aimed at supply restoration of other customers affected by the outage. 3.4 ELECTRIC DISTRIBUTION NETWORK CONTROL Electric distribution network control system has the need to control the load of system elements, but also to generate the change of electricity price signals in different tariff packages NETWORK PLANNING Business function of network planning requires recorded data on consumption, transformer and line load, as well as on past electric distribution network status, for the purpose of execution of various planning optimizations and simulations. Page 13

14 3.6 CUSTOMER INFORMATION SYSTEM (CIS) Customer information system covers the functionalities related to customers and collection. In addition to this, basic functionalities are related to information offering through electric utility information centre, as well as for receiving fault complaints from customers. Customer information system deals with the processes related to accounting complaints, customer disconnection due to non payment, reconnection after the settlement of financial liabilities and change of tariff packages. 3.7 POINT OF DELIVERY MAINTENANCE Every electric utility possesses an information subsystem for asset management, aimed at maintaining detailed records concerning its tangible assets. Property management is included within the domain of asset management. However, for the needs of point of delivery and meter records, having special requirements, all electric utilities use specialized software modules for asset management of points of delivery. Software module for asset management of points of delivery provides records of physical attributes, as well as data on location and installation of equipment. Moreover, the system is responsible for the maintenance of functionalities related to configuration and installation of the meter. Point of delivery asset maintenance system is closely connected to AMI and MDM system. 3.8 WORK MANAGEMENT Business function dealing with work management is responsible for activities performed within electric distribution network from resources possessed by the electric utility. Compared to activities related to metering, work management includes installation, dismantling and replacement of advanced meters, as well as execution of special readings on request. 4. SYSTEM STRUCTURE The System consists of: AMI MDM 4.1. AMI Generally, AMI (Figure 3) consists of the following components equipped by corresponding communication modules: Multifunctional electronic meters Concentrators AMM Centre communicating by means of data transfer subsystems. Technical characteristics of communication modules/modems have been described in detail in special documents: Technical Characteristics and Functional Requirements for PLC Modem and Technical Characteristics and Functional Requirements for GPRS Modem. Page 14

15 Figure 3 АМI architecture Data transfer subsystems have to enable reliable and fast bidirectional data transfer and exchange of alarms and commands between AMI components. Annex 1 (AMI Overview of Basic Data and Controls) provides an overview of basic data and controls transferred between AMI components with corresponding time stamp. Technical solution of subsystems for data transfer shall be such to have capacity sufficient for AMI components to perform all the set tasks within specified time periods. Communication between AMM Centre and other components of the System is performed through WAN. Data transfer subsystem shall provide a corresponding code protection of transferred data (e.g. protection against unauthorized reading, unauthorized command generation, ill intentioned submission of false data, etc.). It is desirable that between AMM Centre and concentrators/gprs industrial meters there are at least 2 communication paths for data transfer, one primary and the other secondary serving as stand by in case that the primary communication path is not functioning. Every electric utility will in accordance with its current state of telecommunication and computer infrastructure define redundant communication directions towards System components. Page 15

16 ELECTRONIC MULTIFUNCTIONAL METER Multifunctional electronic meters (Smart Meters) are installed for metering and reading of consumption and power, recording of events and possible disconnection/connection at the point of delivery of the customer. Technical characteristics of all types of meters (single phase, three phase, industrial meters with direct type connection, industrial meters with current transformer type connection and industrial meters with current and voltage transformer type connection) have been considered in detail in special documents (Technical Characteristics and Functional Requirements for Single Phase Electricity Meters, Technical Characteristics and Functional Requirements for Three Phase Electricity Meters, Technical Characteristics and Functional Requirements for Three Phase Electricity Meters direct metering group, Technical Characteristics and Functional Requirements for Three Phase Electricity Meters semi indirect metering group and Technical Characteristics and Functional Requirements for Three Phase Electricity Meters indirect metering group) CONCENTRATORS Concentrators are autonomous devices executing automatically or on request the functions of meter reading and parameterization and delivery of read data to AMM Centre. They are realized in accordance with standards for industrial computers (resistant to temperature, humidity, dust, vibrations, electromagnetic radiation and other) adapted to operation conditions in substations (SS). In general case we may have several levels of concentrator depending on the concept and implementation of data transfer system. Technical characteristics of concentrators have been considered in detail in a special document Technical Characteristics and Functional Requirements of Low Voltage Concentrators AMM CENTRE AMM Centre is based on the concept implying remote reading and simultaneous efficient supervision and management of other AMI components, high data processing speed in multiuser environment, connection with other information systems and data transfer into MDM. Data are stored into the data base of standard and licensed system for relation data bases management. Applied data model has to be such to enable simple integration with other information systems and subsystems implemented in individual electricity distribution companies. AMM Centre functions in terms of data reading and configuration should also be executed on laptops, connected directly to the concentrator or meter. In addition to this, functions related to data reading and meter configuration should also be executed on laptops or terminals with for example optical interface for direct (local) meter configuration. Functional requirements for AMM Centre have been considered in detail in a special document: Functional Requirements for AMM Centre. Page 16

17 4.2. MDM MDM system provides joint infrastructure for data receipt on metered consumption from the implemented AMI system within one electric utility, it potentially calculates consumed electricity (i.e. provides data necessary to the system for calculation and collection of electricity), preserves and manages data, and it also provides access to subject data to all interested parties. It was anticipated for MDM to use WAN for connection with all entities within electricity distribution companies, as well as with all interested parties. AMM Centre is expected to transfer data on read electricity consumption into MDM system on a daily basis, whereas, it uses a joint protocol SRPS EN 61970/61968 and data transfer structure. Generally, MDM system provides: Receipt and upload of data on metered consumption sent by AMM Centre; Receipt and upload of other data sent by AMM Centre, primarily related to voltage drops and deviations, indication of supply outages and various warnings; Validation, editing and assessment of data on metered consumption; Data storage, management and maintenance; Analysis of energy balance according to logical wholes, as well as generation of corresponding reports *; Other necessary reporting functions; Expandability in terms of full implementation of advanced metering; Revision of all altered data; Data traceability within the entire MDM system; Security in access management to all functions and data; Calculation of consumed electricity for each delivery point based on different price structures, including hourly and other specified period of tariff rates; Data based on previously defined schedule or on request; Receipt and management of support information exchanged between points of delivery, advanced meters, electric utility and interested third parties within MMD subsystem. * Analysis of energy balances is one of the most important analyses MDM needs to have. Without this analysis it is practically impossible to use data obtained from AMM Centre properly for the purpose of identifying and reduction of electricity losses and thereby energy efficiency increase which is one of the System introduction objectives. Page 17

18 Functional requirements for MDM have been presented in detail within a special document: Functional Requirements of Meter Data Management and Repository System (MDM/R). 5. SYSTEM ARCHITECTURE AMI/MDM system architecture may be conceived in several ways depending on PE EPS organisation, concentration and spatial distribution of customers, etc. Before system implementation itself, AMI/MDM system implementation project will be realised. One of the tasks of AMI/MDM system implementation projects is the defining of system architecture, based on all necessary analyses. The following text contains some of the possible architecture models. In this manner, a connection is achieved between technical specification and the real environment. AMI/MDM system will be implemented within the existing telecommunications and computer structure in subsidiaries 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). Communication between АММ and MDM centres is also carried out within the existing telecommunications and computer structure of subsidiaries within PE EPS, in a manner that required redundancy of communication route/routes is fully enabled. In case of data transmission outside of the computer or telecommunications network of a subsidiary, data encryption is mandatory. Depending on the size of demand area of individual subsidiaries, the scope of AMI/MDM system will be in the range from to 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. It is possible to have one AMI/MDM centre at the level of PE EPS, or on the level of a larger number of subsidiaries within PE EPS, or on the level of each of the existing subsidiaries. Based on the overview of the state of AMR/AMM system in Serbia and Europe, as well as experience on working with this kind of system, AMI/MDM system architecture shown in Figure 4 is proposed. Page 18

19 Corporate enterprise centre AMM Centre Meter Data Repository LAN MDM system (Meter Data Management) Mobile phone operator WAN Concentrator PLC Subsidiary/Op. unit Subsidiary/Op. unit Concentrator PLC Households Advanced meters Industry Industry Advanced meters Households Figure 4 Centralised architecture of AMI/MDM system In this architecture there is only one AMM Centre within electric utility communicating with all concentrators and meters, installed in all subsidiaries/operational units of the company. Under all proposed variants, AMI within one subsidiary/operational unit is implemented in the manner shown in Figure 3. In this variant, as well as in the following variants there is only one MDM system for data receipt and storage from AMM Centre on the level of electric utility. Such implementation of AMI/MDM system reduces requirements in subsidiaries/operational units in terms of human and hardware resources and it is more acceptable for the current state in electricity distribution companies. It is a natural choice in the first phase of System implementation. Page 19

20 Figure 5 Decentralised architecture of AMI/MDM system Development perspectives of such system in electric utilities also indicate another architecture variant. It is applicable when the number of advanced meters in the subsidiary/operational unit grows to such number that centralized architecture would not be cost effective (when investments into technical solutions enabling reliable functioning of thus conceived System would be too high). This architecture is shown on Figure 5. Every subsidiary/operational unit would have an independent AMM Centre, while data memorizing would be centralized. In order to have this type of implementation, subsidiaries/operational units need to have corresponding infrastructure (communication and computer) as well as trained staff. Page 20

21 Data storage (Meter Data Repository) Corporate enterprise centre AMM Centre LAN MDM system (Meter Data Management) WAN AMM centre AMM centre AMM centre Subsidiary/Op. unit Subsidiary/Op. unit Subsidiary/Op. unit Figure 6 Distributed architecture of AMI/MDM system There is one more variant, shown on Figure 6, where in every subsidiary/operational unit of electric utility there is one AMM Centre installed. All AMM centres in the subsidiary are connected via WAN to the main AMM center located in the computer centre of electric utility. This AMM centre collects all data from subordinate AMM centres and it forwards them to the unique MDM system. Functional requirements for AMM Centre are provided in the accompanying documents have not considered this type of architecture. 5.1 SELECTION OF COMMUNICATION TECHNOLOGIES It is clear from the proposed System architectures that communication technologies are essential for System implementation. Due to relatively low construction level of telecommunication infrastructure on low voltage and medium voltage network in all electricity distribution companies, it is necessary for the System to rely on existing public telecommunication services of mobile telephony and package information exchange, i.e. where it is possible, to rely on existing IT infrastructure within PE EPS. Naturally, in terms of using the resources of the public telecommunication service, it is necessary to achieve such usage prices acceptable for both sides, considering that tariffs are exclusively based on realised data flow. Electric utilities need to accelerate the expansion of their own telecommunication infrastructure, especially if economically acceptable conditions for the usage of public phone service may not be obtained for System needs. By considering the requirements for System performance from point 5.2, the current state in terms of construction level of own telecommunication infrastructure, development trends of AMI/MDM in EU, as well as previous experience in working with such system, the following solutions for communication paths are proposed at this moment. Page 21

22 Communication between meters and concentrators In this architecture, selection of communication along low voltage energy lines (PLC) as the manner to establish bidirectional communication between concentrators and meters is natural. Communication goes on along LV lines owned by electric utility and it does not require additional investments into TT infrastructure. As the price of such PLC modems is sufficiently low, they may be largely applied. Currently valid standard for this communication is SRPS IEC and it is required in the part of specifications for PLC modem. Communication between concentrators and AMM Centre GPRS communication through the public mobile telephone network imposes itself as the currently most profitable option. This solution is standard and it is very easy to obtain corresponding modems on the market. Since there are several mobile phone operators there is less danger from depending on one operator (in terms of prices and service quality). Such communication goes on via special APNs which are the part of the contract with the service provider. Communication between meters and AMM Centre If meters are equipped with special modems enabling direct communication with AMM Centre, GPRS communication via public mobile phone network imposes itself as the currently most profitable telecommunication technology as in the previous point. Communication between mobile phone operators and AMM Centre As stated above, usage of mobile phone operator services for implementation of GPRS communication requires the provision of direct connection from the provider to AMM Centre (WAN). This connection has so far been realized as frame relay connection and it should have transfer ratio of at least 5 Mb/s with possible expansion based on needs. Page 22

23 5.2 SYSTEM PERFORMANCE Adopted by Expert Council of JP EPS April 29, 2010, Belgrade, In accordance with selected architecture and selection of communication technologies we can provide some System characteristics. At this moment they are as follows: minimum throughput of communication paths: o Meters (PLC) Concentrators 2.4 kb/s o Concentrator (GPRS) APN (Mobile phone network) 53.6 kb/s o Meters (GPRS) APN (Mobile phone network) 53.6 kb/s o APN (Mobile phone network) AMM Centre 5 Мb/s Reliability of data transfer: o occurrence probability of wrong message which may be interpreted as correct is lower than 10 6 ; System response speed (response time to the command given to System component); o 97% success rate within 5 minutes. o 99.5% within 30 minutes. Reading success of metered (registered) value in given time frames: o 98% success rate for one daily reading of meter registers, meter statuses (in case of meters without peak power calculation), electricity quality log and event log within 22 hours from the moment of recording of such daily value. o 98% success rate for complete daily meter reading (in case of meters with peak power calculation), load profile, electricity quality log and event log within 22 hours from reading initiation. o 98% success rate for complete reading of monthly accounting data from all meters within the demand area within 22 hours from initiation of such reading. Failure intensity of system components: o Meters 0.2% annually, 2% in operation life. o Modems 0.2% annually, 2% in operation life. o Concentrator 0.1% annually, 1% in operation life. Page 23

24 System capacity for data set migration: o 10 ТB annually. Operation life of System components. o Meters minimum 15 years. o Modems 15 years. o Concentrators (hardware) 10 years. o АММ Centre (hardware) 5 years. Taking into consideration the selected communication technologies and performance, calculation was provided in Annex 2 (Calculation of Data Amount), indicating what data amount needs to be transferred on a daily basis and how demanding reading options are in terms of data transfer and storage on daily and annual levels. The calculation includes parameters of realistic demand area. Communication path restrictions may be clearly identified here from the meter to AMM Centre. One of the restrictions is PLC communication realised according to SRPS EN (S FSK modulation) enabling transfer speed up to 2.4 kb/s. Obviously this speed can hardly be expected under real life conditions in LV network and speed of 1 kb/s may be considered as acceptable. Considering this, for meters from the category of households, it may be requested that data on one daily value have to be transferred within 22 hours at the latest to the electricity quality log and event log. With all these data in AMM Centre, i.e. MDM it is possible to gain a very good image on the state of meters in the field and make energy balances per day. For meters with customers having peak power charged, reading priorities are slightly different and in this case load profile transfer is obligatory. The number of these customers is not high; therefore this requirement is realistic and achievable. This group also includes meters with total consumption at the substation x/0.4 kv. The calculation given in the annex demonstrates that about 4 TB of storage space needs to be provided annually for data coming from the meters. Since the calculation does not take into account data on reserved communication logs, it should be anticipated that annually minimum 10 TB of storage space is necessary. 5.3 SELECTION OF FUTURE COMMUNICATION TECHNOLOGIES AMI/MDM System is conceived modularly; therefore it is possible to improve drastically System performance with the development of new communication technologies. Among the announced technologies which may have an impact on the System development, the following may be singled out. Page 24

25 Communication between the meter and the concentrator Announcement of the new type of PLC communication will remove restrictions in communication between concentrators and meters. PRIME project is testing the new type of modulation of PLC communication (OFDM) which should enable speeds of about 100 kb/s. Under this speed all data recorded by meters within one day in one substation region would be transferred in several hours. It is expected that during the next year PRIME will announce the draft of new PLC communication standard. In addition to this, development of ZigBee RF communication should be closely followed which may be applied within the larger meter grouping in one place (residential buildings). Communication between the concentrator and AMM Centre In this case new areas are opened for the usage of several types of communication: 3G, PLC on medium voltage, WiMAX, TETRA system, optics... Depending on the market state and the relation between prices and performance, decision on the selection of communication technology should be duly revised. Communication between the meter and AMM Centre The above said may also be applied in this point. Communication between mobile phone service providers and AMM Centre Depending on the state of communication network of electricity distribution companies, this connection might not be necessary in the future. If however it remains present, available technologies will be used enabling the increase of data transfer speed. 6. PROPOSAL OF SYSTEM IMPLEMENTATION STRATEGY AT PE EPS For the purpose of efficient, economic and fast implementation of the System within EPS, implementation strategy should meet a high number of objectives, the following being the most important ones: 1. Priorities in terms of place and introduction method of the System in EPS, 2. Level and scope of consumption management. In accordance with already mentioned reasons for System introduction (energy efficiency improvement and stimulation of more rational energy usage), the following priorities may be identified for Remote Reading System introduction: 1. Remote reading projects of customers on medium voltage and low voltage level one. 2. Remote reading in SS on voltage levels 35/20/10/0.4 kv aimed at loss location. 3. Remote reading projects within a large number of LV substation regions under the criterion of electricity loss level and total cost effectiveness. Page 25

26 Necessary design documents should be developed before the beginning of System implementation. All newly installed meters, together with currently installed pilot projects, remain the part of the future System. The question of integration of existing pilot projects into the unique system may be answered with the position that existing systems have already proven themselves to be cost effective, not only because of the advantages from fast and accurate reading and registering of consumed electricity, but also due to experience gained during the monitoring of their operation. Thereby, considering the principles and objectives of the future System, existing AMR projects which cannot reliably and simply be integrated in the future System (either some of the principles are affected or more funds need to be invested for the transition than for simple replacement) should be abandoned immediately or until the full introduction of the designed System. Term abandon implies the retention of the basic metering function of installed meters in the field, if possible, but without further investment into system maintenance (without servicing of faulty meters or system interventions). Existing AMR projects, which can simply or feasibly be integrated into the future System, with the cooperation with the suppliers of these systems, where possible, should be integrated. System introduction itself may be realised in several ways: Installation of meters prepared for remote reading, without communication module. Later System implementation. Installation of the complete System (through regional projects, etc.) from one manufacturer. Installation of the complete System (through regional projects, etc.) from several component manufacturers. Having in mind that the defined principles of the System (primarily interoperability), expert team proposes the third approach, i.e. installation of the complete System from several manufacturers, where interoperability is provided by precisely defined technical specifications and special requirements to be defined through general tender conditions. Implementation of the System implies implementation of the complete architecture in accordance with Section 5, through establishment of AMM Centre and MDM system and procurement and installation of other AMI components. Level and scope of consumption management within the demand area of EPS is the next strategic issue, whereas, consumption management advantages are not questioned, i.e. consumption management represents an orientation of EPS. System implementation method, anticipated from the start to enable all consumption management functions, may be realised in several ways: Installation of meters with integrated switches in all places where meter mounting with direct connection is anticipated. This provides uniformity, simplicity and installation speed, as well as full implementation of the System, which can start returning the invested funds very quickly through properly regulated consumption. Consumption management functions realised in this manner include the limitation of the permitted power of all customers, as well as remote disconnection/connection of debtors. Page 26

27 Basic disadvantage of this approach is relatively high price of introduction. Installation of meters without internal switch i.e. meters with external mounting of the switching module, in all places where meter mounting with direct connection is anticipated. By installing the corresponding switch, consumption management function is enabled, primarily remote disconnection of debtors. It is estimated that no more than 20% of meters have to be equipped with external switches, not forgetting that switches are modular and that they can be moved if necessary. Advantage of this approach is primarily in reduced costs of System procurement. On the other hand, all advantages related to consumption management on the entire demand area of EPS are reduced and drastically postponed. Finally, in case that the final percentage of meters with external switches is sufficiently high, total price of thus implemented System may exceed the total price of the System proposed in the following point. Installation of meters with integrated switches in a number of places where meter mounting with direct connection is anticipated. Selection of these places is in accordance with the needs of company parts where the System is introduced. In other places where meter mounting with direct connection is anticipated, meters with external mounting of switching module are mounted first. Later, based on the needs and possibilities of electric utility in question, procurement and installation of external switching modules is performed, taking into consideration the requirements from the technical specifications for meters with external switches. It is obvious that this is consumption management principle according to priorities, where meters with internal switches are installed in places of high, while meters with external switches in places of lower priority. In system terms, consumption management functions are realized, more precisely enabled at the start only on meters with an internal switch, and if necessary in other places through procurement and installation of corresponding external modules. Advantage of this approach is reduction of the financial pressure during the introduction of this System, with the settlement of priority places in terms of consumption management. Architecture modularity of the System, i.e. System components, enables simple expansion of consumption management function in accordance with the needs and possibilities of electricity distribution companies, without the need for the change of previously installed meters (meters with external mounting of the switching module anticipated). Considering the defined objectives on energy efficiency increase, and also taking into account the resources of PE EPS, expert team also proposes the third approach: meter installation with integrated switches on a number of subject places of delivery, installation of meters with Page 27

28 external installation of switching modules on other points of delivery (where meter installation with direct connection is anticipated) and later procurement and installation of switching modules in accordance with the needs of different company parts. Amounts and types of meters and corresponding external switching modules will be defined through tender requirements. Verification of these positions and final agreement regarding this dilemma will be given by the concrete economic analyses, which will precede the publishing of the public invitation for procurement. 7. CONCLUSION This document provides the description, objectives, principles and functions of AMI/MDM system. It also presents the position of the System within business functions of electric utilities and System structure. Furthermore, selected architecture variant was also presented, together with the selection of communication technologies and performance which can be achieved through the proposed solution. Advantage of using the modular approach was emphasised, enabling gradual introduction, as well as later unique System adaptation to technological and economic conditions. System Implementation Strategy in EPS was given in the end of the document. Due to relatively poor construction level of telecommunication infrastructure on low voltage and medium voltage network in electric utilities of EPS, as well as incomplete standardisation processes in EU and accelerated technological development, periodical alignment of functional requirements and technical specifications with new technical solution should be done, when necessary or at least once a year. ANNEX 1 ANNEX 2 ANNEX 3 ANNEX 4 AMI Overview of Basic Data and Commands Calculation of Data Amount Applied Standards Literatures Modification of Functional Requirements made by Expert Team under the order no. 950/2 12 dated Mirko Đurić, M.Sc., JP EPS, chairman 2. Saša Marčeta, Elektrovojvodina d.o.o., Novi Sad 3. Vojislav Stevanović, Elektrosrbija, d.о.о, Kraljevo 4. Saša Tošić, CE Jugoistok, Niš 5. Srđan Milošević, M.Sc, Elektrodistribucija Beograd, Belgrade 6. Boris Holik, Elektrovojvodina d.o.o., Novi Sad 7. Zoran Radonjić, Centar d.о.о. Kragujevac Page 28

29 8. Vladimir Obradović, JPEPS 9. Marijana Sučević Tasić, JP EPS ANNEX 1 AMI Overview of Basic Data and Commands АММ Centre entry into concetrator and commands to concentrator entry into concentrator time entry broadcast of time to meters broadcast of tariff mode broadcast of tariff programme route (connection) parameters of concentrator route (connection) broadcast of meter update of concentrator task table concentrator configuration remote upgrade of concentrator firmware mandatory transfer on request group of mandatory data for meters data for meters based on task tables concentrator time during reporting concentrator statuses concentrator task table concentrator configuration route (connection) of concentrator archived data reading from concentrator Data concentrator entry into meters and commands to meters entry into meter time entry tarif mode entry tariff programme entry switch connection/disconnection route adjustment (connection parameters) adjusment of meter parameters update of task table message to buyer via HAN remote upgrade of meter firmware mandatory transfer on request programmable daily values of accounting registers monthly values of accounting registers event log (integrates meter statuses) time and current tariff during reporting meter statuses, voltages, current, power register values: daily, monthly, current event log time and current tariff during reporting tariff, tariff mode, tariff programme meter parameters switch status task table route (connection) archive data 24 hour values of registers+tariff+status meter parameters switch status reading from meter Electricity meter Page 29

30 ANNEX 2 Calculation of Data Amount Value of basic data Minimum daily reading cycle Optimum daily reading cycle Maximum daily reading cycle Basic Data Values Type and value of data according to DLMS meter without peak power calculation Type of meter meter with peak power calculation meter in SS One daily value of registers with meter statuses 1 kb 1 kb 1 kb Electricity quality log (5 events/day) 2 kb 2 kb 2 kb Event log (5 events/day) 2 kb 2 kb 2 kb Load profile for one day 13 kb 13 kb 13 kb All hourly values of registers with meter statuses 24 kb 24 kb 24 kb One daily value of registers with meter statuses Electricity quality log (5 events/day) Event log (5 events/day) Load profile for one day All hourly values of registers with meter statuses Data amount yes yes yes no no 5 kb yes yes yes yes no 18 kb yes yes yes yes yes 42 kb One daily value of registers with meter statuses Electricity quality log (5 events/day) Event log (5 events/day) Load profile for one day All hourly values of registers with meter statuses Data amount yes yes yes no no 5 kb yes yes yes yes yes 42 kb yes yes yes yes yes 42 kb One daily value of registers with meter statuses Electricity quality log (5 events/day) Event log (5 events/day) Load profile for one day All hourly values of registers with meter statuses Data amount yes yes yes yes yes 42 kb yes yes yes yes yes 42 kb yes yes yes yes yes 42 kb Data amount according to types of reading Types of meters meter without peak power calculation meter with peak power calculation meter in SS Total for ED Novi Sad Number of meters in ED Novi Sad according to types of data Daily amount of data Annual amount of data Minimum daily reading cycle 1.35 GB GB GB GB Optimum daily reading cycle 1.35 GB GB GB 1.56 GB Maximum daily reading cycle GB GB GB GB Minimum annual reading cycle GB GB GB GB Optimum annual reading cycle GB GB GB GB Maximum annual reading cycle GB GB GB GB Page 30

31 ANNEX 3 Applied Standards The following standards were used in the course of development of this document: IEC IEC IEC IEC IEC IEC IEC IEC IEC IEC 62051:1999 IEC IEC IEC IEC IEC IEC Degrees of protection provided by enclosures (IP Code) International Electrotechnical Vocabulary Electrical and electronic measurements and measuring instruments Part 311: General terms relating to measurements Part 312: General terms relating to electrical measurements Part 313: Types of electrical measuring instruments Part 314: Specific terms according to the type of instrument 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 Application integration at electric utilities System interfaces for distribution management Part 2: Glossary Application integration at electric utilities System interfaces for distribution management Part 3: Interface for network operations Application integration at electric utilities System interfaces for distribution management Part 9: Interface for meter reading and control Application integration at electric utilities System interfaces for distribution management Part 11: Common Information Model (CIM) Extensions for Distribution 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 Part 1: Terms related to data exchange with metering equipment using DLMS/COSEM Electricity metering equipment (AC) General requirements, tests and test conditions Part 11: Metering equipment. Electricity metering equipment (a.c.) Particular requirements Part 31: Pulse output devices for electromechanical and electronic meters (two wires only). Electricity metering equipment (a.c.) Particular requirements Static meters for active energy (classes 1 and 2) Electricity metering equipment (a.c.) Particular requirements Static meters for active energy (classes 0.2S and 0.5S) Electricity metering equipment (AC) Particular requirements Part 52: Symbols. Page 31

32 IEC IEC IEC IEC IEC IEC IEC IEC IEC IEC EN DIN EN EN EN VDN MID 2004/22/EC Electricity metering (a.c.) Tariff and load control Part 11: Particular requirements for electronic ripple control receivers. Electricity metering (a.c.) Tariff and load control Part 21: Particular requirements for time switches. Electricity metering Payment systems Part 31: Particular requirements Static payment meters for active energy (classes 1 and 2) Electricity metering Data exchange for meter reading, tariff and load control Part 21: Direct local data exchange. Electricity metering Data exchange for meter reading, tariff and load control Part 42: Physical layer services and procedures for connection oriented asynchronous data exchange. Electricity metering Data exchange for meter reading, tariff and load control Part 46: Data link layer using HDLC protocol. Electricity metering Data exchange for meter reading, tariff and load control Part 47: COSEM transport layers for IPv4 networks. Electricity metering Data exchange for meter reading, tariff and load control Part 53: COSEM application layer. Electricity metering Data exchange for meter reading, tariff and load control Part 61: Object identification system (OBIS). Electricity metering Data exchange for meter reading, tariff and load control Part 62: Interface classes. EN Communication systems for remote reading of meters. Physical and link layer. Watt hour meters in molded insulation case without instrument transformers, up to 60 A rated maximum current; principal dimensions for three phase meters CENELEC EN Signaling 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 Electricity metering equipment (a.c) General requirements, tests and test conditions Metering equipment (class indexes A, B, C) EN Electricity metering equipment (a.c) Particular requirements, Static meters for active energy (class indexes A, B, C) Technical recommendations of German`s associations Power distribution companies Directive 2004/22/EC of the European Parliament and of the Council of 31 March 2004 on measuring instruments Page 32

33 ANNEX 4 Literature 1. Documents of the organization OPEN Meter project (*): Report on the identification and specification of functional, technical, economical and general requirements of advanced multi metering infrastructure, including security requirements, July Report on regulatory requirements, July Description of current state of the art of technology and protocols (deliverable overview), June Assessment of potentially adequate telecommunications technologies general requirements and assessment of technologies, September Identification of research needs from bottom up approach knowledge gaps, June Companion Note, October PRIME project Technology Whitepaper, PHY, MAC and Convergence layers, v1.0, July DLMS/COSEM DLMS Green Book, COSEM Architecture and Protocols, Fifth Edition DLMS Blue Book, COSEM Identification System and Interface Classes, Edition NTA 8130:2007 nl, Minimum set of functions for metering of electricity, gas and thermal energy for domestic customers. 5. Papers from the conference: Metering&Billing/CRM Europe, held in the period from to 2012 in Amsterdam, Barcelona and Vienna. (*) Competent EC authority Directorate General Enterprise and Industry has on March 12, 2009 issued a Directive M441 EN, by which it puts the following institutions CEN, CENELEC and ETSI in charge for the development of open AMI architecture, including communication protocols, for metering devices for electricity, heat, gas and water for the purpose of achieving interoperability. The above institutions have also included the organization called OPEN (Open Public Extended Network) Meter Project into the standardization process. Page 33

34 FUNCTIONAL REQUIREMENTS AND TECHNICAL SPECIFICATIONS OF AMI SYSTEM Page 34

35 FUNCTIONAL REQUIREMENTS FOR AMM CENTRE 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 to 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. In case of data transmission outside of the IT or telecommunications network of a subsidiary, data encryption is mandatory. Data export into files option is mandatory (min. ASCII and EXCEL type files). More detailed file formats would be additionally determined based on the needs of electric utility. Functions of AMM Centre in terms of data reading and configuration should be executed on laptops connected directly to the concentrator or the meter. In addition to this, functions related to meter data reading and configuration should also be executed on handhelds. Page 35

36 GPRS GPRS PLC via LV line Figure 1 Block diagram of AMM Centre position within the System Page 36

37 1. 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 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 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. 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. 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. 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 generates 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. Page 37

38 Administration of System components enables: Meter administration. Administration of communication devices. Concentrator administration. Monitoring of System components replacement history. Monitoring of command and parameter history of System components 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). 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. 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. Page 38

39 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) 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. 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. Change of concentrator management software. Review of corresponding concentrator records on the change of parameters and concentrator adjustment Administration of Communication GPRS Modems Administration of communication GRPS modems enables the change of communication parameters 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. Page 39

40 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. 2.2 AMM CENTRE DATA COLLECTION/READING AND MEMORISING FUNCTIONS Data collection/reading and memorizing function collects data automatically in an efficient and reliable manner from the concentrator/meter and memorizes (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 programs/sequences. According to the amount of concentrator/meters being read we differentiate: Reading of individual concentrator/meter. Reading of the group of concentrators/meters According to the reading frequency we differentiate: Automated reading according to the sequence Reading on request o Periodical reading on request o 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. Page 40

41 Data collected from the meter on request (via 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. 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 concentrator (in addition to data obtained by meter reading) include: Statistics of communication. Emergency and regular reports. 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/concentrators in every reading. Page 41

42 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. 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 parameterization 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. Page 42

43 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. If the data is transferred outside of own computer or telecommunications network of a subsidiary, encryption of the transferred data shall be mandatory 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 60 minute data in the end of the daily accounting interval. 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. Page 43

44 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 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. Page 44

45 TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR LOW VOLTAGE CONCENTRATOR Page 45

46 0. 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) SUPPLY: AC: 1х230V or 3х230V, 50Hz, Optional, DC: 24V MOUNTING: Vertical (Wall mounted)) OPERATION TEMPERATURE RANGE: from 20 C to +55 C MAXIMUM OPERATION HUMIDITY: 90% ANTICIPATED OPERATION LIFE: 10 years MAXIMUM HOUSING DIMENSIONS (WхLхH): 400х400х200 (mm) NUMBER OF SUPPORTED METERS (CAPACITY): 1000 meters STORAGE CAPACITY: Capacity: minimum 4 GB COMMUNICATION PORTS (MINIMUM): 1хLAN 10/100, RJ45. COMMUNICATION PORTS FOR COMMUNICATION WITH GPRS or PLC modem depending on GPRS or PLC modem performance): If GPRS modem is executed as external device, corresponding communication port for communication with GPRS modem; If PLC modem is executed as external device, corresponding communication port for communication with PLC modems. COMMUNICATION PORTS (Optional) depending on communication module): 1хUSB (minimum 2.0) 1хRS 232 (Isolated) 1хRS 485 (Isolated) OTHER PORTS (Optional): 1xD Sub (DB15) VGA HARDWARE MONITORING: Watchdog timer, optional CPU and housing temperature monitoring REAL TIME CLOCK PROTECTION AGAINST DUST AND WATER: IP 51 or better OPERATING SYSTEM: Embedded OS (ex: WindowsXP Embedded, Windows CE, Windows Mobile, Linux...) Page 46

47 1. 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 programs/sequences submitted to it remotely (from AMM Centre) or locally (via laptop) independently from AMM Centre and to memories read data obtained through execution of defined programs/sequences for a specified time period. The concentrator follows priorities of programs/sequences during execution of such programs/sequences. At the request of AMM Centre or under reporting program/sequence, the concentrator needs to submit memorized 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 GPRS modem Meters with PLC modem Management Centre Block diagram of concentrator communication ports 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, parameterization 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 Page 47

48 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. Optimization methods include: Data compression Communication channels engagement time reduction Response time optimization 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 realize at least the following functions: Reading and memorizing functions Management/parameterization functions Communication functions Data processing functions Data and access protection functions Administration functions Reading and memorizing (archiving) functions One of the basic functions of the concentrator is reading of meters located in its communication network. Reading function is realized through the reading program/sequence. We differentiate: According to the purpose of read meters: Meters for total metering at the substation Public lighting meters Control meters Customer meters Households Page 48

49 Customer meters Contractual customers 1. According to the type of read meters: Single phase Three phase Direct metering groups. Semi indirect metering groups. 2. According to the amount of read meters: Reading of individual meter Reading of the group of meters 3. 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) Tariff programme Integration period for 15 minute maximum power Page 49

50 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 realized to enable all reading combinations (through corresponding reading programs/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 Proposal for Automated Reading according to Sequence Programmes/sequences related to this type of reading are divided into: Daily Weekly Monthly Initial daily reading program/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: 1. Real time clock reading from all meters. Page 50

51 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 program/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 program interruption. Otherwise, daily reading program/sequence is executed. Readings on request have priority over automated programs/sequences of reading Management/Parameterisation Function Concentrator should have management/parameterization function in charge for the change of meter parameters, bistabile switch control as well as meter software change. This Function is realized through the program/sequence of management/parameterization. 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/parameterized meters: Single phase Three phase Direct metering groups. Semi indirect metering groups. 3. According to the amount of managed/parameterized meters: Management/parameterization of individual meter Management/parameterization of the group of meters According to frequency, function may be divided in: Management/parameterization according to sequence Management/parameterization on request The list of parameters: Real time clock synchronisation. Page 51

52 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. 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 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 GRPS communication Communication with Meters Concentrator is equipped with corresponding PLC modem enabling communication between the concentrator and the meter. 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. Page 52

53 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 Communication with AMM Centre Concentrator is equipped with the corresponding GPRS modem (it also has GSM functionality, due to possible implementation of the system with dynamic addressing of GRPS modem) enabling bidirectional communication of the concentrator and AMM Centre. GRPS modem meets technical characteristics from Technical Requirements for GPRS 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 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.). 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. Page 53

54 The concentrator also automatically informs AMM Centre on the detection of new meters in the subordinate substation region 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 Administration function Administration function may be done locally or remotely. It minimally has to provide: Review and synchronization of reading programs/sequences with AMM Centre or a laptop. Review and synchronization of management/parameterization programs/sequences with AMM Centre or local laptop. Review and change of programs/sequences execution priorities. Real time clock synchronization. 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. 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. Page 54

55 TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR GPRS MODEM Page 55

56 1 BASIC CHARACTERISTICS OF GPRS MODEM 1.1 GPRS MOBILE STATION CLASS: minimum B. 1.2 GPRS MULTI SLOT CLASS: minimum Dual Band GSM/GPRS: 900/1800 MHz 1.4 OPERATING TEMPERATURE RANGE: from 25 C to +55 C. 1.5 EXTERNAL ANTENNA CONNECTION: YES (ex. SMA). 1.6 SIM CARD HOLDER POSITION: From external side of modem. 2. REQUIREMENTS FOR GPRS MODEM 2.1 GENERAL REQUIREMENTS FOR GPRS MODEM GPRS modem mandatory has GSM functionality, due to possible system implementation with dynamic addressing of GPRS modem. GPRS modem starts communication between the concentrator/meter to which it is connected as external communication module, and AMM Centre. GPRS 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. GRPS 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.) GRPS 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. It is desirable for GPRS modem to take over automatically the serial number of the meter, and to sign in to the system with the same number. Every GPRS modem is equipped with the watchdog function in charge to execute hardware reset of GPRS 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. 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 GPRS modem. The function of reading and change of configuration of GPRS 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. Page 56

57 2.1.1 ADDITIONAL REQUIREMENTS OF GRPS MODEM FOR METERS Size and connectors of GPRS 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 covers or below a special cover, but not below the metering part cover (replacement of communication module is performed without state seal disruption). GPRS modem should not be in any mechanical or physical connection with the cover of terminal. GRPS modem is connected according to PLUG IN principle (connector to connector) with no wire connections. GPRS modem supply is realized in the meter or within GPRS 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 GPRS modem, modem supply is single phase or three phase, by which meter consumption and connected GPRS communication module does not exceed maximal allowed consumption of the meter. Due to unification, it is desirable for one type of GRPS modem to operate on all specified types of meters. GRPS modem in communication with the meter and AMM Centre uses communication protocol defined according to DLMS/COSEM specification ADDITIONAL REQUIREMENTS FOR GPRS MODEM FOR THE CONCENTRATOR GPRS 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. GPRS 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 GRPS modem. Page 57

58 TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR PLC MODEM Page 58

59 BASIC CHARACTERISTICS OF S FSK PLC MODEM 1. GENERAL REQUIREMENTS FOR S FSK PLC COMMUNICATION S FKS PLC communication needs to fulfill the following requirements: 1. PLC communication should be in accordance with standards: SRPS EN , SRPS EN , SRPS EN CIASE and standard SRPS CENELEC EN PLC communication on application level should be according to DLMS/COSEM specification. 3. PLC technology needs to support addressing on physical level (MAC) for at least 1,000 meters connected to one concentrator. 4. PLC communication must support unicast, multicast and broadcast communication modes. Unicast is a default mode for normal communication, multicast is used for message sending to the groups of meters, while broadcast may be used for meter firmware update, automatic meter detection, etc. 5. Automatic modem (meter) detection has to be supported. It goes without saying that no information should be provided to the concentrator, so that it can execute meter detection procedure PLC technology has to support repeater operation. Every communication module on meters has to operate as a repeater without any additional device. Mechanism of repetition and finding optimal communication path needs to be automated. 7. Adaptation to topology changes has to be supported. Electric power and communication network are not static, therefore the protocol or the system have to provide routing function adapted to network changes. 8. Listening to PLC signals from other concentrators should not disable communication. Page 59

60 1.1 ILLUSTRATION OF MUTUAL RELATION OF (S FSK PLC) COMMUNICATION STANDARDS Page 60

61 2. 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.) GRPS 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 SPECIAL REQUIREMENTS OF PLC MODEM FOR THE CONCENTRATOR PLC modem for the concentrator 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. PLC modem may also be internal (i.e. located inside the concentrator) and of such manufacture enabling its replacement without the change of the concentrator itself 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. The manner of executing PLC modem (external or integrated) depends on the request of electricity distributor. Page 61

62 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 covers 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 no wire connections. External PLC modem must not be in any mechanical or physical connection with terminal cover. External PLC modem for meters uses 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 take over the serial number of the meter, and to sign in to the system with the same number 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. Page 62

63 FUNCTIONAL REQUIREMENTS FOR SWITCHING MODULE (BISTABLE SWITCH) Page 63

64 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. The manner of execution of switching module (integrated or external) depends on the request of electricity distributor 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 are met. 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 UC3, where maximum switching current is equal to the maximum meter current or higher. Switching module needs to perform at least position changes without the need for any maintenance. Meter manufacturer shall submit corresponding document (attests) proving that it has met indicated standards for the switching module. Disconnection is always performed in all phases simultaneously. Neutral phase is never disconnected. 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 (dimension h 4 ) and item (terminal) of technical specifications of meter are met. 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 UC3 where maximum switching current is equal to the maximum meter current or higher. Switching module needs to perform at least position changes without the need for any maintenance. Disconnection is always performed in all phases simultaneously. Neutral phase is never disconnected. Interface on the switching module for connection with the meter is wired M BUS interface in accordance with standards EN and EN , and it is realized to enable connection with gas meters and water meters, even when the switching module is connected to the meter. Page 64

65 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 is options for meter management remote disconnection/connection of customer and limitation of maximum permitted power. Page 65

66 TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR SINGLE PHASE METERS Page 66

67 1. TECHNICAL CHARACTERISTICS OF METERS FOR DIRECT CONNECTION (SINGLE PHASE METER) 1.1.GENERAL TECHNICAL CHARACTERISTICS OPERATION MODE CONSTRUCTION: Meter shall be electronic (static) for singlephase two wire direct connection RATED (REFERENCE) VOLTAGE: 230 V ( 20%, +15%) RATED CURRENT: 5 ( 60) А RATED FREQUENCY: 50 Hz 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 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 standard) MINIMUM ACCURACY CLASS: For active energy and power SRPS EN standard 2 EN standard A ANTICIPATED OPERATION LIFE: minimum 15 years SIZE (HOUSING, TERMINAL AND COVERS): Dimensions (main measures) have to be done according to Figure 1. All measures are given in mm. b1 b2 C h1 h2 h3 h4 105± Page 67

68 Figure 1 Meter draft of principle Dimension h4 has to fulfil 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 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 Auxiliary and control terminals are executed under the PLUG IN principle or through corresponding clamps. Terminal is executed, in such a way, to fully eliminate the possibility of winding sliding (maximum moment of re screwing the screws defined by the manufacturer), screw fallout from sockets and simultaneously providing easy re screwing of screws and safe opening of clamps in accordance with the opening size for conductor introduction into the terminal, regardless of meter position. 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.) 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. Page 68

69 LC display operates in automatic, manual and self check 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), which is programmable. Under automatic regime, values of metered and registered values are shown cyclically. Individual value display period should be programmable and between 5 to 20 sec. Values presented on LC display, their sequence and number shall be changeable (programmable). Initially, only accounting elements and current date and time are cyclically changed in the period of 5 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.). Values displayed in the standard data menu, their sequence and number shall be changeable (programmable) and independent from the setting for automatic display regime. Self check display regime is realised to visually verify the accuracy of symbol and character display on it (verification of proper operation of all LC display elements), as well as basic meter functions. Self check function is described in more detail under point 2.6. 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 8 (eight) digits, while at least 2 (two) digits are used for display of decimal digits, and the remaining for whole digits. 5 (five) to 7 (seven) 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 (OBIS). Figures for value display shall at least be: For metered values 7 mm For characteristic codes 5 mm In case of wrong energy flow direction detection, phase presence display symbol shall blink with the frequency of about 1 Hz. Page 69

70 In case of detection of metering integrity violation (terminal cover opening, meter housing opening, parameter change, strong magnetic field impact on the meter, etc.) it is desirable that the signalling for violation is performed via display with all elements blinking, until status registry is reset. General appearance of the display with the display sequence is as shown on Figure 2 and together with the scrolling function is in accordance with VDN recommendations, by which the position of the elements is not critical. Phase display Area of metered values Unit display L Area of characteristic codes Cursor field Figure 2 Principal general appearance of display Access to accounting elements for previous months is realised in a very simple manner (e.g. by pressing the key for 2 sec), grouping the values according to accounting period, chronologically, starting from the last accounting period towards previous ones 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 Number Of Tariffs Meter has the possibility of storing metered values in 4 (four) tariff registers Impulse (Test) Terminals Meter has at least two impulse terminals. One shall be optical (via red LE diode), the other electrical, with galvanic insulation, passive and executed on a corresponding terminal connection. Page 70

71 Characteristics of Impulse Terminals Characteristics of impulse terminals of the meter are realised according to the standard SRPS EN i.e. SRPS EN Meter Constant Meter constant is expressed by the number of impulses per energy unit (imp/kwh), amounting to: Electrical 500 imp/kwh Optical 1000 imp/kwh 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 OTHER TECHNICAL CHARACTERISTICS 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 standard. Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN 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. 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, consumption management terminals, tariff control, etc.). This space shall be anticipated either under the terminal covers 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 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 Electromagnetic Compatibility and Resistance to Other Impacts Meter shall meet norms required by regulations from this field under SRPS EN and SRPS EN standards, i.e. EN and EN (for meters according to MID directive). Page 71

72 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 standard, i.e. EN (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 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 that 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 Sealing Meter is constructed to provide a corresponding protection level against dust and humidity penetration. According to SRPS IEC meters are manufactured to provide the protection level of at least IP METER FUNCTIONS 2.1. METERING, REGISTRATION AND DISPLAY FUNCTIONS Page 72

73 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 (OBIS)). Presentation of these values on the display is programmable, as already described under point 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 (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 INSTANEOUS ACTIVE POWER The meter measures and displays on request current active power on LC display LOAD 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 6 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: load profile and profile of daily values of register. Optionally, meter records the profiles of hourly measures and metering values LOAD PROFILE Meter records and registers the load profile (mean active power value). 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 memorising of at least 4320 power metering records 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. In addition to hourly values of registers, meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of hourly register values with the corresponding block of registers. 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 PROFILE OF DAILY REGISTER VALUES Page 73

74 Meter records and registers the values of all accounting registers at the pre set time. Initially this is at 00 hrs, but this parameter is programmable. In addition to daily register values, the meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of daily register values with the corresponding block of registers. Memory for the storage of profiles of daily values of meter registers and statuses has the capacity of at least 7 records, under FIFO principle PROFILE OF METERING VALUES This profile is initially used for recording and registering of the voltage value at the meter inlet. Corresponding time stamp is recorded in the profile of metering values with the corresponding block of registers. Total memory capacity for saving of profiles of metering values shall enable memorising of at least 500 sets of metering values. This profile may be used for recording and registering of other metering values (e.g. values of current through the meter) 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 VOLTAGE METERING Meter measures and displays effective voltage value on request CURRENT METERING Meter measures and displays effective current value on request PHASE PRESENCE Meter displays phase voltage presence on the connected conductors. Phase display function provides information on certain phase presence. As a rule, voltage drop below the value of 50% of rated voltage is valued as the absence of corresponding phase voltage. This value is programmable, and it is initially 50% TIME AND DATE Meter displays time and date from internal switching clock. Page 74

75 2.1.9 INTERNAL CLOCK Accuracy and other features of internal clock shall be realised in accordance with SRPS EN and SRPS EN 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 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. 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 (under self check regime of meter operation). 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 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 CURRENT TARIFF Meter shall have continuous display of current active tariff register, regardless of its display mode 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 five different days within the season and two different days for holidays. Tariffs may be changed during one day for at least eight times EXTERNAL TARIFF REGISTER MANAGEMENT Page 75

76 External tariff register management is executed by means of two clamps for control voltage 230 V connection and it has priority over local tariff register management 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. It is desirable that meters memorise accounting registers state during each metering integrity violation. For each of the indicated events, Event Log shall make a record with a time stamp when this event occurred 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 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). Event Log shall record each data change occurring on the meter COUNTDOWN Meter shall have the reduction blockade of achieved individual register values 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. Page 76

77 2.2 ADDITIONAL FUNCTIONS 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. Block diagram of meter interfaces. Meter shall have the following interfaces: Type Type Physical characteristics of interface Communication protocol Optical interface: IR port SRPS EN DLMS/COSEM Electrical interface 1 RS 485 RS 485 DLMS/COSEM *Optionally (subject to additional request of electricity distributor) Electrical interface 2 M BUS EN EN RS 232 RS 232 EN Electrical interface 3 or Ethernet RJ 45 Ethernet TCP/IP (DHCP) *bidder can offer interfaces no.2 and 3, but he is not obliged Meter shall have DLMS/COSEM certificate issued based on the verification with the latest version of testing software (at least version 2). Page 77

78 Electrical interface is galvanically insulated from the metering part of the meter. Communication part of the meter is executed to enable simultaneous communication with the meter via all meter interfaces, without their mutual disturbance, especially 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), with no wire connections, whereas the total consumption of the meter and communication module does not exceed the requirement from point 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. Electrical interface RS 485 is two wire active and it is used for: Connection with communication module for remote reading (GRPS modem, PLC modem, etc.) Direct connection with laptop when necessary to access the meter/meter parameters directly Possible connection of several meters to the bus in cases of grouped meter installation. For the easier realisation of the connection of more meters on the bus in the event of group installation of the meters over the bicable active RS 485 interface, meter has additional connector which is realized: via separate connector on the meter (auxiliary contacts) or via separate connector on communication module for remote reading (GPRS 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. Electrical interface M BUS shall be realised upon the request of electricity distributor and it is used for: Meter connection with other metering devices (water meter, gas meter, heat meter) point 2.7. Managing switch 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 requests for switch module (bistable switch)) Electrical interface RS 232, or Ethernet, shall be realised upon the request of electricity distributor and it is used for: HAN (Home Area Network) connection of modem/module (depending on the manufacture, and upon the request of electricity distributor). Optional electric interfaces (M BUS, RS 232, Ethernet) may be realized via separate connector on the meter (auxiliary contacts) or Page 78

79 via separate connector on communication module for remote reading (GPRS 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 GPRS COMMUNICATION At the request of Employer, the meter may be equipped with GPRS communication module which is connected to the meter via specific electrical interface, whereas the requests from items (dimensions) and (housing) are fulfilled. Characteristics of GPRS communication module are given in the Chapter Technical Characteristics and functional requests for GPRS modem items 1, 2.1 and PLC COMMUNICATION At the request of Employer, the meter may be equipped with PLC communication module which may be, in accordance with the Employer s request, installed as: External PLC communication modem, which is connected to the meter via specific electrical interface. Characteristics of integrated PLC communication modem are given in the Chapter Technical Characteristics and functional requests for GPRS modem, items 1, 2 and 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 In that case, electrical interface number 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. In accordance with the Employer s request, 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 requests 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 requests for switching module (bistable switch). If distributor chooses 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. Page 79

80 In addition to this, meter has minimally one control output (independent relay) for management of individual devices in customer installation (consumption management function). In the course of meter parameterization it should be possible to define the category (group) to which the meter belongs, in terms of consumption management function realization 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: CONDITIONAL SWITCH RECLOSING After receiving instructions for reconnection/expiry of penalty time, it is necessary to confirm switch reclosing locally via key/keys. The display shows a corresponding notification that the condition necessary for connection has been achieved, and that key confirmation is expected AUTOMATIC SWITCH RECLOSING After receiving instructions for reconnection/expiry of penalty time, the switch is automatically reconnected REMOTE CONSUMPTION MANAGEMENT Meter has at least one control output (independent relay) for management of individual devices at the customer installation (usually thermal ones). 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 remotely (AMM Centre command), with possible automatic activation in accordance with the current tariff programme done via programming 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, the meter (for ex. via display) gives a signal that the limit has been exceeded and that the customer will be disconnected from the network if during the permitted overload time it does not reduce its consumption. This signalling is Page 80

81 possible on an additional display located at the customer s house/flat (if communication with additional display is achieved HAN). After expiry of permitted overload time, switching module for customer disconnection/connection is activated, and meter display/additional display shows that disconnection was done due to limit exceedence as well as information about the time until the expiry of the penalty period (if this parameter is active in the meter). After the expiry of penalty time reconnection is done in accordance with active switch operation regime (conditional or automatic switch reconnection). 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 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 MAXIMUM AND MINIMUM VOLTAGE Meter measures and registers maximum and minimum voltage value on the monthly level MAXIMUM CURRENT Meter measures and registers maximum current value on the monthly level 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 100 entries. Under voltage and overvoltage thresholds may be adjusted. Initially: under voltage = 20% Un, overvoltage = +15% Un SUPPLY INTERRUPTION REGISTRATION Meter registers supply interruptions in accordance with SRPS ЕN 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 Page 81

82 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. 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). If this parameter is 0, this means that meter will directly after new firmware upgrade start its execution. 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 LOCAL FIRMWARE UPGRADE Meter is connected via its local electrical interface with the manual terminal or laptop containing corresponding software for installation of the new firmware on the meter. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, there is a procedure to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner REMOTE FIRMWARE UPGRADE Meter is connected via its local external communication module with AMM Centre containing the corresponding software module for installation of the new firmware on the meter. Alternatively, AMM Centre role may be taken over by concentrators (if they exist within the system), but after AMM Centre instruction. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, there is a procedure to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner. Also, this type of action shall be recorded permanently within AMM Centre. 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). In addition to this, self check is mandatory during every firmware upgrade. Self check is also executed upon the request of authorised person, at the point of delivery itself via handheld devices. Page 82

83 Self check verifies the following: Memory integrity of the meter Meter statuses and alarms Meter display Battery status In addition to these, the following checks may be performed: connection check towards external communication module, voltage presence, etc. Self check results are entered into the Event Log. 2.7 MULTI UTILITY METERING Meter possesses an electrical interface (M Bus) 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 three access levels and transferred data encryption. 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 firmware, change of meter parameters, as well as local connection/disconnection of switching module. These actions over meter are enabled after removal of terminal cover (violation of distribution company seal) but only after verification of user type of software package installed on the handheld device/laptop, as well as meter password. Each change of parameters/firmware 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. VII TECHNICAL CHARACTERISTICS OF SUBJECT OF PROCUREMENT FOR LOT TECHNICAL CHARACTERISTICS OF SUBJECT OF PROCUREMENT FOR LOT 2 1. TECHNICAL CHARACTERISTICS OF METERS FOR DIRECT CONNECTION (THREE PHASE METER) Page 83

84 1.1.GENERAL TECHNICAL CHARACTERISTICS OPERATION MODE CONSTRUCTION: Meter shall be electronic (static) for threephase four wire direct connection with three measurement systems RATED (REFERENCE) VOLTAGE: 3 x 230/400 ( 20%, +15%) V RATED CURRENT: 5 ( 60) А RATED FREQUENCY: 50 Hz 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 3 W and 15 VA (SRPS EN 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 standard) MINIMUM ACCURACY CLASS: For active energy and power SRPS EN standard 2 EN standard A ANTICIPATED OPERATION LIFE: minimum 15 years SIZE (HOUSING, TERMINAL AND COVERS): Dimensions (main measures) have to be done according to Figure 1. All measures are given in mm. b1 b2 C h1 h2 h3 h4 150± Page 84

85 Figure 1 Meter draft of principle Dimension h4 has to fulfil 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 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 Auxiliary and control terminals are executed under the PLUG IN principle or through corresponding clamps. Terminal is executed, in such a way, to fully eliminate the possibility of winding sliding (maximum moment of re screwing the screws defined by the manufacturer), screw fallout from sockets and simultaneously providing easy re screwing of screws and safe opening of clamps in accordance with the opening size for conductor introduction into the terminal, regardless of meter position. 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.) 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. Page 85

86 LC display operates in automatic, manual and self check 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), which is programmable. Under automatic regime, values of metered and registered values are shown cyclically. Individual value display period should be programmable and between 5 to 20 sec. Values presented on LC display, their sequence and number shall be changeable (programmable). Initially, only accounting elements and current date and time are cyclically changed in the period of 5 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.). Values displayed in the standard data menu, their sequence and number shall be changeable (programmable) and independent from the setting for automatic display regime. Self check display regime is realised to visually verify the accuracy of symbol and character display on it (verification of proper operation of all LC display elements), as well as basic meter functions. Self check function is described in more detail under point 2.6. 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 8 (eight) digits, while at least 2 (two) digits are used for display of decimal digits, and the remaining for whole digits. 5 (five) to 7 (seven) 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 (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. In case of wrong energy flow direction detection, phase presence display symbol shall blink with the frequency of about 1 Hz. In case of detection of phase and neutral conductor crossing (point 1.2.2), all symbols showing the phase presence shall blink with the frequency of about 1 Hz. In case of detection of metering integrity violation (terminal cover opening, meter housing opening, parameter change, strong magnetic field impact on the meter, etc.) it is desirable that the signalling for violation is performed via display with all elements blinking, until status registry is reset. General appearance of the display with the display sequence is as shown on Figure 2 and together with the scrolling function is in accordance with VDN recommendations, by which the position of the elements is not critical. Page 86

87 Phase display Area of metered values Unit display L Area of characteristic codes Cursor field Figure 2 Principal general appearance of display Access to accounting elements for previous months is realised in a very simple manner (e.g. by pressing the key for 2 sec), grouping the values according to accounting period, chronologically, starting from the last accounting period towards previous ones 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 Number Of Tariffs Meter has the possibility of storing metered values in 4 (four) tariff registers Impulse (Test) Terminals Meter has at least two impulse terminals. One shall be optical (via red LE diode), the other electrical, with galvanic insulation, passive and executed on a corresponding terminal connection Characteristics of Impulse Terminals Characteristics of impulse terminals of the meter are realised according to the standard SRPS EN i.e. SRPS EN Meter Constant Meter constant is expressed by the number of impulses per energy unit (imp/kwh), amounting to: Electrical 500 imp/kwh Page 87

88 Optical 1000 imp/kwh 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 OTHER TECHNICAL CHARACTERISTICS 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 standard. Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN 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. 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, consumption management terminals, tariff control, etc.). This space shall be anticipated either under the terminal covers 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 Irregular Connection and Neutral Conductor Disconnection IRREGULAR CONNECTION Phase conductor input output connection sequence shall not have an impact on accuracy and regular metering. 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 NEUTRAL CONDUCTOR DISCONNECTION 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 specified accuracy class DISCONNECTION OF ONE OR TWO PHASES Page 88

89 Meter shall operate properly within the rated accuracy class boundaries in case of disconnection of one or two phases Electromagnetic Compatibility and Resistance to Other Impacts Meter shall meet norms required by regulations from this field under SRPS EN and SRPS EN standards, i.e. EN and EN (for meters according to MID directive) 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 standard, i.e. EN (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 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 that 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 Page 89

90 1.2.5 SEALING Meter is constructed to provide a corresponding protection level against dust and humidity penetration. According to SRPS IEC meters are manufactured to provide the protection level of at least IP METER FUNCTIONS 3.1. METERING, REGISTRATION AND DISPLAY FUNCTIONS 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 (OBIS)). Presentation of these values on the display is programmable, as already described under point 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 (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 INSTANTEOUS ACTIVE POWER The meter measures and displays on request current active power on LC display LOAD 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 6 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: load profile and profile of daily values of register. Optionally, meter records the profiles of hourly measures and metering values LOAD PROFILE Meter records and registers the load profile (mean active power value). 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 memorising of at least 4320 power metering records 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. Page 90

91 In addition to hourly values of registers, meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of hourly register values with the corresponding block of registers. 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 PROFILE OF DAILY REGISTER VALUES Meter records and registers the values of all accounting registers at the pre set time. Initially this is at 00 hrs, but this parameter is programmable. In addition to daily register values, the meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of daily register values with the corresponding block of registers. Memory for the storage of profiles of daily values of meter registers and statuses has the capacity of at least 7 records, under FIFO principle PROFILE OF METERING VALUES This profile is initially used for recording and registering of the voltage value at the meter inlet. Corresponding time stamp is recorded in the profile of metering values with the corresponding block of registers. Total memory capacity for saving of profiles of metering values shall enable memorising of at least 500 sets of metering values. This profile may be used for recording and registering of other metering values (e.g. values of current through the meter) 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 VOLTAGE METERING Meter measures and displays effective voltage value on request CURRENT METERING Meter measures and displays effective current value on request. Page 91

92 2.1.8 PHASE PRESENCE Meter displays phase voltage presence on the connected conductors. Phase display function provides information on certain phase presence. As a rule, voltage drop below the value of 50% of rated voltage is valued as the absence of corresponding phase voltage. This value is programmable, and it is initially 50% TIME AND DATE Meter displays time and date from internal switching clock INTERNAL CLOCK Accuracy and other features of internal clock shall be realised in accordance with SRPS EN and SRPS EN 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 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. 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 (under self check regime of meter operation). 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 DAYLIGHT SAVING TIME DST Meter shall possess automatic daylight saving time function, according to the calendar of Central European Time CET CURRENT TARIFF Meter shall have continuous display of current active tariff register, regardless of its display mode. Page 92

93 2.1.14LOCAL 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 five different days within the season and two different days for holidays. Tariffs may be changed during one day for at least 8 times EXTERNAL TARIFF REGISTER MANAGEMENT External tariff register management is executed by means of two clamps for control voltage 230 V connection and it has priority over local tariff register management 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. It is desirable that meters memorise accounting registers state during each metering integrity violation. For each of the indicated events, Event Log shall make a record with a time stamp when this event occurred 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 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). Event Log shall record each data change occurring on the meter COUNTDOWN Meter shall have the reduction blockade of achieved individual register values DATA STORAGE PERIOD Page 93

94 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 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). Block diagram of meter interfaces. Meter shall have the following interfaces: Type Type Physical characteristics of interface Communication protocol Optical interface: IR port SRPS EN DLMS/COSEM Electrical interface 1 RS 485 RS 485 DLMS/COSEM Page 94

95 Optionally (subject to additional request of electricity distributor) Electrical interface 2 M BUS EN EN RS 232 RS 232 EN Electrical interface 3 or Ethernet RJ 45 Ethernet TCP/IP (DHCP) *Bidder may offer interfaces number 2 and 3, but it is not mandatory Electrical interfaces are galvanically insulated from the metering part of the meter. Communication part of the meter is executed to enable simultaneous communication with the meter via all meter interfaces, without their mutual disturbance, especially 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 are achieved under PLUG IN principle (connector to connector), with no wire connections, whereas the total consumption of the meter and communication module does not exceed the requirement from point 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. Electrical interface RS 485 is two wire active and it is used for: Connection with communication module for remote reading (GRPS modem, PLC modem, etc.) Direct connection with laptop when necessary to access the meter/meter parameters directly Possible connection of several meters to the bus in cases of grouped meter installation. For easier realization of connection of several meters to the bus in case of grouped meter installation via two wire active RS 485 interface, meter has additional connector which is realized: Via separate connector on the meter (for example, auxiliary contacts) or Via separate connector on communication module for remote reading (GPRS modem, PLC modem, and etc.) or Via corresponding module for the extension of external interfaces RS 485 function. In that case the mentioned module is mandatory delivered with the meter. Electrical interface M BUS shall be realised upon the request of electricity distributor and it is used for: Meter connection with other metering devices (water meter, gas meter, heat meter) point 2.7. 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 requests for switch module (bistable switch)) Page 95

96 Electrical interface RS 232, or Ethernet, shall be realised upon the request of electricity distributor and it is used for: HAN (Home Area Network) connection of modem/module (depending on the manufacture, and upon the request of electricity distributor). Optional electrical interfaces (M BUS, RS 232, Ethernet) may be realized Via separate connector on the meter (for example, auxiliary contacts) or Via separate connector on communication module for remote reading (GPRS 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 GPRS COMMUNICATION At the request of Employer, the meter may be equipped with GPRS communication module which is connected to the meter via specific electrical interface, whereas the requests from items (dimensions) and (housing) are fulfilled. Characteristics of GPRS communication module are given in the Chapter Technical Characteristics and functional requests for GPRS modem items 1, 2.1 and PLC COMMUNICATION At the request of Employer, the meter may be equipped with PLC communication module which may be, in accordance with the Employer s request, installed as: External PLC communication modem, which is connected to the meter via specific electrical interface. Characteristics of integrated PLC communication modem are given in the Chapter Technical Characteristics and functional requests for GPRS modem, items 1, 2 and 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 In that case, electrical interface number 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. In accordance with the Employer s request, 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 requests 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 requests for switching module (bistable switch). Page 96

97 If distributor chooses meter with external switching module, meter functions are not conditioned by connection of external switching module. Exceptions are only the options of consumption management remote disconnection/connection of customers and limiting of permitted maximum power. In addition to this, meter has minimally one control output (independent relay) for management of individual devices in customer installation (consumption management function). In the course of meter parameterization it should be possible to define the category (group) to which the meter belongs, in terms of consumption management function realization 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: 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 AUTOMATIC SWITCH RECLOSING After receiving instructions for reconnection/expiry of penalty time, the switch is automatically reconnected REMOTE CONSUMPTION MANAGEMENT Meter has at least one control output (independent relay) for management of individual devices at the customer installation (usually thermal ones). 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 remotely (AMM Centre command), with possible automatic activation in accordance with the current tariff programme done via programming 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. Page 97

98 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, the meter (for ex. via display) gives a signal that the limit has been exceeded and that the customer will be disconnected from the network if during the permitted overload time it does not reduce its consumption. This signalling is possible on an additional display located at the customer s house/flat (if communication with additional display is achieved HAN). After expiry of permitted overload time, switching module for customer disconnection/connection is activated, and meter display/additional display shows that disconnection was done due to limit exceedence as well as information about the time until the expiry of the penalty period (if this parameter is active in the meter). After the expiry of penalty time reconnection is done in accordance with active switch operation regime (conditional or automatic switch reconnection). 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 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 MAXIMUM AND MINIMUM VOLTAGE Meter measures and registers maximum and minimum voltage value on the monthly level MAXIMUM CURRENT Meter measures and registers maximum current value on the monthly level 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 100 entries. Under voltage and overvoltage thresholds may be adjusted. Initially: under voltage = 20% Un, overvoltage = +15% Un SUPPLY INTERRUPTION REGISTRATION Meter registers supply interruptions in accordance with SRPS ЕN Page 98

99 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). Regardless of meter firmware realization option, firmware upgrade 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. Procedure for firmware upgrade, local or remote, shall be performed in accordance with the applicable legal regulation. 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). If this parameter is 0, this means that meter will directly after new firmware upgrade start its execution. 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 LOCAL FIRMWARE UPGRADE Meter is connected via its local electrical interface with the manual terminal or laptop containing corresponding software for installation of the new firmware on the meter. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, there is a procedure to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner REMOTE FIRMWARE UPGRADE Meter is connected via its local external communication module with AMM Centre containing the corresponding software module for installation of the new firmware on the meter. Alternatively, AMM Centre role may be taken over by concentrators (if they exist within the system), but after AMM Centre instruction. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, there is a procedure to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner. In addition, this type of action shall be recorded permanently within AMM Centre. Page 99

100 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). In addition to this, self check is mandatory during every firmware upgrade. Self check is also executed upon the request of authorised person, at the point of delivery itself via handheld devices. Self check verifies the following: Memory integrity of the meter Meter statuses and alarms Meter display Battery status In addition to these, the following checks may be performed: connection check towards external communication module, voltage presence, etc. Self check results are entered into the Event Log. 2.7 MULTI UTILITY METERING Meter possesses an electrical interface (M Bus) 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 and transferred data encryption. 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 firmware, change of meter parameters, as well as local connection/disconnection of switching module. These actions over meter are enabled after removal of terminal cover (violation of distribution company seal) but only after verification of user type of software package installed on the handheld device/laptop, as well as meter password. Each change of parameters/firmware shall be registered in the standard Event Log with the date and time of change. Registers storing accounting data may not be changed. Page 100

101 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. Page 101

102 TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE PHASE ELECTRICITY METERS Page 102

103 TECHNICAL CHARACTERISTICS OF METERS FOR DIRECT CONNECTION (THREE PHASE ELECTRICITY METER) 1.1. GENERAL TECHNICAL CHARACTERISTICS OPERATION MODE CONSTRUCTION: Meter shall be electronic (static) for threephase four wire direct connection with three metering systems RATED (REFERENCE) VOLTAGE: 3 x 230/400 ( 20%, +15%) V RATED CURRENT: 5 ( 60) А RATED FREQUENCY: 50 Hz AUXILIARY CONSUMPTION OF THE METER: Auxiliary mean power of each meter 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 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 2.5 VA for class 2 meter, i.e. 4 VA for class 1 meter (SRPS EN standard) MINIMUM REFERENCE ACCURACY CLASS: For active energy and power According to SRPS EN standard 2 According to EN standard А ANTICIPATED OPERATION LIFE: minimum 15 years SIZE (HOUSING, TERMINAL AND COVERS): Dimensions (main measures) have to be done according to Figure 1. All measures are given in mm. b 1 b 2 C h 1 h 2 h 3 h 4 * 150± * Procuring Entity retains the right to, in accordance with its needs, also define other values for minimum dimension of h 4 Page 103

104 Figure 1: General meter draft. Dimension h 4 has to fulfil 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 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 Auxiliary and control terminals are executed under the PLUG IN principle or through corresponding clamps. Terminal is executed, in such a way, to fully eliminate the possibility of winding sliding (maximum moment of re screwing the screws defined by the manufacturer), screw fallout from sockets and simultaneously providing easy re screwing of screws and safe opening of clamps in accordance with the opening size for conductor introduction into the terminal, regardless of meter position. Each clamp screw shall have the size and corresponding travel to, at maximum moment of rescrewing the screws defined by the 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.). Page 104

105 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, manual and self check 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), which is programmable. Under automatic regime, values of metered and registered values are shown cyclically. Individual value display period should be programmable and between 5 to 20 sec. Values presented on LC display, their sequence and number shall be changeable (programmable). Initially, only accounting elements and current date and time are cyclically changed in the period of 5 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). Values displayed in the standard data menu, their sequence and number shall be changeable (programmable) and independent from the setting for automatic display regime. Self check display regime is realised to visually verify the accuracy of symbol and character display on it (verification of proper operation of all LC display elements), as well as basic meter functions. Self check function is described in more detail under point 2.6. 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 8 (eight) digits, while at least 2 (two) digits are used for display of decimal digits, and the remaining for whole digits. 5 (five) to 7 (seven) 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 (OBIS). Figures for value display shall at least be: For metered values 7 mm For characteristic codes 5 mm Relevant symbols are turned of ( are lost ) in the absence of some phase voltages. In case of wrong energy flow direction detection, phase presence display symbol shall blink with the frequency of about 1 Hz. In case of detection of phase and neutral conductor crossing (point ), all symbols showing the phase presence shall blink with the frequency of about 1 Hz. Page 105

106 In case of detection of metering integrity violation (terminal cover opening, meter housing opening, parameter change, strong magnetic field impact on the meter, etc) it is desirable that the signalling for violation is performed via display with all elements blinking, until status registry is reset. General appearance of the display is as shown on Figure 2 and together with the scrolling function is in accordance with VDN recommendations, by which the position of the elements is not critical. Phase display Area of metered values Unit display L 1 L 2 L 3 Area of characteristic codes Cursor field Figure 2: Principal general appearance of display Access to accounting elements for previous months is realised in a very simple manner (e.g. by pressing the key for 2 sec), grouping the values according to accounting period, chronologically, starting from the last accounting period towards previous ones 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 NUMBER OF TARIFFS Meter has the possibility of storing metered values in 4 (four) tariff registers IMPULSE (TEST) TERMINALS Meter has at least two impulse terminals. One shall be optical (via red LE diode), the other electrical, with galvanic insulation, passive and executed on a corresponding terminal connection CHARACTERISTICS OF IMPULSE TERMINALS Page 106

107 Characteristics of impulse terminals of the meter are realised according to the standard SRPS EN i.e. SRPS EN METER CONSTANT Meter constant is expressed by the number of impulses per energy unit (imp/kwh), amounting to: Electrical 500 imp/kwh Optical 1000 imp/kwh 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 OTHER TECHNICAL CHARACTERISTICS 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 quenching characteristics in accordance with the requirements indicated by SRPS EN standard. Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN 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. Meter for which installation of external communication module is foreseen should contain space for communication module installation in meter housing (point 2.2.1). This space shall be realised not to overlap with the space anticipated for other purposes (meter wiring, switching modules for remote disconnection/connection of the customer, consumption management terminals, tariff control, 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 the meter with installed communication and/or external switching module shall be done in accordance with dimensions from point IRREGULAR CONNECTION AND NEUTRAL CONDUCTOR DISCONNECTION IRREGULAR CONNECTION Page 107

108 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 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 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 ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS Meter shall meet norms required by regulations from this field under SRPS EN and SRPS EN standards, i.e. EN and EN (for meters under MID Directive) 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 standard i.e. EN (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 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. 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 Page 108

109 12. Communication protocol Adopted by Expert Council of JP EPS April 29, 2010, Belgrade, 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 that 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 SEALING Meter is constructed to provide a corresponding protection level against dust and humidity penetration. According to SRPS IEC meters are manufactured to provide the protection level of at least IP METER FUNCTIONS 2.1. METERING, REGISTRATION AND DISPLAY FUNCTIONS ACTIVE ENERGY The meter measures, registers and displays active energy within the rated accuracy class. Meter measures total active energy (register label 15.8.x in accordance with SRPS EN (OBIS)). Presentation of these values on the display is programmable, as already described under point MAXIMUM POWER The meter measures, registers and displays maximum mean active power under all tariffs (register label 1.6.x in accordance with SRPS EN (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 INSTANEOUS ACTIVE POWER The meter measures and displays on request current active power on LC display PROFILES OF METERED AND REGISTERED VALUES Meter shall have the possibility to record at least 2 profiles of metered or registered values. Each profile should support the recording of at least 6 selected values (channels). Sampling period inside each profile can be independently set. Change of all recording and registering parameters of metered and registered values may be done locally (via optical port) and remotely (via external communication). Initially, meter records the following profiles: load profile and profile of hourly register values. Optionally, meter records profiles of hourly register values and metered values. Page 109

110 LOAD PROFILE Meter records and registers the load profile (mean active power value). Integration period is initially 15 minutes. Corresponding time stamp is recorded in the load profile with corresponding block of registered mean active power value. Total capacity for load profile storage shall enable memorising of at least 4320 power metering records 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. In addition to hourly values of registers, meter records and registers meter statuses. Corresponding time stamp is recorded in the profile of hourly register values with the corresponding block of registered values of registers. 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 PROFILE OF DAILY REGISTER VALUES Meter records and registers the values of all accounting registers at the pre set time. Initially this is at 00 hrs, but this parameter is programmable. In addition to daily register values, the meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of daily register values with the corresponding block of registers. Memory for the storage of profiles of daily values of meter registers and statuses has the capacity of at least 7 records, under FIFO principle PROFILE OF METERING VALUES This profile is initially used for recording and registering of the voltage value at the meter inlet. Corresponding time stamp is recorded in the profile of metering values with the corresponding block of registers. Total memory capacity for saving of profiles of metering values shall enable memorising of at least 500 sets of metering values. This profile may be used for recording and registering of other metering values (e.g. values of current through the meter) 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. Page 110

111 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 VOLTAGE METERING Meter measures and displays effective voltage value on each phase on request CURRENT METERING Meter measures and displays effective current value on each phase on request PHASE PRESENCE Meter displays phase voltage presence on the connected conductors. Phase display function provides information on certain phase presence. As a rule, voltage drop below the value of 50% of rated voltage is valued as the absence of corresponding phase voltage. This value is programmable, and it is initially 50% TIME AND DATE Meter displays time and date from internal switching clock INTERNAL CLOCK Accuracy and other features of internal clocks shall be realised in accordance with SRPS EN and SRPS EN 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 of internal clock provides data storing of real time. Meter possesses real time calendar 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 displyed. 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 (under self check regime of meter operation). If irregular battery state is detected (failure, if the battery is empty or if it Page 111

112 does not exist), the function of clear display of irregular state is realized and (preferably) entered into Event Log DAYLIGHT SAVING TIME DST Meter shall possess automatic daylight saving time function, according to the calendar of Central European Time CET CURRENT TARIFF Meter shall have continuous display of current active tariff register, regardless of its display mode 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 five different days within the season and at least two different days for holidays. Tariffs may be changed during one day for at least eight times EXTERNAL TARIFF REGISTER MANAGEMENT External tariff register management is executed by means of two clamps for control voltage 230 V connection and it has priority over local tariff register management. This function shall be realized solely upon the request of electricity distributor 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. It is desirable that meters memorise accounting registers state during each metering integrity violation. For each of the indicated events, Event Log shall make a record with a time stamp when this event occurred 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 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. Page 112

113 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). Event Log shall record each data change occurring on the meter COUNTDOWN Meter shall have the reduction blockade of achieved individual tariff register values 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 ADDITIONAL FUNCTIONS 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). Block diagram of meter interfaces. P 113

114 Meter shall have the following interfaces: Type Type Physical characteristics of interface Communication protocol Optical interface: IR port SRPS EN DLMS/COSEM Electrical interface 1: RS 485 RS 485 DLMS/COSEM Optionally (subject to additional request of electricity distributor) Electrical interface 2: Electrical interface 3: M BUS EN EN RS 232 RS 232 EN Ethernet RJ 45 Ethernet TCP/IP (DHCP) or Electrical interface is galvanically insulated from the metering part of the meter. Communication part of the meter is executed to enable simultaneous communication with the meter via all meter interfaces, without their mutual disturbance, especially 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), with no wire connections, whereas the total consumption of the meter and communication module does not exceed the requirement from point 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. Electrical interface RS 485 is two wire active and it is used for: Connection with communication module for remote reading (GRPS modem, PLC modem, etc.). Direct connection with laptop when necessary to access the meter/meter parameters directly. Possible connection of several meters to the bus in cases of grouped meter installation. For the easier realisation of the connection of more meters on the bus in the event of group installation of the meters over the bicable active RS 485 interface, meter has additional connector which is realized: via separate connector on the meter (auxiliary contacts) or Page 114

115 via separate connector on communication module for remote reading (GPRS modem, PLC modem, etc.), or via appropriate module for the extension of external interfaces RS 485 function. In that case the indicated module shall always be delivered with the meter. Electrical interface M BUS shall be realised upon the request of electricity distributor and it is used for: Meter connection with other metering devices (water meter, gas meter, heat meter) point 2.7. Managing switch module for remote disconnection/connection of customers, in case that it is realized by the external switch module (point 1.2 of the Chapter Functional requests for switch module (bistable switch)) Electrical interface RS 232, or Ethernet, shall be realised upon the request of electricity distributor and it is used for: HAN (Home Area Network) connection of modem/module (depending on the manufacture, and upon the request of electricity distributor). Optional electric interfaces (M BUS, RS 232, Ethernet) may be realized via separate connector on the meter (auxiliary contacts) or via separate connector on communication module for remote reading (GPRS 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 GPRS COMMUNICATION At the request of Procuring Entity, the meter may be equipped with GPRS communication module which is connected to the meter via specific electrical interface, whereas the requests from items (dimensions) and (housing) are fulfilled. Characteristics of GPRS communication module are given in the Chapter Technical Characteristics and functional requests for GPRS modem, points 1, 2.1 and PLC COMMUNICATION At the request of Procuring Entity, the meter may be equipped with PLC communication module which may be, in accordance with the Procuring Entity s request, installed as: External PLC communication module, which is connected to the meter via specific electrical interface. Characteristics of external PLC communication module are given in the Chapter Technical Characteristics and functional requests for PLC modem, items 1, 2 and 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 In that case, electrical interface number 1 is not mandatory. Page 115

116 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. In accordance with the Procuring Entity s request, 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 requests 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 requests for switching module (bistable switch). If distributor chooses meter with external switching module, meter functions are not conditioned by connection of external switching module. Exceptions are only the options of consumption management remote disconnection/connection of customers and limiting of permitted maximum power. In addition to this, meter has minimally one control output (independent relay) for management of individual devices in customer installation (consumption management function). 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: 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 AUTOMATIC SWITCH RECLOSING After receiving instructions for reconnection/expiry of penalty time, the switch is automatically reconnected REMOTE CONSUMPTION MANAGEMENT Meter has at least one control output (independent relay) for management of individual devices at the customer installation (usually thermal ones). 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 remotely (AMM Centre command), with possible automatic activation in accordance with the current tariff programme done via programming 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 Page 116

117 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, the meter (for ex. via display) gives a signal that the limit has been exceeded and that the customer will be disconnected from the network if during the permitted overload time it does not reduce its consumption. This signalling is possible on an additional display located at the customer s house/flat (if communication with additional display is achieved HAN). After expiry of permitted overload time, switching module for customer disconnection/connection is activated, and meter display/additional display shows that disconnection was done due to limit exceedence as well as information about the time until the expiry of the penalty period (if this parameter is active in the meter). After the expiry of penalty time reconnection is done in accordance with active switch operation regime (conditional or automatic switch reconnection). 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 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 ELECTRICITY QUALITY METERING MAXIMUM AND MINIMUM VOLTAGE Meter measures and registers maximum and minimum voltage value on the monthly level MAXIMUM CURRENT Meter measures and registers maximum current value on the monthly level UNDER AND OVER VOLTAGES Page 117

118 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 100 entries. Under voltage and overvoltage thresholds may be adjusted. Initially: under voltage = 20% Un, overvoltage = +15% Un SUPPLY INTERRUPTION REGISTRATION Meter registers supply interruptions in accordance with SRPS ЕN 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 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). Regardless of meter firmware realization option, firmware upgrade 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. Procedure for firmware upgrade, local or remote, shall be performed in accordance with the applicable legal regulation. 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). If this parameter is 0, this means that meter will directly after new firmware upgrade start its execution. 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 LOCAL FIRMWARE UPGRADE Meter is connected via its local electrical interface with the manual terminal or laptop containing corresponding software for installation of the new firmware on the meter. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, it is desirable that the meter has the mechanism to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner REMOTE FIRMWARE UPGRADE Page 118

119 Meter is connected via its local external communication module with AMM Centre containing the corresponding software module for installation of the new firmware on the meter. Alternatively, AMM Centre role may be taken over by concentrators (if they exist within the system), but after AMM Centre instruction. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, it is desirable that the meter has the mechanism to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner.in addition, this type of action shall be recorded permanently within AMM Centre 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). In addition to this, self check is mandatory during every firmware upgrade. Self check is also executed upon the request of authorised person, at the point of delivery itself via handheld devices. Self check verifies the following: Memory integrity of the meter Meter statuses and alarms Meter display Battery status In addition to these, the following checks may be performed: connection check towards external communication module, voltage presence, etc. Self check results are entered into the Event Log МULTI UTILITY METERING Meter possesses an electrical interface (M Bus) 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 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 and transferred data encryption. 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. Page 119

120 The second level of protection is protection against unauthorised changes in meter firmware, change of other meter parameters, as well as local connection/disconnection of switching module. These actions over meter are enabled after removal of terminal cover (violation of distribution company seal) but only after verification of user type of software package installed on the handheld device/laptop, as well as meter password. Each change of parameters/firmware 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. Page 120

121 TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE PHASE ELECTRICITY METERS DIRECT METERING GROUP Page 121

122 1. TECHNICAL CHARACTERISTICS OF METERS FOR DIRECT CONNECTION (THREE PHASE DIRECT METERING GROUP) 1.1. GENERAL TECHNICAL CHARACTERISTICS 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 RATED (REFERENCE) VOLTAGE: 3 x 230/400 ( 20%, +15%) V RATED CURRENT: 5 ( 60) А RATED FREQUENCY: 50 Hz 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 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 standard) MINIMUM RATED ACCURACY CLASS: For active energy and power SRPS EN standard 1 EN standard B For reactive energy SRPS EN standard ANTICIPATED OPERATION LIFE: minimum 15 years SIZE (HOUSING, TERMINAL AND COVERS): Dimensions (main measures) have to be done according to Figure 1. All measures are given in mm. b 1 b 2 C h 1 h 2 h 3 h 4 * 150± * Procuring Entity retains the right to, in accordance with its needs, also define other values for minimum dimension of h 4 Page 122

123 Figure 1: General meter draft. Dimension h 4 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 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 Auxiliary and control terminals are executed under the PLUG IN principle or through corresponding clamps. Terminal is executed to fully eliminate the possibility of winding sliding (during maximum moment of re screwing the screw defined by the manufacturer), screw fallout from sockets and simultaneously providing easy re screwing of screws and safe opening of clamps in accordance with the opening size for conductor introduction into the terminal, regardless of meter position. 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.). Page 123

124 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, manual and self check 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), which is programmable. Under automatic regime, values of metered and registered values are shown cyclically. Individual value display period should be programmable and between 5 to 20 sec. Values presented on LC display, their sequence and number shall be changeable (programmable). Initially, only accounting elements and current date and time are cyclically changed in the period of minimum 5 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.). Values displayed in the standard data menu, their sequence and number shall be changeable (programmable) and independent from the setting for automatic display regime. Self check display regime is realised to visually verify the accuracy of symbol and character display on it (verification of proper operation of all LC display elements), as well as basic meter functions. Self check function is described in more detail under point 2.6. 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 8 (eight) digits, while at least 2 (two) digits are used for display of decimal digits, and the remaining for whole digits. 5 (five) to 7 (seven) 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 (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. In case of wrong energy flow direction detection, phase presence display symbol shall blink with the frequency of about 1 Hz. Page 124

125 In case of detection of phase and neutral conductor crossing (point ), all symbols showing the phase presence shall blink with the frequency of about 1 Hz. In case of detection of metering integrity violation (terminal cover opening, meter housing opening, parameter change, strong magnetic field impact on the meter, etc.) it is desirable that the signalling for violation is performed via display with all elements blinking, until status registry is reset. General appearance of the display is as shown on Figure 2 and together with the scrolling function is in accordance with VDN recommendations, by which the position of the elements is not critical. Phase display Area of metered values Unit display -P +Q L 1 L 2 L 3 +P -Q Area of characteristic codes Cursor field Figure 2: Principled general display design Access to accounting elements for previous months is realised in a very simple manner (e.g. by pressing the key for 2 sec), grouping the values according to accounting period, chronologically, starting from the last accounting period towards previous ones 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. Page 125

126 NUMBER OF TARIFFS Meter has the possibility of storing metered values in 4 (four) tariff registers IMPULSE (TEST) TERMINALS Meter has at least two impulse terminals. One shall be optical (via red LE diode), the other electrical, with galvanic insulation, passive and executed on a corresponding terminal connection CHARACTERISTICS OF IMPULSE TERMINALS Characteristics of impulse terminals of the meter are realised according to the standard SRPS EN i.e. SRPS EN METER CONSTANT Meter constant is expressed by the number of impulses per energy unit (imp/kwh or kvarh), amounting to: Electrical 500 imp/kwh (imp/kvarh) Optical 1000 imp/kwh (imp/kvarh) 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 OTHER TECHNICAL CHARACTERISTICS METER HOUSING MATERIALS, SHAPES 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 quenching characteristics in accordance with the requirements indicated by SRPS EN standard. Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN 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. 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, consumption management terminals, tariff control, 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 Page 126

127 IRREGULAR CONNECTION AND NEUTRAL CONDUCTOR DISCONNECTION 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 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 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 ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS Meter shall meet norms required by regulations from this field under SRPS EN and SRPS EN standards, i.e. EN and EN (for meters under MID Directive) 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 standard i.e. EN 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. Type of label 1. Serial number 2. Name or 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 Page 127

128 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, i.e. 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 meter type in the same way. 17. Connection diagram with labels (numbers) of contact points SEALING Meter is constructed to provide a corresponding protection level against dust and humidity penetration. According to SRPS IEC meters are manufactured to provide the protection level of at least IP METER FUNCTIONS 2.1. METERING, REGISTRATION AND DISPLAY FUNCTIONS 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 (OBIS)). In addition to that, in manual display operating mode it shows the value of registers 1.8.x and 2.8.x (register label in accordance with SRPS EN (OBIS)). Presentation of these values on the display is programmable, as already described under point REACTIVE ENERGY The meter measures, registers and displays reactive energy within the rated accuracy class boundaries. The meter measures consumed reactive energy (register labels 3.8.x in accordance with SRPS EN (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 (OBIS)). Presentation of these values on the display is programmable, as already described under point 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 (OBIS)). Power integration period is Page 128

129 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 INSTANEOUS ACTIVE POWER The meter measures and displays on request current active power on LC display LOAD PROFILES OF METERED AND REGISTERED VALUES Meter shall have the possibility to record at least 4 profiles of metering or registered values. Each profile should support the recording of at least 6 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: LOAD PROFILE Meter records and registers the load profile (mean active power value). Integration period is initially 15 minutes. Corresponding time stamp is recorded in the load profile with corresponding block of registered mean active power value. Total capacity for load profile storage shall enable memorising of at least 4320 power metering records 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. In addition to hourly values of registers, meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of hourly register values with the corresponding block of registers. 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 PROFILE OF DAILY REGISTER VALUES Meter records and registers the values of all accounting registers at the pre set time. Initially this is at 00 hrs, but this parameter is programmable. In addition to daily register values, the meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of daily register values with the corresponding block of registers. Memory for the storage of profiles of daily values of meter registers and statuses has the capacity of at least 7 records, under FIFO principle. Page 129

130 PROFILE OF METERING VALUES This profile is initially used for recording and registering of the voltage value at the meter inlet. Corresponding time stamp is recorded in the profile of metering values with the corresponding block of registers. Total memory capacity for storage of profiles of metering values shall enable memorising of at least 500 sets of metering values. This profile may be used for recording and registering of other metering values (e.g. values of current through the meter) 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 VOLTAGE METERING Meter measures and displays effective voltage value on request CURRENT METERING Meter measures and displays effective current value on request PHASE PRESENCE Meter displays phase voltage presence on the connected conductors. Phase display function provides information on certain phase presence. As a rule, voltage drop below the value of 50% of rated voltage is valued as the absence of corresponding phase voltage. This value is programmable, and it is initially 50% TIME AND DATE Meter displays time and date from internal switching clock INTERNAL CLOCK Accuracy and other features of internal clock shall be realised in accordance with SRPS EN and SRPS EN 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. Page 130

131 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/ 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 (under self check regime of meter operation). 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 DAYLIGHT SAVING TIME DST Meter shall possess automatic daylight saving time function, according to the calendar of Central European Time CET CURRENT TARIFF Meter shall have continuous display of current active tariff register, regardless of its display mode 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 five different days within the season and two different days for holidays. Tariffs may be changed during one day for at least eight times EXTERNAL TARIFF REGISTER MANAGEMENT External tariff register management is executed by means of two clamps for control voltage 230 V connection and it has priority over local tariff register management. This function shall be realized solely upon the request of electricity distributor 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. It is desirable that meters memorise accounting registers state during each metering integrity violation. Page 131

132 For each of the indicated events, Event Log shall make a record with a time stamp when this event occurred 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 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). Event Log shall record each data change occurring on the meter COUNTDOWN Meter shall have the reduction blockade of achieved individual tariff register values DATA STORAGE PERIOD Accounting data (active and reactive 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 ADDITIONAL FUNCTIONS 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. Page 132

133 Block diagram of meter interfaces. Meter shall have the following interfaces: Type Type Physical characteristics of interface Communication protocol Optical interface: IR port SRPS EN DLMS/COSEM Electrical no.1* : interface See explanation in the text below Optionally (subject to additional request of electricity distributor) Electrical interface no. 2 : Electrical interface no. 3 : Electrical interface no. 4 : DLMS/COSEM RS 485 RS 485 DLMS/COSEM M BUS EN EN RS 232 RS 232 EN Ethernet RJ 45 Ethernet TCP/IP (DHCP) or Meter shall have DLMS/COSEM certificate issued upon checking software for testing the latest version (at least 2.0) Electrical interfaces are galvanically insulated from the metering part of the meter. P 133

134 Communication part of the meter is executed to enable simultaneous communication with the meter via all meter interfaces, without their mutual disturbance, especially 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 are achieved under PLUG IN principle (connector to connector), with no wire connections, whereas the total consumption of the meter and communication module does not exceed the requirement from point 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. * Electrical interface number 1 is used for: Connection with communication module for remote reading (GRPS modem, PLC modem, etc.). Direct connection with laptop when necessary to access the meter/meter parameters directly. It is desired to be executed via two wire active RS 485 interface, but due to the specific feature of envisaged Point to point communication with direct metering groups, the use of another solution that the manufacturer considers to be efficient enough in order to achieve planned system performances is allowed. In the event when the electrical interface number 1 is not executed via two wire active RS 485 interface, in accordance with the request of the distributor it is optionally requested that the meter, in order to easily connect more meters on the bus in the event of group installation of the meters, has additional connector with two wire active RS 485 interface and it is realized: by separate connector on the meter itself (eg. auxiliary contacts) or by separate connector at the communication module for remote reading (GRPS modem, PLC modem, etc.), or by relevant module for extension of external interface RS 485 function. In that case the mentioned module is delivered with the meter. Electrical interface M BUS shall be realised upon the request of electricity distributor and it is used for: Meter connection with other metering devices (water meter, gas meter, heat meter) point 2.7. 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 requests for switch module (bistable switch)). Electrical interface RS 232, i.e. Ethernet, shall be realised subject to the request of electricity distributor and it is used for: HAN (Home Area Network) connection of modem/module (depending on the manufacture, and upon the request of electricity distributor). Page 134

135 Optional electrical interfaces (M BUS, RS 232, Ethernet) can be realised by separate connector on the meter itself (eg. auxiliary contacts) or by separate connector at the communication module for remote reading (GRPS modem, PLC modem, etc), or by relevant module for extension of external interfaces. In that case the mentioned module is delivered with the meter GPRS COMMUNICATION At the request of the Procuring Entity, the meter may be equipped with GPRS communication module which is connected to the meter via specific electrical interface, whereas the requests from items (dimensions) and (housing) are fulfilled. Characteristics of GPRS communication module are given in the Chapter Technical Characteristics and functional requests for GPRS modem items 1, 2.1 and PLC COMMUNICATION At the request of the Procuring Entity, the meter may be equipped with PLC communication module which may be, in accordance with the Procuring Entity s request, installed as: External PLC communication modem, which is connected to the meter via specific electrical interface. Characteristics of external PLC communication module are given in the Chapter Technical Characteristics and functional requests for PLC modem, items 1, 2 and 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 In that case, electrical interface number 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. In accordance with the Procuring Entity s request, 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 requests 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 requests for switching module (bistable switch). If distributor chooses 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 addition to this, meter has minimally one control output (independent relay) for management of individual devices in customer installation (consumption management function). Page 135

136 In the course of meter parameterization it should be possible to define the category (group) to which the meter belongs, in terms of consumption management function realization 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: CONDITIONAL SWITCH RECLOSING After receiving instructions for reconnection/expiry of penalty time, it is necessary to confirm switch reclosing locally via key/keys. The display shows a corresponding notification that the condition necessary for connection has been achieved, and that key confirmation is expected AUTOMATIC SWITCH RECLOSING After receiving instructions for reconnection/expiry of penalty time, the switch is automatically reconnected REMOTE CONSUMPTION MANAGEMENT Meter has at least one control output (independent relay) for management of individual devices at the customer installation (usually thermal ones). 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 remotely (AMM Centre command), with possible automatic activation in accordance with the current tariff programme done via programming 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, the meter (e.g. via display) gives a signal that the limit has been exceeded and that the customer will be disconnected from the network if during the permitted overload time it does not reduce its consumption. This signalling is possible on an additional display located at the customer s house/flat (if communication with additional display is achieved HAN). After expiry of permitted overload time, switching module for customer disconnection/connection is activated, and meter display/additional display shows that disconnection was done due to limit exceedence as well as information about the time until the expiry of the penalty period (if this parameter is active in the meter). Page 136

137 After the expiry of penalty time reconnection is done in accordance with active switch operation regime (conditional or automatic switch reconnection). 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 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 QUALITY METERING MAXIMUM AND MINIMUM VOLTAGE Meter measures and registers maximum and minimum voltage value on the monthly level MAXIMUM CURRENT Meter measures and registers maximum current value on the monthly level 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 100 entries. Under voltage and overvoltage thresholds may be adjusted. Initially: under voltage = 20% Un, overvoltage = +15% Un SUPPLY INTERRUPTION REGISTRATION Meter registers supply interruptions in accordance with SRPS ЕN 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 POWER FACTOR METERING (cos φ) The meter measures and registers power factor METER FIRMWARE UPGRADE Meter shall support firmware upgrade option in accordance with the Directive WELMEC 7.2, publication 5 or newer, Software Guideline (Directive 2004/22/EC of the European Parliament and of the Council on measuring instruments). Regardless of meter firmware realization option, firmware upgrade 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. Procedure of firmware upgrade in meter, local and remote, shall be executed in accordance with valid legal regulation. Page 137

138 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). If this parameter is 0, this means that meter will directly after new firmware upgrade start its execution. 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 LOCAL FIRMWARE UPGRADE Meter is connected via its local electrical interface with the manual terminal or laptop containing corresponding software for installation of the new firmware on the meter. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, it is desirable that the meter has the mechanism to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner REMOTE FIRMWARE UPGRADE Meter is connected via its local external communication module with AMM Centre containing the corresponding software module for installation of the new firmware on the meter. Alternatively, AMM Centre role may be taken over by concentrators (if they exist within the system), but after AMM Centre instruction. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, it is desirable that the meter has the mechanism to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner. Also, this type of action shall be recorded permanently within AMM Centre 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). In addition to this, self check is mandatory during every firmware upgrade. Self check is also executed upon the request of authorised person, at the point of delivery itself via handheld devices. Self check verifies the following: Memory integrity of the meter Meter statuses and alarms Meter display Battery status In addition to these, the following checks may be performed: connection check towards external communication module, voltage presence, etc. Self check results are entered into the Event Log. Page 138

139 2.7 МULTI UTILITY METERING Meter possesses an electrical interface (M Bus) 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 and transferred data encryption. 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 firmware, change of meter parameters, as well as local connection/disconnection of switching module. These actions over meter are enabled after removal of terminal cover (violation of distribution company seal) but only after verification of user type of software package installed on the handheld device/laptop, as well as meter password. Each change of parameters/firmware 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. Page 139

140 TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE PHASE ELECTRICITY METERS SEMI INDIRECT METERING GROUP Page 140

141 1. TECHNICAL CHARACTERISTICS OF METERS FOR SEMI INDIRECT CONNECTION (THREE PHASE SEMI INDIRECT METERING GROUP) 1.1. GENERAL TECHNICAL CHARACTERISTICS OPERATION MODE CONSTRUCTION: Meter shall be electronic (static) for threephase four wire semi indirect connection with three metering systems and operating in all four quadrants RATED (REFERENCE) VOLTAGE: 3 x 230/400 ( 20%, +15%)V RATED CURRENT: 5 (6) А RATED FREQUENCY: 50 Hz 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 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 standard) MINIMUM ACCURACY CLASS: For active energy and power SRPS EN standard 1 EN standard B For reactive energy SRPS EN standard ANTICIPATED OPERATION LIFE: minimum 15 years SIZE (HOUSING, TERMINAL AND COVERS): Dimensions (main measures) have to be done according to Figure 1. All measures are given in mm. b 1 b 2 C h 1 h 2 h 3 h 4 * 150± * Procuring Entity retains the right to, in accordance with its needs, also define other values for minimum dimension of h 4 Page 141

142 Figure 1: General meter draft. Dimension h 4 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 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 Auxiliary and control terminals are executed under the PLUG IN principle or through corresponding clamps. Terminal is executed to fully eliminate the possibility of winding sliding (during maximum moment of re screwing the screw defined by the manufacturer), screw fallout from sockets and simultaneously providing easy re screwing of screws and safe opening of clamps in accordance with the opening size for conductor introduction into the terminal, regardless of meter position. 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.) 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. Page 142

143 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, manual and self check 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), which is programmable. Under automatic regime, values of metered and registered values are shown cyclically. Individual value display period should be programmable and between 5 to 20 sec. Values presented on LC display, their sequence and number shall be changeable (programmable). Initially, only accounting elements and current date and time are cyclically changed in the period of 5 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). Values displayed in the standard data menu, their sequence and number shall be changeable (programmable) and independent from the setting for automatic display regime. Self check display regime is realised to visually verify the accuracy of symbol and character display on it (verification of proper operation of all LC display elements), as well as basic meter functions. Self check function is described in more detail under point 2.6. 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 8 (eight) digits, while at least 3 (three) digits are used for display of decimal digits, and the remaining for whole digits. 5 (five) to 7 (seven) 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 (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. In case of detection of phase and neutral conductor crossing (point ), all symbols showing the phase presence shall blink with the frequency of about 1 Hz. In case of detection of metering integrity violation (terminal cover opening, meter housing opening, parameter change, strong magnetic field impact on the meter, etc.) it is desirable that the signalling for violation is performed via display with all elements blinking, until status registry is reset. Page 143

144 General appearance of the display with the display sequence is as shown on Figure 2 and together with the scrolling function is in accordance with VDN recommendations, by which the position of the elements is not critical. Phase display Area of metered values Unit display -P +Q L 1 L 2 L 3 +P -Q Area of characteristic codes Cursor field Figure 2: Principled general display design Access to accounting elements for previous months is realised in a very simple manner (e.g. by pressing the key for 2 sec), grouping the values according to accounting period, chronologically, starting from the last accounting period towards previous ones 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, as well as return to automatic operation regime NUMBER OF TARIFFS Meter has the possibility of storing metered values in 4 (four) tariff registers IMPULSE (TEST) TERMINALS Meter has at least two impulse terminals. One shall be optical (via red LE diode), the other electrical, with galvanic insulation, passive and executed on a corresponding terminal connection. Page 144

145 CHARACTERISTICS OF IMPULSE TERMINALS Characteristics of impulse terminals of the meter are realised according to the standard SRPS EN i.e. SRPS EN 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 imp/kwh (imp/kvarh) 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 METER HOUSING MATERIALS, SHAPES 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 quenching characteristics in accordance with the requirements indicated by SRPS EN standard. Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN 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. 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, consumption management terminals, tariff control, etc.) and not disturb direct access to the terminal and auxiliary contacts. This space shall be anticipated either under the terminal covers 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 IRREGULAR CONNECTION AND NEUTRAL CONDUCTOR DISCONNECTION 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. Page 145

146 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 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) ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS Meter shall meet norms required by regulations from this field under SRPS EN and SRPS EN standards, i.e. EN and EN (for meters under MID Directive) 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 standard i.e. EN (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. 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 Page 146

147 that 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 SEALING Meter is constructed to provide a corresponding protection level against dust and humidity penetration. According to SRPS EN meters are manufactured to provide the protection level of at least IP METER FUNCTIONS 2.1 METERING, REGISTRATION AND DISPLAY FUNCTIONS Meter shall measure and register in all four energy quadrants ACTIVE ENERGY The meter measures, registers and displays active energy within the rated accuracy class. Meter measures consumed and delivered active energy (register labels 1.8.x and 2.8 x in accordance with SRPS EN (OBIS)). Presentation of these values on the display is programmable, as already described under point REACTIVE ENERGY The meter measures, registers and displays reactive energy within the rated accuracy class. The meter measures consumed and delivered reactive energy (register labels 3.8.x and 4.8x in accordance with SRPS EN (OBIS)). Presentation of these values on the display is programmable, as already described under point 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 (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 INSTANEOUS ACTIVE POWER The meter measures and displays on request current active power on LC display LOAD PROFILES OF METERED AND REGISTERED VALUES Meter shall have the possibility to record at least 4 profiles of metering or registered values. Each profile should support the recording of at least 6 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: Page 147

148 LOAD PROFILE Meter records and registers the load profile (mean active power value). Integration period is initially 15 minutes. Corresponding time stamp is recorded in the load profile with corresponding block of registered mean active power value. Total capacity for load profile storage shall enable memorising of at least 4320 power metering records 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. In addition to hourly values of registers, meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of hourly register values with the corresponding block of registers. 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 PROFILE OF DAILY REGISTER VALUES Meter records and registers the values of all accounting registers at the pre set time. Initially this is at 00 hrs, but this parameter is programmable. In addition to daily register values, the meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of daily register values with the corresponding block of registers. Memory for the storage of profiles of daily values of meter registers and statuses has the capacity of at least 7 records, under FIFO principle PROFILE OF METERING VALUES This profile is initially used for recording and registering of the voltage value at the meter inlet. Corresponding time stamp is recorded in the profile of metering values with the corresponding block of registers. Total memory capacity for saving of profiles of metering values shall enable memorising of at least 500 sets of metering values. This profile may be used for recording and registering of other metering values (e.g. values of current through the meter) 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. Page 148

149 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 VOLTAGE METERING Meter measures and displays effective voltage value on request CURRENT METERING Meter measures and displays effective current value on request PHASE PRESENCE Meter displays phase voltage presence on the connected conductors. Phase display function provides information on certain phase presence. As a rule, voltage drop below the value of 50% of rated voltage is valued as the absence of corresponding phase voltage. This value is programmable, and it is initially 50% TIME AND DATE Meter displays time and date from internal switching clock INTERNAL CLOCK Accuracy and other features of internal clock shall be realised in accordance with SRPS EN and SRPS EN 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 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 (under self check regime of meter operation). 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. Page 149

150 DAYLIGHT SAVING TIME DST Meter shall possess automatic daylight saving time function, according to the calendar of Central European Time CET CURRENT TARIFF Meter shall have continuous display of current active tariff register, regardless of its display mode 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 five different days within the season and two different days for holidays. Tariffs may be changed during one day for at least eight times EXTERNAL TARIFF REGISTER MANAGEMENT External tariff register management is executed by means of two clamps for control voltage 230 V connection and it has priority over local tariff register management. This function shall be realized solely upon the request of electricity distributor 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. It is desirable that meters memorise accounting registers state during each metering integrity violation. For each of the indicated events, Event Log shall make a record with a time stamp when this event occurred 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 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). Event Log shall record each data change occurring on the meter. Page 150

151 COUNTDOWN Meter shall have the reduction blockade of achieved individual tariff registers DATA STORAGE PERIOD Accounting data (active and reactive imported and exported 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 first (the oldest) in the sequence of registers. Total registered electricity cannot be deleted. 2.2 ADDITIONAL FUNCTIONS 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. Block diagram of meter interfaces. Meter shall have the following interfaces: Type Type Physical characteristics of interface Communication protocol Optical interface: IR port SRPS EN DLMS/COSEM P 151

152 Electrical interface no. 1* : Adopted by Expert Council of JP EPS April 29, 2010, Belgrade, See explanation in the text below Optionally (subject to additional request of electricity distributor) Electrical interface no. 2 : Electrical interface no. 3 : Electrical interface no. 4 : DLMS/COSEM RS 485 RS 485 DLMS/COSEM M BUS EN EN RS 232 RS 232 EN Ethernet RJ 45 Ethernet TCP/IP (DHCP) or Meter shall have DLMS/COSEM certificate issued upon checking software for testing the latest version (at least 2.0) Electrical interfaces are galvanically insulated from the metering part of the meter. Communication part of the meter is executed to enable simultaneous communication with the meter via all meter interfaces, without their mutual disturbance, especially without impact on the measuring part of the meter. External communication is executed via special communication module, situated in the corresponding space (point ). All electrical connections of communication module with the meter are achieved under PLUG IN principle (connector to connector), with no wire connections, whereas the total consumption of the meter and communication module does not exceed the requirement from point 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. *Electrical interface number 1 is used for: Connection with communication module for remote reading (GRPS modem, PLC modem, etc.) Direct connection with laptop when necessary to access the meter/meter parameters directly. It is desired to be executed via two wire active RS 485 interface, but due to the specific feature of envisaged Point to point communication with semi indirect metering groups, the use of another solution that the manufacturer considers to be efficient enough in order to achieve planned system performances is allowed. In the event when the electrical interface number 1 is not executed via two wire active RS 485 interface, in accordance with the request of the distributor it is optionally requested that the meter, in order to easily connect with other equipment or devices in for example distribution transformer station, has additional connector with two wire active RS 485 interface and it is realized: By separate connector on the meter itself (e.g. auxiliary contacts) or By separate connector at the communication module for remote reading (GRPS modem, PLC modem, etc.), or Page 152

153 By relevant module for extension of external interface RS 485 function. In that case the mentioned module shall be delivered with the meter. Electrical interface M BUS shall be realised upon the request of electricity distributor and it is used for: Meter connection with other metering devices (water meter, gas meter, heat meter) point 2.7. Electrical interface RS 232, i.e. Ethernet, shall be realised upon the request of electricity distributor and it is used for: HAN (Home Area Network) connection of modem/module (depending on the manufacture, and upon the request of electricity distributor). Optional electrical interfaces (M BUS, RS 232, Ethernet) 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 (GRPS modem, PLC modem, etc.), or By relevant module for extension of external interfaces. In that case the mentioned module is delivered with the meter GPRS COMMUNICATION At the request of the Procuring Entity, the meter may be equipped with GPRS communication module which is connected to the meter via specific electrical interface, whereas the requests from items (dimensions) and (housing) are fulfilled. Characteristics of GPRS communication module are given in the Chapter Technical Characteristics and functional requests for GPRS modem items 1, 2.1 and PLC COMMUNICATION At the request of the Procuring Entity, the meter may be equipped with PLC communication module which may be, in accordance with the Procuring Entity s request, installed as: External PLC communication module, which is connected to the meter via specific electrical interface. Characteristics of external PLC communication module are given in the Chapter Technical Characteristics and functional requests for PLC modem, items 1, 2 and 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 ELECTRICAL DEVICES MANAGEMENT Meter has minimally one control output (independent relay) for management of individual devices in customer installation (consumption management function). In the course of meter parameterization it should be possible to define the category (group) to which the meter belongs, in terms of consumption management function realization in the case of simultaneous disconnection/connection of switching modules with the larger number of users REMOTE CONSUMPTION MANAGEMENT Meter has at least one control output (independent relay) for management of individual devices at the customer installation (usually thermal ones). Control output is galvanically Page 153

154 separated as a relay, with minimum technical characteristics 230V, 2A, whose connections are executed on meter terminal. Activation of this output is primarily done remotely (AMM Centre command), with possible automatic activation in accordance with the current tariff programme done via programming. 2.4 ELECTRICITY QUALITY METERING MAXIMUM AND MINIMUM VOLTAGE Meter measures and registers maximum and minimum voltage value on the monthly level MAXIMUM CURRENT Meter measures and registers maximum current value on the monthly level 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 100 entries. Under voltage and overvoltage thresholds may be adjusted. Initially: under voltage = 20% Un, overvoltage = +15% Un SUPPLY INTERRUPTION REGISTRATION Meter registers supply interruptions in accordance with SRPS ЕN 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 METERING OF TOTAL HARMONIC DISTORTION (THD) FACTOR The meter measures total harmonic distortion factor (THD) according to EN POWER FACTOR METERING (cos φ) The meter measures and registers power factor. 2.5 METER FIRMWARE UPGRADE Meter shall support firmware upgrade option in accordance with the Directive WELMEC 7.2, publication 5 or newer, Software Guideline (Directive 2004/22/EC of the European Parliament and of the Council on measuring instruments). Regardless of meter firmware realization option, firmware upgrade 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. Procedure of firmware upgrade in meter, local and remote, shall be executed in accordance with valid legal regulation. 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). If this parameter is 0, this means that meter will directly after new firmware upgrade start its execution. Page 154

155 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 LOCAL FIRMWARE UPGRADE Meter is connected via its local electrical interface with the manual terminal or laptop containing corresponding software for installation of the new firmware on the meter. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, it is desirable that the meter has the mechanism to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner REMOTE FIRMWARE UPGRADE Meter is connected via its local external communication module with AMM Centre containing the corresponding software module for installation of the new firmware on the meter. Alternatively, AMM Centre role may be taken over by concentrators (if they exist within the system), but after AMM Centre instruction. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, it is desirable that the meter has the mechanism to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner. Also, this type of action shall be recorded permanently within AMM Centre. 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). In addition to this, self check is mandatory during every firmware upgrade. Self check is also executed upon the request of authorised person, at the point of delivery itself via handheld devices. Self check verifies the following: Memory integrity of the meter Meter statuses and alarms Meter display Battery status In addition to these, the following checks may be performed: connection check towards external communication module, voltage presence, etc. Self check results are entered into the Event Log. Page 155

156 2.7 МULTI UTILITY METERING Meter possesses an electrical interface (M Bus) 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 mentionedd 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 and transferred data encryption. 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 firmware or change of other meter parameters. These actions over meter are enabled after removal of terminal cover (violation of distribution company seal) but only after verification of user type of software package installed on the handheld device/laptop, as well as meter password. Each change of parameters/firmware 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. Page 156

157 TECHNICAL CHARACTERISTICS AND FUNCTIONAL REQUIREMENTS FOR THREE PHASE ELECTRICITY METERS INDIRECT METERING GROUP Page 157

158 1. TECHNICAL CHARACTERISTICS OF THE METER FOR INDIRECT CONNECTION (THREE PHASE INDIRECT METERING GROUP) 1.1. GENERAL TECHNICAL CHARACTERISTICS 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 RATED (REFERENCE) VOLTAGE: Under threesystem metering 3 x 100/ 3V Under twosystem metering (Aaron connection). 3 x 100V RATED CURRENT: 5 (6) А RATED FREQUENCY: 50 Hz 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 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 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 NKT 0.5S) SRPS EN standard 0.5S EN standard C For reactive energy SRPS EN standard 3 or For active energy and power (IMG NKT 0.2S) SRPS EN standard 0.2S For reactive energy SRPS EN standard ANTICIPATED OPERATION LIFE: minimum 15 years Page 158

159 SIZE (HOUSING, TERMINAL AND COVERS): Dimensions (main measures) have to be done according to Figure 1. All measures are given in mm. b 1 b 2 C h 1 h 2 h 3 h 4 * 150± * Procuring Entity retains the right to, in accordance with its needs, also define other values for minimum dimension of h 4 Figure 1 Figure 1: General meter draft. Dimension h 4 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. Page 159

160 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 Auxiliary and control terminals are executed under the PLUG IN principle or through corresponding clamps. Terminal is executed to fully eliminate the possibility of winding sliding (during maximum moment of re screwing the screw defined by the manufacturer), screw fallout from sockets and simultaneously providing easy re screwing of screws and safe opening of clamps in accordance with the opening size for conductor introduction into the terminal, regardless of meter position. 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.) 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, manual and self check 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), which is programmable. Under automatic regime, values of metered and registered values are shown cyclically. Individual value display period should be programmable and between 5 to 20 sec. Values presented on LC display, their sequence and number shall be changeable (programmable). Initially, only accounting elements and current date and time are cyclically changed in the period of 5 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.). Values displayed in the standard data menu, their sequence and number shall be changeable (programmable) and independent from the setting for automatic display regime. Self check display regime is realised to visually verify the accuracy of symbol and character display on it (verification of proper operation of all LC display elements), as well as basic meter functions. Self check function is described in more detail under point 2.5. 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 8 (eight) digits, while at least 4 (four) digits are used for display of decimal digits, and the remaining for whole digits. 5 (five) to 7 (seven) 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 (OBIS). Page 160

161 Figures for value display shall at least be: For metered values 7 mm For characteristic codes 5 mm General appearance of the display is as shown on Figure 2 and together with the scrolling structure is in accordance with VDN recommendations, by which the position of the elements is not critical. Area of metered values Phase display Unit display -P +Q L 1 L 2 L 3 +P -Q Area of characteristic codes Cursor field Figure 2: Principled general display design Corresponding symbols are turned off ( fade out ) during absence of individual phase voltages, i.e. in accordance with current direction of energy flow. In case of detection of metering integrity violation (terminal cover opening, meter housing opening, parameter change, strong magnetic field impact on the meter, etc.) it is desirable that the signalling for violation is performed via display with all elements blinking, until status registry is reset. Access to accounting elements for previous months is realised in a very simple manner (e.g. by pressing the key for 2 sec), grouping the values according to accounting period, chronologically, starting from the last accounting period towards previous ones 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, as well as return to automatic operation regime NUMBER OF TARIFFS Page 161

162 Meter has the possibility of storing metered values in 4 (four) tariff registers IMPULSE (TEST) TERMINALS Meter has at least two impulse terminals. One shall be optical (via red LE diode), the other electrical, with galvanic insulation, passive and executed on a corresponding terminal connection CHARACTERISTICS OF IMPULSE TERMINALS Characteristics of impulse terminals of the meter are realised according to the standard SRPS EN i.e. SRPS EN METER CONSTANT Meter constant is expressed by the number of impulses per energy unit (imp/kwh or kvarh), amounting to: Electrical imp/kwh (imp/kvarh) Optical imp/kwh (imp/kvarh) 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 OTHER TECHNICAL CHARACTERISTICS METER HOUSING MATERIALS, SHAPES 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 quenching characteristics in accordance with the requirements indicated by SRPS EN standard. Meters shall meet Class II electrical insulation level (requirements also defined under SRPS EN 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. 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 connections, etc.) and not disturb direct access to the terminal and auxiliary contacts. This space shall be anticipated either under the terminal covers 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 Page 162

163 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) ELECTROMAGNETIC COMPATIBILITY AND RESISTANCE TO OTHER IMPACTS Meter shall meet norms required by regulations from this field under SRPS EN and SRPS EN standards, i.e. EN and EN (for meters under MID Directive) 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 standard i.e. EN (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. 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, i.e. 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 Page 163

164 1.2.5 SEALING Meter is constructed to provide a corresponding protection level against dust and humidity penetration. According to SRPS EN meters are manufactured to provide the protection level of at least IP METER FUNCTIONS 2.1. METERING, REGISTRATION AND DISPLAY FUNCTIONS Meter measures and registers in all four energy quadrants ACTIVE ENERGY The meter measures, registers and displays active energy within the rated accuracy class. Meter measures consumed and delivered active energy (register labels 1.8.x and 2.8 x in accordance with SRPS EN (OBIS)). Presentation of these values on the display is programmable, as already described under point 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 REACTIVE ENERGY The meter measures, registers and displays reactive energy within the rated accuracy class boundaries. The meter measures consumed and delivered reactive energy (register labels 3.8.x and 4.8xin accordance with SRPS EN (OBIS)). Presentation of these values on the display is programmable, as already described under point 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 3.8x or 4.8 x 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 (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 INSTANEOUS ACTIVE POWER The meter measures and displays on request current active power on LC display LOAD PROFILES OF METERED AND REGISTERED VALUES Meter shall have the possibility to record at least 4 profiles of metering or registered values. Each profile should support the recording of at least 6 selected values (channels). Sampling period inside each profile can be independently set. Page 164

165 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: LOAD PROFILE Meter records and registers the load profile (mean active power value). Integration period is initially 15 minutes. Corresponding time stamp is recorded in the load profile with corresponding block of registered mean active power value. Total capacity for load profile storage shall enable memorising of at least 4320 power metering records 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. In addition to hourly values of registers, meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of hourly register values with the corresponding block of registers. 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 PROFILE OF DAILY REGISTER VALUES Meter records and registers the values of all accounting registers at the pre set time. Initially this is at 00 hrs, but this parameter is programmable. In addition to daily register values, the meter records and registers meter statuses. Corresponding time stamp is recorded in the meter in the profile of daily register values with the corresponding block of registers. Memory for the storage of profiles of daily values of meter registers and statuses has the capacity of at least 7 records, under FIFO principle PROFILE OF METERING VALUES This profile is initially used for recording and registering of the voltage value at the meter inlet. Corresponding time stamp is recorded in the profile of metering values with the corresponding block of registers. Total memory capacity for storage of profiles of metering values shall enable memorising of at least 500 sets of metering values. This profile may be used for recording and registering of other metering values (e.g. values of current through the meter) EVENT LOG Meter memorises events related to metering, adjustment and handling into the specialmemory 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. Page 165

166 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 VOLTAGE METERING Meter measures and displays effective voltage value on request CURRENT METERING Meter measures and displays effective current value on request PHASE PRESENCE Meter displays phase voltage presence on the connected conductors. Phase display function provides information on certain phase presence. As a rule, voltage drop below the value of 50% of rated voltage is valued as the absence of corresponding phase voltage. This value is programmable, and it is initially 50% TIME AND DATE Meter displays time and date from internal switching clock INTERNAL CLOCK Accuracy and other features of internal clock shall be realised in accordance with SRPS EN and SRPS EN 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 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. Page 166

167 Battery state testing function shall be realised inside the meter (under self check regime of meter operation). 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 DAYLIGHT SAVING TIME DST Meter shall possess automatic daylight saving time function, according to the calendar of Central European Time CET CURRENT TARIFF Meter shall have continuous display of current active tariff register, regardless of its display mode 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 five different days within the season and two different days for holidays. Tariffs may be changed during one day for at least eight times EXTERNAL TARIFF REGISTER MANAGEMENT External tariff register management is executed by means of two clamps for control voltage connection and it has priority over local tariff register management. This function shall be realised upon the request of electricity distributor 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. It is desirable that meters memorise accounting registers state during each metering integrity violation. For each of the indicated events, Event Log shall make a record with a time stamp when this event occurred 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 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). Page 167

168 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). Event Log shall record each data change occurring on the meter COUNTDOWN Meter shall have the reduction blockade of achieved individual tariff register states DATA STORAGE PERIOD Accounting data (active and reactive imported and exported 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 first (the oldest) in the sequence of registers. Total registered electricity cannot be deleted ADDITIONAL FUNCTIONS 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. Block diagram of meter interfaces. P 168

169 Meter shall have the following interfaces: Type Type Physical characteristics of interface Communication protocol Optical interface: IR port SRPS EN DLMS/COSEM Electrical interface.1* : See explanation in the text below DLMS/COSEM Optionally (subject to additional request of electricity distributor) Electrical interface.2 : RS 485 RS 485 DLMS/COSEM RS 232 RS 232 EN Electrical interface.3 : or Ethernet RJ 45 Ethernet TCP/IP (DHCP) Meter must have DLMS/COSEM certificate issued upon software for testing the latest version (at least 2.0) Electrical interfaces are galvanically insulated from the metering part of the meter. Communication part of the meter is executed to enable simultaneous communication with the meter via all meter interfaces, without their mutual disturbance, especially without impact on the metering 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), with no wire connections, where the total consumption of the meter and communication module does not exceed the requirement from point 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. * Electrical interface number 1 is used for: Connection with communication module for remote reading (GRPS modem, etc.) Direct connection with laptop when necessary to access the meter/meter parameters directly. It is desired to be executed via two wire active RS 485 interface, but due to the specific feature of envisaged Point to point communication with indirect metering groups, the use of another solution that the manufacturer considers to be efficient enough in order to achieve planned system performances is allowed. In the event when the electrical interface number 1 is not executed via two wire active RS 485 interface, in accordance with the request of the distributor it is optionally requested that the meter, in order to easily connect with other equipment or devices in for example distribution Page 169

170 transformer station, has additional connector with two wire active RS 485 interface and it is realized: by separate connector on the meter itself (eg. auxiliary contacts) or by separate connector at the communication module for remote reading (GRPS modem, PLC modem, etc.), or by relevant module for extension of external interface RS 485 function. In that case the mentioned module is delivered with the meter. Electrical interface RS 232, i.e. Ethernet, shall be realised upon the request of electricity distributor and it is used for: HAN (Home Area Network) connection of modem/module (depending on the manufacture, and upon the request of electricity distributor). Optional electrical interfaces (RS 232, Ethernet) can be realized: by separate connector on the meter itself (eg. auxiliary contacts) or by separate connector at the communication module for remote reading (GRPS modem, PLC modem, etc), or by relevant module for extension of external interfaces. In that case the mentioned module is delivered with the meter GPRS COMMUNICATION At the request of the Procuring Entity, the meter may be equipped with GPRS communication module which is connected to the meter via specific electrical interface, whereas the requests from items (dimensions) and (housing) are fulfilled. Characteristics of GPRS communication module are given in the Chapter Technical Characteristics and functional requests for GPRS modem, items 1, 2.1 and ELECTRICITY QUALITY METERING MAXIMUM AND MINIMUM VOLTAGE Meter measures and registers maximum and minimum voltage value on the monthly level MAXIMUM CURRENT Meter measures and registers maximum current value on the monthly level 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 100 entries. Under voltage and overvoltage thresholds may be adjusted. Initially: under voltage = 20% Un, overvoltage = +15% Un SUPPLY INTERRUPTION REGISTRATION Meter registers supply interruptions in accordance with SRPS ЕN 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 Page 170

171 longer than 3 minutes), recorded in the electricity quality log. Meter records corresponding codes into electricity quality log for each supply interruption METERING OF TOTAL HARMONIC DISTORTION (THD) FACTOR The meter measures total harmonic distortion factor (THD) according to EN POWER FACTOR METERING (cos φ) The meter measures and registers power factor METER FIRMWARE UPGRADE Meter shall support firmware upgrade option in accordance with the Directive WELMEC 7.2, publication 5 or newer, Software Guideline (Directive 2004/22/EC of the European Parliament and of the Council on measuring instruments). Regardless of meter firmware realization option, firmware upgrade 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. Procedure of firmware upgrade in meter, local and remote, shall be executed in accordance with valid legal regulation. 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). If this parameter is 0, this means that meter will directly after new firmware upgrade start its execution. 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 date 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 LOCAL FIRMWARE UPGRADE Meter is connected via its local electrical interface with the manual terminal or laptop containing corresponding software for installation of the new firmware on the meter. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not completed successfully, it is desirable that the meter has the mechanism to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner REMOTE FIRMWARE UPGRADE Meter is connected via its local external communication module with AMM Centre containing the corresponding software module for installation of the new firmware on the meter. Alternatively, AMM Centre role may be taken over by concentrators (if they exist within the system), but after AMM Centre instruction. This process is executed in the manner not affecting at any time the data in the meter. If for some reason firmware upgrade was not Page 171

172 completed successfully, it is desirable that the meter has the mechanism to restore automatically the original (previous version) firmware. Event Log records all actions of this type in the corresponding manner. Also, this type of action shall be recorded permanently within AMM Centre 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). In addition to this, self check is mandatory during every firmware upgrade. Self check is also executed upon the request of authorised person, at the point of delivery itself via handheld devices. Self check verifies the following: Memory integrity of the meter Meter statuses and alarms Meter display Battery status In addition to these, the following checks may be performed: connection check towards external communication module, voltage presence, etc. Self check results are entered into the Event Log 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 and transferred data encryption. 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 firmware or change of other meter parameters. These actions over meter are enabled after removal of terminal cover (violation of distribution company seal) but only after verification of user type of software package installed on the handheld device/laptop, as well as meter password. Each change of parameters/firmware 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. Page 172

173 ADDITIONAL METER FUNCTIONS FOR CONNECTION OF ELECTRICITY GENEREATION FACILITIES Page 173

174 1. ADDITIONAL METER FUNCTIONS FOR CONNECTION OF ELECTRICITY GENEREATION FACILITIES According to the additional requests of electricity distributor, for placement to the connection point of electricity generation facilities on distribution network, meter fulfills 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 MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR METERS WITH DIRECT CONNECTION (DIRECT METERING GROUPS) 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 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 (OBIS)). Presentation of these values on the display is programmable, as already described under point of technical specifications for direct metering groups 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 (OBIS)). Presentation of these values on the display is programmable, as already described under point of technical specifications for direct metering groups MAXIMUM ACTIVE POWER Meter measures, registers and displays maximum mean active power under all tariffs and in both directions (register mark 1.6.x in accordance with SRPS EN (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 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 (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. Page 174

175 1.2. MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR METERS WITH SEMI INDIRECT CONNECTION (SEMI INDIRECT METERING GROUPS) According to the specific request of electricity distributor, due to the specific manner of electricity measuring on connection points of the electricity genereation facilities, functions of the meters for semi indirect connection (semi indirect metering groups) are mandatory extended with the following functions 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 (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 MANDATORY SCOPE OF EXTENDED FUNCTIONS FOR METERS WITH INDIRECT CONNECTION (INDIRECT METERING GROUPS) According to the specific request of electricity distributor, due to the specific manner of electricity measuring on connection points of the electricity genereation facilities, functions of the meters for indirect connection (indirect metering groups) are mandatory extended with the following functions 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 (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, additionаl extensions of existing functions are optionally realized for all electricity meters on connection points of electricity generation facilities SEALING According to the additional request of electricity distributor and SRPS IEC meters are manufactured to provide the protection level of at least IP PROFILES OF METERED AND REGISTERED VALUES Page 175

176 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 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 (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 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 (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 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 METERS WITH SEMI INDIRECT CONNECTION (SEMI INDIRECT METERING GROUPS) 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 optionally extended with the following functions RATED ACCURACY CLASS Page 176

177 According to the specific request of electricity distributor, rated accuracy class of semi indirect meter for connection of electricity generation facilities is: 0.5 for active energy and active power. Minimum 3 for reactive energy and power. Page 177

178 LIST OF MANDATORY TESTINGS (ATTESTS) ACCORDING TO THE RELEVANT STANDARDS Page 178

179 LIST OF MANDATORY TESTINGS (ATTESTS) ACCORDING TO THE RELEVANT STANDARDS All meters that shall be procured in accordance with the technical specifications must have all relevant reports on results of meter testing (attests), on meeting requirements defined by standards and in accordance with rated mater accuracy class and energy type for which the meter is intended: General requirements for all meter types and with all rated accuracy classes: SRPS EN (or equivalents), Specific requirements for static meters of active energy of rated accuracy classes 1,0 and 2,0: SRPS EN (or equivalents), Specific requirements for static meters of active energy of rated accuracy classes 0,5S and 0,2S: SRPS EN (or equivalents), Specific requirements for static meters of active energy of rated accuracy classes 2,0 and 3,0: SRPS EN (or equivalents). Testing results should be issued by accredited laboratories which scope of accreditation is subject testing. Laboratory that issues the report should be accredited by national accreditation body that is equal member of European Accrediting Organization (EA) or International Accreditation Form (IAF) or International Laboratory Accreditation Cooperation (ILAC). Procuring Entity stipulates transitory period during which interested meter manufacturers can obtain relevant attests. Until the end of transitory period, manufacturer at least has to be in possession of list of attests under title Mandatory Tastings. Upon the end of transitory period, list of attests under the title Additional Tastings becomes an integral part of the list Mandatory Tastings. Also, until the end of transitory period the Procuring Entity shall equally treat the results of meter tastings (attests), whether they are performed only on the meter or on the meter with connected external communication module or on the meter with connected external communication module and external switching module. Upon the end of transitory period, the Procuring Entity shall request the results of tastings (attests) to be performed for meter with connected external communication module and external switching module. The expiration date of transitory period is: six (6) months from the adoption date of this document. Page 179

180 List of mandatory tastings (attests) for single phase and three phase meters Mandatory tests (necessary attests) Item Description SRPS EN SRPS EN Power consumption 7.1. Voltage dips and short interruptions Influence of short time overcurrents 7.2. Heating 7.2. Fast transient burst Impulse voltage test AC voltage test 7.4 Ambient temperature variation 8.2. Magnetic induction of external origin 0.5 mt 8.2. Immunity to electrostatic discharges IP SRPS EN Relay in bi stable switch SRPS EN UC3 Additional tests (provide until the end of transitory period) Influence of self heating 7.3. Test of immunity to electromagnetic RF fields Fast transient burst Test of immunity to conducted disturbances, Induced by RF fields Surge immunity test Damped oscillatory waves immunity test Radio interference suppression RTC SRPS EN , SRPS EN Impulse outlets SRPS EN , SRPS EN Power consumption SRPS EN Bi stable switch SRPS EN UC3 Page 180

181 List of mandatory tastings (attests) for direct and semi direct metering groups Mandatory tests Item Description SRPS EN SRPS EN SRPS EN Power consumption Voltage dips and short interruptions Influence of short time overcurrents Heating 7.2. Fast transient burst Impulse voltage test AC voltage test Ambient temperature variation Magnetic induction of external origin 0.5 mt Immunity to electrostatic discharges IP SRPS EN Relays in bi stable switch* SRPS EN UC3 * relevant only for direct metering groups Additional tests (provide until the end of transitory period) Influence of self heating Test of immunity to electromagnetic RF fields Fast transient burst Test of immunity to conducted disturbances, Induced by RF fields Surge immunity test Damped oscillatory waves immunity test Radio interference suppression RTC SRPS EN , SRPS EN Impulse outlets SRPS EN , SRPS EN Power consumption SRPS EN Bi stable switch* * relevant only for direct metering groups SRPS EN UC3 Page 181

182 List of mandatory testing (attests) for indirect metering groups, accuracy class 0.5S and 0.2S Mandatory tests Item description SRPS EN SRPS EN SRPS EN Power consumption Voltage dips and short interruptions Influence of short time overcurrents Heating 7.2. Fast transient burst Impulse voltage test AC voltage test Ambient temperature variation Magnetic induction of external origin 0.5 mt Immunity to electrostatic discharges IP SRPS EN Additional tests (provide until the end of transitory period) Influence of self heating Test of immunity to electromagnetic RF fields Fast transient burst Test of immunity to conducted disturbances, Induced by RF fields Surge immunity test Damped oscillatory waves immunity test Radio interference suppression RTC SRPS EN , SRPS EN Impulse outlets SRPS EN , SRPS EN Power consumption SRPS EN Page 182

183 LIST OF FUNCTIONAL METER TESTINGS Page 183

184 LIST OF FUNCTIONAL METER TESTINGS In the procedure of technical acceptance of meter and sample testing, it is necessary to perform detail meter testing to verify fulfillment of requests from technical specifications for meters from this document. List of requested functionalities is given in Table 1. Usually, the Procuring Entity performs the testing for all items from this list, but it retains the right to perform the testing only for specific items from this list according to its needs. Table number 1 No. Type of testing 1 Meter size overview 2 Display harmonization overview 3 Key functionality overview 4 Tariff harmonization overview 5 Meter labels overview Meter overview Irregular connection Change of the sequence of input and output 6 phase conductors 7 Neutral conductor disconnection 8 Replacement of phase and neutral conductor Meter fulfils the conditions YES NO Additional comment 9 Current active tariff 10 Active energy in both tariffs 11 Reactive energy in both tariffs 12 Mid 15 minutes active power in both tariffs 13 Voltage in all phases 14 Current in all phases 15 Time 16 Date 17 Detection of terminal cover opening 18 Detection of strong magnetic field 19 Calculation values profile 20 Load profile 21 Hourly values profile 22 Daily values profile 23 Metering values profile Metering integrity Profiles Page 184

185 24 Event Log 25 Electricity quality Log Event Log Communication 26 Local communication (optical port) 37 Local communication (RS 485 modem)¹ 28 Remote communication (PLC modem)² 29 Remote communication (GPRS modem)ᶟ Consumption management 30 Remote connection/disconnection of the switch 31 Local connection/disconnection of the switch 32 Conditional switch connection 33 Automatic switch connection 34 Function of switch limiting 35 Relay outlet functioning 36 Local firmware update 37 Remote firmware update 38 Maximum and minimum voltage 39 Sub voltage and over voltage 40 Maximum current 41 Short term voltage disconnection 42 Long term voltage disconnection 43 Self check 44 Data safety function Firmware update Electricity quality measurement Parameterization 45 Time 46 Date 47 DTS 48 Tariff table 49 Sequence of the values displayed in automatic regime 50 Specifying time interval for shift of values in display automatic regime 51 Specifying the starting point of the new tariff 52 program Specifying starting point of the new software (firmware) 53 Specifying automatic switch connection 54 Specifying conditional switch connection Page 185

186 55 56 Specifying limit of the power for automatic switch disconnection Determining values in metering values profile and time when values were entered 1) Local communication testing via RS 485 port is executed if realized on the meter (realization modes of RS 485 port are described in technical requests for the meters). 2) Remote communication testing via PLC modem is executed only if such communication is requested 3) Remote communication testing via GPRS modem is executed only if such communication is requested Page 186

187 FUNCTIONAL REQUIREMENTS OF METER DATA MANAGEMENT AND REPOSITORY SYSTEM (MDM/R) Page 187

188 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. 1.1 ABBREVIATIONS Table 1 Overview of used abbreviations Figure 1 AMS Advanced Metering System API AM AMCD AMR AMRC AMI AMM AMCC CET CIM CIS COSEM CPP 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 Companion Specification for Energy Metering Critical Peak Pricing Page 188

189 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 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 Accounting data 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. Designates metering data processed by VEE and ready for use for collection purposes. Page 189

190 CPP Customer Daily period Firmographic/ Demographic GUI reading Interested party kwh CIS Metered consumption MDM/R MMD POD RPP TOU VEE 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. Term related to electricity consumption of individual and grouped residential facilities, where additional metering compared to the approved power is not necessary. Designates 24 hour period for metering data collection, whereas it may be altered due to daylight saving time changes. Daily reading period starts on midnight, i.e hrs. every day, Term related to basic data of customer profile, either business or 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. Related to graphic user interface, whereas it is the most frequently used type of computer interface within modern operating systems. Represents legal entities having authorisation to access certain data from MDM/R system. Measure for active electricity. Term related to central information subsystem of electric utility used for customer data storage and processing. Represents the value generated by the meter, representing cumulative electricity consumption at the point of delivery at a certain moment. Meter data management and repository system used to process data on metered consumption aimed at obtaining accounting data and data storage for further use. 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. 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. Represents electricity distribution system access tariff for customers based on consumed kwh. 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 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 Page 190

191 WAN 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. Page 191

192 1.2 APPLIED STANDARDS The following standards were used in the course of development of this document: IEC 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 Application integration at electric utilities System interfaces for distribution management Part 1: Interface architecture and general requirements IEC Application integration at electric utilities System interfaces for distribution management Part 2: Glossary IEC Application integration at electric utilities System interfaces for distribution management Part 3: Interface for network operations IEC Application integration at electric utilities System interfaces for distribution management Part 9: Interface for meter reading and control IEC Application integration at electric utilities System interfaces for distribution management Part 11: Common Information Model (CIM) Extensions for Distribution IEC Energy management system application program interface (EMS API) Part 301: Common information model (CIM) base IEC 62051:1999 Electricity metering Glossary of terms IEC 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 Electricity metering Payment systems Part 31: Particular requirements Static payment meters for active energy (classes 1 and 2) IEC Electricity metering Data exchange for meter reading, tariff and load control Page 192

193 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 to 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. Page 193

194 Generally, MDM/R system provides: Adopted by Expert Council of JP EPS April 29, 2010, Belgrade, 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. 1.6 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. Page 194

195 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. Page 195

196 2. 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. Figure 2 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. Figure 3 Detailed functionality of MDM/R system Page 196

197 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. 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. Page 197

198 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. Data entered into MDM/R system include: 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 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 60 minute 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. Page 198

199 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. 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, Page 199

200 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. 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: 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. Page 200

201 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. Reports stored within MDM/R system should not be distributed further to other information subsystems within electric utility 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: 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: Page 201

202 Unique POD ID 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. 2.5 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. Figure 4 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 Page 202

203 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. 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 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 Page 203

204 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 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: 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 Page 204

205 enabling its execution of additional requests with the delay, or to provide data access by using the procedure not influencing operational processing 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. 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 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: Page 205

206 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 USER INTERFACE MDM/R system should enable MDM/R system operator and/or external user, insight into possible changes of received meter data. 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 Page 206

207 IDs. These external possibilities related to value change will be used as the support during editing under (VEE) analysis 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 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: 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. Page 207

208 2.7.2 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 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 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 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. Page 208

209 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 metering points, as well as for certain meter IDs, for which an external identity has been identified as primary authority for such data 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 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 Page 209

210 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 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 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. Page 210

211 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). 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. Page 211

212 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 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 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, Page 212

213 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 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 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. Page 213

214 Amendments to documents: Amendments to documents are stated here after their adoption by the Expert Council of EPS in Belgrade, In addition to removal of noted spelling mistakes, document has been slightly changed in its logical organization: Separate sections are introduced, describing Functional Requirements and technical characteristics of integrated and external PLC modems, external and integrated switching modules. Technical characteristics for meters are organized in five lots, according to the meter type (single phase meters, three phase meters, direct metering groups, semi indirect metering groups and indirect metering groups). In accordance with potential requirements of the Procuring Entity, logical connections towards specific system elements (PLC and GPRS modems, i.e. switching modules) are given in corresponding places. Within separate sections, specific requirements for meters are defined for connection of the electricity generation facilities. Meter Testing Lists are defined in items from relevant standards, under the title Mandatory tastings and Additional testing, as well as the transitory deadline with the conditions for attests acceptance. During the procedure of technical meter acceptance or sample testing, the list of functional testing of meters is defined. List of important amendments: Requirements for concentrators in terms of operating conditions are defined in more detail, while the manner of realization of the concentrator is not amended. Technical requirements in terms of supply type, number and type of communication and other ports are adjusted as well. 1. Amendments are on pages 16 and 47, respectively. Requirements for GPRS modems are defined in more detail and adjusted according to the needs of electricity distributor. 2. Technical requirements in terms of GPRS modem supply and its operation under irregular conditions on the network, etc. are also described in more detail. 3. Amendments are on pages 58 and 59. Requirements for PLC modems are defined in more detail and adjusted according to the needs of electricity distributor. 4. Functional requirements for external and internal PLC modem are defined. 5. Technical requirements in terms of PLC modem supply, its operation under irregular conditions on the network, etc. are described in more detail. 6. Amendments are on pages 61 until 64. Page 214

215 Adopted by Expert Council of JP EPS April 29, 2010, Belgrade, Functional requirements for switching modules (integrated and external switching module) are defined. 7. The stated functional requirements are listed on page 66. Requirements in terms of permitted meter consumption are defined in more detail. 8. Amendments are on pages 69, 88, 107, 127 and145. Requirements in terms of minimum rated meter accuracy class (in the light of recent adoption of MID directive) are defined in more detail. Amendments are on pages 69, 88, 107, 127 and145. In accordance with the observations from the field, the requirement for minimum value of h 4 dimension is amended. 9. Amendments are on pages 69, 88, 107, 127 and 146. Requirements in terms of the structure of data which are shown on the display, without limitations of the manner of display realization are described in more detail. 10. Amendments are on pages 71, 90, 109, 128 and 147. Requirements for the space for the installation of external communication module within meter housing are described in more detail. Amendments are on pages 73, 92, 111, 131 and 149. Definition of irregular connection, disconnection of neutral conductor and disappearance of one or two phases (where applicable) are described in more detail. Amendments are on pages 74, 93, 112 and 131. Requirements for meter labels are described in more detail. Amendments are on pages 74, 93, 112, 132 and 150. Requirements for event log(s) are described in more detail. Amendments are on pages 76, 96, 115, 135 and 153. Requirements for internal clock are described in more detail. Amendments are on pages 77, 96, 115, 135 and 153. Requirements for stand by supply are described in more detail. Amendments are on pages 77, 96, 116, 135 and 154. In items regarding the detection of strong magnetic field, the text is amended in the following manner instead of referring to the value of 200mT at which detection of magnetic field is realized, it is left to the manufacturer itself to define external magnetic field detection threshold, when malfunction in meter operation can occur. Amendments are on pages 78, 98, 117, 137 and 155. In accordance with logical reorganization of document, requirements for meter communication are described in more detail. Requirements for the manner of execution of RS 485 interface are defined in more detail. Page 215

216 Within metering groups, due to the apparent specific characteristics of point to point communication, the requirement for electric interface number 1 is reduced. Spelling mistake made during the stating of the standards EN and EN (tables of realized interfaces in meters) is corrected: instead of EN and EN , it was stated EN i.e. EN by mistake. Amendments are on pages 79 82, , , and In accordance with the logical document reorganization, the requirements for consumption and electrical devices management (where applicable) are described in more detail. Amendments are on pages 82 84, , and Within the requirements for electricity quality measuring, the requirement for the voltage variations measuring is deleted. Amendments are on pages 84, 103, 122, 140 and 158. Requirement on the meter firmware upgrade is additionally defined. Amendments are on pages 84, 103, 123, 141 and 158. Request on data security is defined in more detail. Amendments are on pages 86, 105, 124, 143 and 160. Page 216