Am550 Um V3.00 Eng [PDF]

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AM550 User manual

ISKRAEMECO, d.d. Savska loka 4, 4000 Kranj +386 4 206 4000 [email protected]

www.iskraemeco.com

AM550 User manual

ISKRAEMECO, d.d. Savska loka 4, 4000 Kranj +386 4 206 4000 [email protected]

www.iskraemeco.com

AM550 User manual Document code:

EAK 020.616.337

Version:

V3.00

Language:

English

Date:

22.03.2019

COPYRIGHT © 2019 ISKRAEMECO, d.d. All rights reserved. No part of this document can be copied, reproduced, transferred, distributed, presented or stored in any format without the prior written consent of Iskraemeco, d.d., except as otherwise provided in your license or as expressly permitted in writing by Iskraemeco, d.d. TRADEMARKS The trademarks and brand names represented in this manual, including corporate logos and emblems, are property of Iskraemeco, d.d. and subject of protection of applicable laws. All rights reserved. DISCLAIMER AND LIMITATION OF LIABILITY This User manual was written for use of AM550 meters. This document, including all documentation incorporated by reference herein, such as documentation provided or made available at Iskraemeco d.d. website, is provided or made accessible "AS IS" and "AS AVAILABLE" and without condition, endorsement, guarantee, representation, or warranty of any kind by Iskraemeco d.d. and its affiliated companies (hereinafter collectively referred to as ”Iskraemeco”). Iskraemeco assumes no responsibility for any typographical, technical, or other inaccuracies, errors, or omissions in this documentation, nor for any loss due to the use of this documentation. Iskraemeco reserves the right to periodically change information that is contained in this documentation; however, Iskraemeco makes no commitment to provide any such changes, updates, enhancements, or other additions to this documentation. Iskraemeco shall not be liable for any type of damages related to this documentation or its use, or performance or non-performance of any software, hardware, service, or any third party products and services. SAVE AS EXPRESSLY PROVIDED IN YOUR CONTRACT WITH ISKRAEMECO, ISKRAEMECO EXPRESSLY DISCLAIMS ALL WARRANTIES, EXPRESS OR IMPLIED, INCLUDING, BUT NOT LIMITED TO THE IMPLIED WARRANTIES OF MERCHANTABILITY OR FITNESS, FOR A PARTICULAR PURPOSE AND AGAINST INFRINGEMENT. ISKRAEMECO DOES NOT WARRANT THAT THE FUNCTIONS CONTAINED IN THE PRODUCT WILL BE UNINTERRUPTED OR ERROR-FREE, OR THAT DEFECTS IN THE PRODUCT OR ERRORS IN THE DATA WILL BE CORRECTED. FURTHERMORE, ISKRAEMECO DOES NOT WARRANT OR MAKE ANY REPRESENTATIONS REGARDING THE USE OR THE RESULTS OF THE USE OF THE PRODUCT OR ITS DOCUMENTATION IN TERMS OF THEIR CORRECTNESS, ACCURACY, RELIABILITY, OR OTHERWISE. NO ORAL OR WRITTEN INFORMATION OR ADVICE, GIVEN BY ISKRAEMECO OR AN ISKRAEMECO AUTHORIZED REPRESENTATIVE, SHALL CREATE A WARRANTY OR IN ANY WAY INCREASE THE SCOPE OF THIS WARRANTY. SOME JURISDICTIONS DO NOT ALLOW EXCLUSION OF THE IMPLIED WARRANTIES, SO THE ABOVE EXCLUSION MAY NOT APPLY. UNDER NO CIRCUMSTANCES, INCLUDING NEGLIGENCE, SHALL ISKRAEMECO, THEIR DIRECTORS, OFFICERS, EMPLOYEES OR AGENTS BE LIABLE FOR ANY INCIDENTAL, SPECIAL OR CONSEQUENTIAL DAMAGES (INCLUDING DAMAGES FOR LOSS OF BUSINESS, LOSS OF PROFITS, BUSINESS INTERRUPTION, LOSS OF BUSINESS INFORMATION, ETC.) ARISING OUT OF THE USE OR INABILITY TO USE THE PRODUCT OR ITS DOCUMENTATION, EVEN IF ISKRAEMECO OR AN ISKRAEMECO-AUTHORIZED REPRESENTATIVE HAS BEEN ADVISED OF THE POSSIBILITY OF SUCH DAMAGES. SOME JURISDICTIONS DO NOT ALLOW LIMITATION OR EXCLUSION OF LIABILITY FOR INCIDENTAL OR CONSEQUENTIAL DAMAGES, OR ALLOW EXCLUSION OR LIMITATION OF LIABILITY ONLY FOR NEGLIGENCE, BUT NOT FOR GROSS NEGLIGENCE OR WILLFUL MISCONDUCT, SO THIS LIMITATION MAY NOT APPLY. ISKRAEMECO'S TOTAL LIABILITY FOR ALL DAMAGES, LOSSES AND CAUSES OF ACTION (WHETHER IN CONTRACT, TORT, INCLUDING NEGLIGENCE, OR OTHERWISE) SHALL BE DEFINED WITH THE CONTRACT WITH WHICH YOU BOUGHT THE PRODUCT OR SERVICE. IF LIABILITY IS NOT DEFINED WITHIN THE PREVIOUSLY MENTIONED CONTRACT, ISKRAEMECO’S LIABILITY FOR ANY AND ALL DAMAGE EVER RELATED TO THIS DOCUMENTATION SHALL NOT EXCEED (IF NOT OTHERWISE DEFINED WITH APPLICABLE LAW) THE AMOUNT: 1) PAID FOR THE PRODUCT/ SERVICE AND ITS DOCUMENTATION, 2) OF 20% OF THE VALUE OF THE CUSTOMER’S ORDERS FROM THE LAST12 MONTHS BEFORE THE OCCURRENCE OF DAMAGE, OR 3) 10 000 EUR, WHICHEVER THE LOWEST.

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List of meter variants covered by this document AM550-ED0 230 V, 5(60) A AM550-ED1 230 V, 5(85) A AM550-EB2 230 V, 5(100) A AM550-TD0 3×230/400V, 5(60) A AM550-TD1 3×230/400V, 5(85) A AM550-TD2 3×230/400 V, 5(100) A AM550-TD3 3×230/400 V, 5(120) A AM550-TT2 3×230/400 V, 1(10) A

ADVANCED RESIDENTIAL SMART METER with modular communication

USER MANUAL

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i. About This document describes the AM550-E meter (E stands for one-phase meters) and AM550-T meter (T stands for three-phase meters), their usage, installation, and maintenance. It represents the purpose of the AM550 meter, meter construction, the way of deriving the measured quantities and meter functionalities. The document is intended for technically qualified personnel at energy supply companies, responsible for system planning and system operation.

ii. Reference documents  

Iskraemeco’s general terms and condition Technical descriptions of communication modules

iii. Versioning Date

Version Update

21.03.2017 V1.00 12.04.2017 V2.00

18.04.2017 V2.01

17.07.2017 V2.20

11.09.2017 V2.21

14.12.2017 V2.22

12.04.2018 V2.30

V3.00 – English

The first version of the document.  One-phase meter variants and some three-phase meter variants were added.  Some guiding improvements were made.  Improved explanation of I/O terminals in chapters 3.5. Connection diagram and 4.2.2.2. Terminal block – I/O area  Minor change on nameplate (MID) of AM550 three-phase meter in Figure 35  Added chapter 8.7.2.11. Power failure event log  Minor changes in chapter 16. TECHNICAL CHARACTERISTICS  Due to FW-Application-version upgrade (one- and three-phase meter), object lists were updated (chapters 17. ANNEX: OBJECT LIST)  In chapter iv. Definitions, Acronyms and Abbreviations, “CLRFW” was added  In chapter 2. ENERGY METERING WITH AM550 / Optical port property, IEC 62056-46 standard was added  In chapters 4.2.1. Current and voltage terminals, 12. INSTALLATION PROCEDURE, and 12.1.1. Power (main) cables, minimum cross section was added  Figure 16: Terminating-resistor switch – positions 0 and 1 was added  Figure 34 was updated  For calculating the total energy (in addition to the vector method), arithmetic method was added (chapter 7. MEASUREMENT PLATFORM) and description of the measurement platform was improved  In Table 25, for all meter types default values for the energy output constants were added  In the first note of chapter 8.4.1. Push on Power down (Last gasp), “battery” was changed in “ultracapacitor” and the sentence was improved  In chapters 8.5.1. Meter cover open, terminal cover open, communication-module cover open and 8.5.2. Magnetic field detection, explanation of “15 minutes” was added  Improved explanations in chapter 8.6. Load profiles and chapter 8.7. Billing was moved under it  In chapter 8.6. Load profiles, objects Load profile with period 1 – secondary and Load profile with period 2 – secondary were removed  OBIS code of "Image activation log” was corrected (1-0:99.98.8*255  0-0:99.98.8*255)  In chapter 17. ANNEX: OBJECT LIST, object lists and firmware versions were updated  BS meter type AM550-EB2 was added to the document.  In chapter 12.3. SIM card installation, SIM card type recommendation was added.  Cable with minimum cross-section wire of 2.5 mm2 can be used for all main terminals at all meter variants (4.2.1. Current and voltage terminals).  Signs of additional connections were added (Figure 35)  Terminal reducing insert for installation of cable with minimum cross-section wire was added (12.1.1. Power (main) cables)  In chapter 16. TECHNICAL CHARACTERISTICS, additional connections were added and data updated.  Some improvements were made (additional explanations, cross-references…).  Document improvements  In chapter 5.1. Display, “K” and “k” characters were added  Updated chapter 5.2. OBIS code on the display  Chapter 5.4.2. Display format for demand: “energy presentation” changed to “demand presentation” iii/xv

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06.12.2018 V2.40

22.03.2019 3.00

V3.00 – English

 Upgraded chapter 7.4. Energy (Metrological) LED and digital output constants and its subchapters  Added functionalities: - 8.10.1. External tariff inputs - 8.16. Mirrored objects (option) - 9.2.1. Roles  Upgraded chapter 11.1. SAP assignment  Updated chapter 12.3. SIM card installation  Improvements in chapter 1. SAFETY INFORMATION  Electrical characteristics of RS-485, I/Os, and M-Bus were added  Updated lists of available I/Os and their functions  On the list of available characters on LCD, “K” and “k” characters were removed  Functional description of energy scaler was added  Net Active Energy per tariff, and Instantaneous reactive import/export power per phase were added  Updated list of events (Table 44)  Configuration of terminals for external tariff inputs was added  Roles were updated  Through entire document, additional safety information were added  Correction of AM550-EB2 utilization category  Improved technical characteristics table with additional information  Upgraded FW versions and object lists  Added integrated Ethernet communication  Added AM550-TT2 type (current transformer) of meter  LCD character list was upgraded  Upgraded firmware versions and object lists  Minor improvements of the document

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iv. Definitions, Acronyms and Abbreviations Abbreviation AC A/D AES AMI API APDU ARP ASCII BS CDMA CIP CLRFW COM COSEM CPU CT DC DHCP DIN disconnector DLMS DLMS UA DNS DST EN ECDH ECDSA EMC E-meter ESD ETSI FD/FM FEM FF FIFO FW GCM G-meter GPRS GSM HAN HDLC HES HLS HHU HW ICMP ID IDIS IEC IEEE IHD I/O IP ISO JEDEC V3.00 – English

Explanation Alternating Current Analog/Digital Advanced Encryption Standard Advanced Metering Infrastructure Application Programming Interface Application Protocol Data Unit Address Resolution Protocol American Standard Code for Information Interchange British Standard Code Division Multiple Access Consumer Information Push Country Legally Relevant FirmWare COMmunication Companion Specification for Energy Metering Central Processing Unit Current Transformer Direct Current Dynamic Host Configuration Protocol Deutsches Institut für Normung Switching device Device Language Message Specification DLMS User Association Domain Name Server Daylight Saving Time European Norm Elliptic Curve Diffie-HellmanGCM Elliptic Curve Digital Signature Algorithm ElectroMagnetic Compatibility Electrical meter ElectroStatic Discharge European Telecommunications Standards Institute Fraud Detection/Factory Mode Field Exchangeable Module Fatal Failure First In, First Out FirmWare Galois/Counter Mode Gas meter General Packet Radio Service Global System for Mobile communications Home Area Network High-level Data Link Control Head-End System High Level Security Hand Held Unit HardWare Internet Control Message Protocol Identification Interoperable Device Interface Specifications International Electrotechnical Commission Institute of Electrical and Electronics Engineers In-House Display Input/Output Internet Protocol International Organization for Standardization Joint Electron Device Engineering Council; JEDEC Solid State Technology Association – independent semiconductor engineering trade organization and standardization body v/xv

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AM550 User manual Abbreviation Last gasp LCD LED LLS LNRFW LP LRFW LSB LTE MAC address MCU MDI MID MP MSB MU NAN Nm NV memory OBIS OSM OVC P* P0 P1 P2 P3 PC PCB PDP PLC PPP RAM RF RMS RTC SAP SD SHA SIM SSR SW TCO TOU UC UDP UMTS UTC UV VDEW WAN WEEE WP

Explanation Synonym for the “Push on Power down” functionality Liquid Crystal Display Light Emitting Diode Low Level Security (also NLRFW) Legally Non-Relevant FirmWare Load Profile Legally Relevant FirmWare Least Significant Bit Long-Term Evolution Media Access Control address MicroController Unit Maximum Demand Indicator Measuring Instruments Directive Measurement Period Most Significant Bit Multi-Utility Neighbourhood Area Network Newton metre Non-Volatile memory Object Identification System Other Service Module Over Voltage Category Meter’s interface for communication modules (WAN and HAN) Optical interface Communication port/interface for OSM Communication port/interface for M-Bus (Gas, Heat and Water meters) Communication port/interface for WAN and NAN communication Personal Computer Printed Circuit Board Packet Data Protocol Power Line Communication Point-to-Point Protocol Random-Access Memory Radio Frequency Root Mean Square Real Time Clock Service Access Point Switching Device Secure Hash Algorithm Subscriber Identity Module Solid State Relay SoftWare Total Cost of Ownership Time Of Use Utilization Category User Datagram Protocol Universal Mobile Telecommunications System Coordinated Universal Time Ultra Violet Verband Der ElektrizitätsWirtschaft Wireless Area Network Waste Electrical and Electronic Equipment Directive Width, Precision

NOTE OBIS (Object Identification System) code (according to DLMS UA 1000-1:2001 standard) is composed of 6 groups of digits (A-B:C.D.E*F; i.e. 0-0:1.0.0*255). If the last group of digits (group F) is omitted, the value of F is 255 presumed.

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TABLE OF CONTENTS 1.

SAFETY INFORMATION ...................................................................................................................... 1 1.1. Responsibilities .............................................................................................................................. 1 1.2. Safety instructions.......................................................................................................................... 1 1.2.1. Handling and mounting ........................................................................................................... 1 1.2.2. Meter installation procedure .................................................................................................... 3 1.2.3. Meter maintenance ................................................................................................................. 7

2.

ENERGY METERING WITH AM550 ..................................................................................................... 8

3.

METER INTRODUCTION ..................................................................................................................... 9 3.1. Standards and references .............................................................................................................. 9 3.2. AM550 meter type designation ......................................................................................................11 3.3. Meter appearance .........................................................................................................................12 3.3.1. One-phase meter appearance ................................................................................................12 3.3.2. Three-phase meter appearance .............................................................................................13 3.4. Main meter properties ...................................................................................................................14 3.5. Connection diagram ......................................................................................................................16 3.5.1. One-phase meter connection diagram ....................................................................................16 3.5.1.1. DIN connection ...............................................................................................................16 3.5.1.2. BS connection .................................................................................................................16 3.5.2. Three-phase meter connection diagram .................................................................................17 3.5.2.1. Direct connected meter ...................................................................................................17 3.5.2.2. Indirect connected meter .................................................................................................17

4.

METER CONSTRUCTION ...................................................................................................................18 4.1. Technical figures and dimensions .................................................................................................18 4.1.1. One-phase meter ...................................................................................................................18 4.1.2. Three-phase meter.................................................................................................................19 4.1.2.1. Three-phase meter with regular terminal cover ................................................................19 4.1.2.2. Three-phase meter with extended terminal cover ............................................................20 4.2. Terminal block ..............................................................................................................................21 4.2.1. Current and voltage terminals.................................................................................................21 4.2.1.1. One-phase meter current and voltage terminals ..............................................................21 4.2.1.1.1. DIN connection ...........................................................................................................21 4.2.1.1.2. BS connection ............................................................................................................22 4.2.1.2. Three-phase meter current and voltage terminals ............................................................23 4.2.1.2.1. Direct connected meter ...............................................................................................23 4.2.1.2.2. Indirect connected meter ............................................................................................24 4.2.2. Other terminals (options) ........................................................................................................25 4.2.2.1. Terminal block – communication area .............................................................................25 4.2.2.1.1. RS-485 (option) ..........................................................................................................25 4.2.2.1.2. Ethernet (option) .........................................................................................................26 4.2.2.2. Terminal block – I/O area ................................................................................................28 4.2.2.2.1. Electrical characteristics of inputs and outputs ............................................................29 4.2.2.3. Terminal block – M-Bus area ...........................................................................................30 4.2.2.3.1. Wired M-Bus (option) ..................................................................................................30 4.2.3. Terminal-cover-opening detector ............................................................................................31 4.2.4. U-I calibration link ..................................................................................................................31 4.3. Terminal cover ..............................................................................................................................32

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4.4. Communication-module part of the meter ......................................................................................33 4.4.1. Communication-module-cover opening detector .....................................................................33 4.5. Communication-module cover .......................................................................................................33 4.6. Sealing .........................................................................................................................................34 4.6.1. Sealing of terminal and communication covers .......................................................................34 4.6.2. Sealing of U-I link ...................................................................................................................35 4.6.3. Sealing of lower button (option) ..............................................................................................35 4.7. Nameplate ....................................................................................................................................36 4.7.1. Nameplate according to IEC...................................................................................................36 4.7.1.1. Three-phase meter nameplate (IEC) ...............................................................................36 4.7.2. Nameplate according to MID ..................................................................................................37 4.7.2.1. One-phase meter nameplate (MID) .................................................................................37 4.7.2.2. Three-phase meter nameplate (MID) ...............................................................................38 4.8. Label for CT ratio ..........................................................................................................................39 5.

CONSOLE ...........................................................................................................................................40 5.1. Display..........................................................................................................................................40 5.2. OBIS code on the display ..............................................................................................................43 5.3. Console modes of operation..........................................................................................................44 5.3.1. General Display Readout mode (auto-scroll sequence) ..........................................................44 5.3.2. Alternate Display Readout mode (manual-scroll sequence) ....................................................44 5.3.2.1. Reduced console menu type ...........................................................................................45 5.3.2.2. Normal console menu type ..............................................................................................45 5.3.3. Service mode (service manual-scroll sequence) .....................................................................46 5.4. Display format ...............................................................................................................................46 5.4.1. Display format for energy .......................................................................................................46 5.4.2. Display format for demand .....................................................................................................47 5.5. Other supported display functions .................................................................................................48 5.5.1. Display consumer message text .............................................................................................48 5.5.2. Signature on display...............................................................................................................48 5.5.3. Neutral - Phase wrong connection indication ..........................................................................48 5.5.4. Switching device disconnection indication ..............................................................................48 5.6. Practical cases..............................................................................................................................49 5.6.1. Reading firmware version, signature and hash on LCD ..........................................................49 5.6.2. Reading load profile values on LCD .......................................................................................50 5.6.3. Reading the certification log (P.99) values on LCD .................................................................50 5.7. Metrological LED...........................................................................................................................51 5.8. Buttons and Switching device status LED......................................................................................51 5.8.1. Sealable lower button (option) ................................................................................................51

6.

METER MODULES .............................................................................................................................52 6.1. 6.2. 6.3.

7.

P* interface ...................................................................................................................................52 Communication module – WAN (P3) – (option) .............................................................................53 Communication module – Consumer interface (P1) – (option) .......................................................53

MEASUREMENT PLATFORM.............................................................................................................55 7.1. Measuring configuration ................................................................................................................55 7.2. Measurement principle ..................................................................................................................55 7.3. Direct/indirect connection of the meter ..........................................................................................55 7.3.1. The ratio of the external measurement transformer ................................................................56 7.4. Energy (Metrological) LED and digital output constants .................................................................57 7.4.1. Energy (Metrology) LED constants .........................................................................................58

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7.4.2. Energy (Metrological) digital output constants.........................................................................58 7.5. Measured values...........................................................................................................................58 7.5.1. Energy ...................................................................................................................................58 7.5.1.1. Energy scaler ..................................................................................................................59 7.5.2. Demand (power) ....................................................................................................................60 7.5.3. Average values ......................................................................................................................61 7.5.4. Instantaneous values .............................................................................................................62 8.

DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES .........................................63 8.1. RTC Backup .................................................................................................................................63 8.2. Time .............................................................................................................................................63 8.3. Communication .............................................................................................................................63 8.3.1. Local communication .............................................................................................................63 8.3.1.1. Optical interface (P0).......................................................................................................63 8.3.1.2. P1 interface (P1) (option) ................................................................................................64 8.3.1.3. M-Bus interface (P2) .......................................................................................................65 8.3.1.3.1. Data encryption of user data on M-Bus interface (P2) .................................................65 8.3.2. Remote communication (P3) ..................................................................................................66 8.3.2.1. RS-485 (option)...............................................................................................................66 8.3.2.1.1. Port setup ...................................................................................................................67 8.3.2.2. Ethernet (option) .............................................................................................................69 8.3.2.2.1. Ethernet configuration .................................................................................................70 8.3.2.2.2. Ethernet filter ..............................................................................................................70 8.3.2.2.3. MAC address setup ....................................................................................................71 8.3.2.2.4. IPv4 Setup ..................................................................................................................71 8.3.2.2.5. Ethernet diagnostic information ...................................................................................71 8.4. Push .............................................................................................................................................73 8.4.1. Push on Power down (Last gasp) ...........................................................................................74 8.4.1.1. Enabling and disabling Push on Power down (Last gasp) ................................................74 8.5. Fraud detection .............................................................................................................................75 8.5.1. Meter cover open, terminal cover open, communication-module cover open...........................75 8.5.2. Magnetic field detection..........................................................................................................75 8.6. Load profiles .................................................................................................................................76 8.6.1. E-meter-related load profiles (definable load profiles) .............................................................77 8.6.1.1. Capture period ................................................................................................................77 8.6.1.2. Profile status ...................................................................................................................78 8.6.2. Billing load profile ...................................................................................................................78 8.6.3. Multi-utility-related load profiles ..............................................................................................80 8.6.3.1. Profile status for M-Bus load profile .................................................................................80 8.7. Event logs .....................................................................................................................................81 8.7.1. Event Code Objects ...............................................................................................................82 8.7.2. Event Log Objects..................................................................................................................82 8.7.2.1. Standard event log ..........................................................................................................84 8.7.2.2. Fraud detection log .........................................................................................................84 8.7.2.3. Disconnector control log ..................................................................................................85 8.7.2.4. M-Bus event log ..............................................................................................................85 8.7.2.5. Power quality log.............................................................................................................85 8.7.2.6. Communication event log ................................................................................................86 8.7.2.7. Communication details log ..............................................................................................86 8.7.2.8. Security event log............................................................................................................88 8.7.2.8.1. Security event counters ..............................................................................................89

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8.7.2.9. Image activation data log.................................................................................................90 8.7.2.10. M-Bus master control logs ...............................................................................................90 8.7.2.11. Power failure event log ....................................................................................................90 8.7.2.12. Certification data log .......................................................................................................91 8.7.3. Event Codes ..........................................................................................................................92 8.8. Errors..........................................................................................................................................106 8.8.1. Other errors .........................................................................................................................106 8.8.2. Critical errors .......................................................................................................................106 8.8.3. M-Bus errors ........................................................................................................................107 8.8.4. Error Register ......................................................................................................................107 8.8.5. Error codes interpretation .....................................................................................................109 8.9. Alarms ........................................................................................................................................110 8.9.1. Alarm Filter ..........................................................................................................................113 8.9.2. Alarm Register .....................................................................................................................113 8.9.3. Alarm Status ........................................................................................................................114 8.9.4. Alarm Descriptor ..................................................................................................................114 8.9.5. Alarm Register Monitor.........................................................................................................114 8.10. Activity calendar and TOU registration .....................................................................................115 8.10.1. External tariff inputs ..........................................................................................................116 8.10.2. Activity calendar Disconnector ..........................................................................................117 8.11. Power quality...........................................................................................................................117 8.11.1. Voltage sag ......................................................................................................................117 8.11.1.1. Threshold for voltage sag ..............................................................................................117 8.11.1.2. Time threshold for voltage sag ......................................................................................117 8.11.1.3. Counter for voltage sag .................................................................................................117 8.11.1.4. Number of voltage sags (per phase) ..............................................................................117 8.11.2. Voltage swell ....................................................................................................................118 8.11.2.1. Threshold for voltage swell ............................................................................................118 8.11.2.2. Time threshold for voltage swell ....................................................................................118 8.11.2.3. Counter for voltage swell ...............................................................................................118 8.11.2.4. Number of voltage swells (per phase) ............................................................................118 8.11.3. Voltage cut .......................................................................................................................118 8.11.4. Under-voltage ...................................................................................................................118 8.11.5. Over-voltage.....................................................................................................................119 8.11.5.1. Actual voltage values ....................................................................................................119 8.11.6. Voltage level.....................................................................................................................119 8.11.7. Daily peak and minimum...................................................................................................119 8.11.8. Voltage asymmetry ...........................................................................................................120 8.11.9. Power failure ....................................................................................................................120 8.12. Switching device (option) .........................................................................................................121 8.12.1. Disconnect control ............................................................................................................122 8.12.2. Additional disconnection control functions .........................................................................124 8.13. Limitation.................................................................................................................................125 8.13.1. Limiter ..............................................................................................................................125 8.13.2. Supervision monitor - IDIS ................................................................................................126 8.14. Counters .................................................................................................................................126 8.15. Function activation...................................................................................................................126 8.16. Mirrored objects (option) ..........................................................................................................127 9.

SECURITY ........................................................................................................................................128 9.1.

Physical security .........................................................................................................................128

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9.1.1. Sealing protection ................................................................................................................128 9.1.2. Tamper detection .................................................................................................................128 9.2. Logical security ...........................................................................................................................129 9.2.1. Roles ...................................................................................................................................129 10.

FIRMWARE UPDATE ....................................................................................................................131

10.1. 11.

ASSOCIATION ..............................................................................................................................133

11.1. 12.

Type of images ........................................................................................................................131

SAP assignment ......................................................................................................................133

INSTALLATION PROCEDURE ......................................................................................................134

12.1. Preparation of cables ...............................................................................................................134 12.1.1. Power (main) cables .........................................................................................................134 12.1.1.1. Installation without terminal reducing insert....................................................................135 12.1.1.2. Installation with terminal reducing insert ........................................................................136 12.1.2. Cables for Auxiliary terminals............................................................................................137 12.1.3. Ethernet cable ..................................................................................................................137 12.1.4. P1 port connector .............................................................................................................137 12.2. Mounting and installation procedure.........................................................................................138 12.3. SIM card installation ................................................................................................................139 13.

DISASSEMBLING OF A MODULE ................................................................................................140

13.1.

Removing the P1 module out of the meter cover ......................................................................142

14.

METER MAINTENANCE ................................................................................................................144

15.

METER DEINSTALLATION ...........................................................................................................145

16.

TECHNICAL CHARACTERISTICS ................................................................................................146

16.1. 16.2. 17.

One-phase meter.....................................................................................................................146 Three-phase meter ..................................................................................................................148

ANNEX: OBJECT LIST..................................................................................................................150

17.1. 17.2.

One-phase meter.....................................................................................................................150 Three-phase meter ..................................................................................................................167

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INDEX OF FIGURES Figure 1: Smart metering system .................................................................................................................................. 8 Figure 2: Appearance of AM550 one-phase meter (example) .......................................................................................12 Figure 3: Appearance of AM550 three-phase meter (example) .....................................................................................13 Figure 4: Connection diagram of the AM550 – one-phase meter – DIN connection .......................................................16 Figure 5: Connection diagram of the AM550 – one-phase meter – BS connection.........................................................16 Figure 6: Connection diagram of AM550 – direct connected three-phase meter ............................................................17 Figure 7: Connection diagram of AM550 – indirect connected three-phase meter .........................................................17 Figure 8: Overall and fixing dimensions of the AM550 – one-phase meter (in mm) ........................................................18 Figure 9: Overall and fixing dimensions of the AM550 three-phase meter with regular terminal cover (in mm). ...............19 Figure 10: Overall and fixing dimensions of the AM550 three-phase meter with extended terminal cover (in mm). .........20 Figure 11: Terminal block – example of one-phase meter with DIN connection .............................................................21 Figure 12: Terminal block – example of one-phase meter with BS connection...............................................................22 Figure 13: Terminal block – example of a three-phase meter with direct connection ......................................................23 Figure 14: Terminal block – example of a three-phase meter with indirect connection ...................................................24 Figure 15: RS-485 terminals with terminating resistor switch ........................................................................................25 Figure 16: Terminating-resistor switch – positions 0 and 1............................................................................................26 Figure 17: Ethernet interface .......................................................................................................................................26 Figure 18: Pin numbering of RJ45 socket ....................................................................................................................27 Figure 19: Terminal block – I/O area – example ...........................................................................................................28 Figure 20: Terminal block – M-Bus area ......................................................................................................................30 Figure 21: Position of the terminal-cover-opening detector at one-phase meter.............................................................31 Figure 22: Position of the terminal-cover-opening detector at three-phase meter...........................................................31 Figure 23: U-I link access-protection slider ..................................................................................................................31 Figure 24: U-I link access-protection slider – sealing example ......................................................................................32 Figure 25: Terminal cover – example for three-phase meter .........................................................................................32 Figure 26: Terminal cover with attached meter hanger and connection-diagram label – example for three-phase meter .32 Figure 27: Position of the communication-module-cover opening detector ....................................................................33 Figure 28: Communication module cover .....................................................................................................................33 Figure 29: Positions of sealing points at AM550 one-phase meter ................................................................................34 Figure 30: Positions of sealing points at AM550 three-phase meter ..............................................................................34 Figure 31: Sealing sample ..........................................................................................................................................34 Figure 32: Example of sealed button ...........................................................................................................................35 Figure 33: Example of an AM550 three-phase meter nameplate (IEC) ..........................................................................36 Figure 34: Example of an AM550 one-phase meter nameplate (MID) ...........................................................................37 Figure 35: Example of an AM550 three-phase meter nameplate (MID) .........................................................................38 Figure 36: Label for CT ratio .......................................................................................................................................39 Figure 37: All segments of LCD display .......................................................................................................................40 Figure 38: Show full OBIS code attribute in Display configuration object .......................................................................43 Figure 39: Example of wrong Neutral-Phase connection indication text on display ........................................................48 Figure 40: Connect text on display ..............................................................................................................................49 Figure 41: Metrological LED on front plate of AM550 meters (left one-phase meter, right three-phase meter)) ...............51 Figure 42: Scroll button, switching device button and switching device status LED ........................................................51 Figure 43: P* interface (left: FEM1, right: FEM2) ..........................................................................................................52 Figure 44: Position of the communication module in the meter (example for GPRS module)..........................................53 Figure 45: P1 communication module..........................................................................................................................53 Figure 46: P1 module fitted in communication module cover ........................................................................................53 Figure 47: P1 socket (left: closed, right: opened)..........................................................................................................54 Figure 48: Different set energy scaler (example), where display format for energy is WP=80 .........................................60 Figure 49: Read-only scaler in energy object (example) ...............................................................................................60 Figure 50: Optical interface .........................................................................................................................................63 Figure 51: Optical probe..............................................................................................................................................64 Figure 52: M-Bus connection for wired M-Bus devices .................................................................................................65 Figure 53: RS-485 Master – Slave parallel connection diagram ....................................................................................67 Figure 54: Terminal-cover-opening detector position on one-phase meter ....................................................................75 Figure 55: Terminal-cover-opening detector position on three-phase meter ..................................................................75 Figure 56: Communication-module-cover opening detector ..........................................................................................75 V3.00 – English

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AM550 User manual Figure 57: Manually executing MDI reset / End of billing period ....................................................................................79 Figure 58: Event handling ...........................................................................................................................................81 Figure 59: Example of Standard event log buffer content .............................................................................................84 Figure 60: Example of Fraud detection log buffer content .............................................................................................84 Figure 61: Example of Disconnector control log buffer content .....................................................................................85 Figure 62: Example of Power quality log buffer content ................................................................................................85 Figure 63: Example of Communication event log buffer content....................................................................................86 Figure 64: Example of Communication details log buffer content ..................................................................................86 Figure 65: Example of Security event log buffer content ...............................................................................................88 Figure 66: Example of image activation log buffer content ............................................................................................90 Figure 67: Example of Power failure event log buffer content .......................................................................................90 Figure 68: Example of Certification data log buffer content ...........................................................................................91 Figure 69: Alarm reporting process............................................................................................................................ 110 Figure 70: Graphical tariff program ............................................................................................................................ 115 Figure 71: Tariff external input connections ............................................................................................................... 116 Figure 72: Disconnect state control diagram .............................................................................................................. 121 Figure 73: ConnEct on the display ............................................................................................................................. 124 Figure 74: EntEr on the display ................................................................................................................................. 124 Figure 75: dISconn on the display ............................................................................................................................. 124 Figure 76: Limiter diagram ........................................................................................................................................ 125 Figure 77: Enabled Mirror objects in System options object ........................................................................................... 127 Figure 78: Different approaches/options to FW Upgrade ............................................................................................ 132 Figure 79: Properly prepared cables .......................................................................................................................... 134 Figure 80: Power cables preparation for AM550 meter ............................................................................................... 134 Figure 81: Properly inserting and fixing cable with 2.5 mm 2 wire cross-section in main terminal ................................... 135 Figure 82: Terminal reducing insert (option) ............................................................................................................... 136 Figure 83: Installation of terminal reducing insert ....................................................................................................... 136 Figure 84: RJ45 male connector (example of shielded cable) and pin designation ...................................................... 137 Figure 85: P1 port – RJ12 female socket ................................................................................................................... 137 Figure 86: RJ12 male connector and pin designation ................................................................................................. 138 Figure 87: Bottom side of the communication module with SIM-card colder (example of hinged type of the holder) ...... 139 Figure 88: Example of a SIM card ............................................................................................................................. 139 Figure 89: Removing communication module – step 1 ............................................................................................... 140 Figure 90: Removing communication module – step 2 ............................................................................................... 140 Figure 91: Removing communication module – step 3 ............................................................................................... 141 Figure 92: Removing communication module – step 4 ............................................................................................... 141 Figure 93: P1 module – snap-fit elements in the inner side of the communication module cover .................................. 142 Figure 94: P1 module removing procedure ................................................................................................................ 142 Figure 95: Removed P1 module ................................................................................................................................ 143 Figure 96: P1 “dummy” module ................................................................................................................................. 143 Figure 97: P1 “dummy” module inserted in the module cover ..................................................................................... 143

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INDEX OF TABLES Table 1: Description of the AM550 type designation .....................................................................................................11 Table 2: Terminal data for one-phase meter – DIN connection .....................................................................................21 Table 3: Terminal data for one-phase meter – BS connection.......................................................................................22 Table 4: Terminal data of three-phase meter with direct connection..............................................................................23 Table 5: Terminal data of three-phase meter with indirect connection ...........................................................................24 Table 6: Terminal data of RS-485 interface..................................................................................................................25 Table 7: Electrical characteristics of RS-485 ................................................................................................................25 Table 8: RS-485 terminals ..........................................................................................................................................25 Table 9: RS-485 switch position ..................................................................................................................................26 Table 10: RJ45 socket pin assignment ........................................................................................................................27 Table 11: Ethernet LED diodes ...................................................................................................................................27 Table 12: Terminal data of input terminals ...................................................................................................................28 Table 13: Terminal data of output terminals .................................................................................................................28 Table 14: Inputs – electrical characteristics..................................................................................................................29 Table 15: Outputs – electrical characteristics ...............................................................................................................29 Table 16: Terminal data of M-Bus................................................................................................................................30 Table 17: Electrical characteristics of M-Bus ................................................................................................................30 Table 18: U-I link access protection slider – position meaning ......................................................................................31 Table 19: LCD – meaning of available cursors .............................................................................................................42 Table 20: OBIS Code Abbreviation Characters ............................................................................................................44 Table 21: Usage of the Scroll button in the reduced console menu type........................................................................45 Table 22: Usage of the Switching device button regardless of console mode ................................................................45 Table 23: Usage of the Scroll button in the normal console menu type .........................................................................45 Table 24: Examples of current transformer ratio values ................................................................................................56 Table 25: Default values for the energy output constants .............................................................................................57 Table 27: Source energy valid values, their meaning and the default value ...................................................................57 Table 28: Energy scaler – value of object meter and energy register solution................................................................59 Table 29: Structure of unencrypted part of the message, using encryption mode 0 .......................................................65 Table 30: Structure of encrypted part of the message, using encryption mode 5 ...........................................................66 Table 31: Structure of encrypted part of the message, using encryption mode 9 ...........................................................66 Table 32: IEC Local Port COSEM Object .....................................................................................................................67 Table 33: IEC HDLC COSEM Object ...........................................................................................................................68 Table 34: Ethernet configuration..................................................................................................................................70 Table 35: Ethernet filter ...............................................................................................................................................70 Table 36: IPv4 setup ...................................................................................................................................................71 Table 37: Ethernet status (0-0:128.20.52) ....................................................................................................................72 Table 38: All supported profiles in meter ......................................................................................................................76 Table 39: Profile status register notifications ................................................................................................................78 Table 40: Billing profile – action list of Script 1 and of Script 2 ......................................................................................79 Table 41: Event code objects ......................................................................................................................................82 Table 42: Event code objects COSEM object ...............................................................................................................82 Table 43: Event log objects .........................................................................................................................................83 Table 44: Security Event Counters COSEM Objects ....................................................................................................89 Table 44: List of events ............................................................................................................................................. 105 Table 46: Error IDIS Register COSEM Object ............................................................................................................ 107 Table 47: IDIS Error Codes ....................................................................................................................................... 108 Table 48: Error code interpretation ............................................................................................................................ 109 Table 49: Bits of Alarm Register 1 ............................................................................................................................. 111 Table 50: Bits of Alarm Register 2 ............................................................................................................................. 112 Table 51: Alarm Filter 1 COSEM Object .................................................................................................................... 113 Table 52: Alarm Filter 2 COSEM Object .................................................................................................................... 113 Table 53: Alarm Register 1 COSEM Object ............................................................................................................... 113 Table 54: Alarm Register 2 COSEM Object ............................................................................................................... 113 Table 55: Under and Over Voltage Detection Model ................................................................................................... 119 Table 56: Disconnect transitions................................................................................................................................ 121 Table 57: Disconnect control object 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AM550 User manual Table 58: Disconnect control modes .......................................................................................................................... 123 Table 59: AM550 counters ........................................................................................................................................ 126 Table 60: Security suite ............................................................................................................................................ 129 Table 61: List of available Roles ................................................................................................................................ 130 Table 62: List of available functions for Roles ............................................................................................................ 130 Table 63: Image types .............................................................................................................................................. 132 Table 64: COSEM SAP assignment example ............................................................................................................ 133 Table 65: COSEM Application Associations ............................................................................................................... 133 Table 66: RJ45 pin assignment of mail connector ...................................................................................................... 137 Table 67: Pin designation of RJ12 connector (for passive P1) .................................................................................... 138

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1. SAFETY INFORMATION Safety information in this document is described with the following pictograms: DANGER: possibly dangerous situation, which could result in severe physical injury or fatality –attention to high-risk hazards WARNING: attention to medium-risk hazards CAUTION: possibly dangerous situation, which could result in minor physical injury or material damage - attention to low-risk hazards Operating instructions, general details, and other useful information All safety information in this document describes the type and source of danger, its possible consequences, and measures to avoid danger.

1.1. Responsibilities The owner of the meter is responsible for assuring that all authorized persons, who work with the meter, read and understand the parts of this document that explain safe handling with the meter. The personnel must be sufficiently qualified for the work that will be performed. The installation personnel must possess the required electro technical knowledge and skills, and must be authorized by the utility to perform the installation procedure. The personnel must strictly follow safety regulations and operating instructions, written in the individual chapters in this document. The owner of the meter responds specially for the protection of the persons, for prevention of material damage, and for professional training of personnel.

1.2. Safety instructions 1.2.1. Handling and mounting At the beginning of installation at the metering point, the meter should be carefully taken out of the box, in which is packed. This should prevent the meter from falling as well as any other external or internal damage to the device and personal injuries. If such an incident occurs despite all precautions, the meter should not be installed at the metering point to avoid different hazards. In such a case, the meter needs to be sent back to the manufacturer for examination and testing.

CAUTION The edges of the seals, sealing wires and edges under (removed) terminal/module cover are sharp!

CAUTION The temperature of the terminal block of the connected and operating meter may rise; therefore, the temperature of the terminal/module cover may rise as well.

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WARNING In a case the device is used under extremely hot climatic conditions, it is possible that temperature of the device’s surface, which is close to the mounting surfaces, exceed 90° C. In this case, it is danger of ignition.

DANGER Penetration into internals of the meter is strictly forbidden. It is dangerous for life.

DANGER In a case of any damage inside the meter (fire, explosion...), do not open the meter.

CAUTION The meter may be used only for the purpose of measurement, for which it was produced. Any misuse of the meter will lead to potential hazards.

WARNING Safety measures should be observed at all times. Do not break the seals or open the meter at any time!

It must be consulted in all cases where symbol is marked in order to find out the nature of the potential hazards and any actions, which have to be taken to avoid them. The meter installation procedure is described in this User manual. For safety reasons, the following instructions should be followed.

See the complete User manual for detailed technical features of AM550 meter and its intended use.

Only a properly connected meter can measure correctly! Every connection error could result in a financial loss for the power company!

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1.2.2. Meter installation procedure

DANGER The AM550 electricity meter is a device connected into the electricity network. Any unauthorized manipulation of the device is dangerous for life and prohibited according to the applicable legislation. Any attempt to damage the seals as well as any unauthorized opening of the terminal or meter cover is strictly forbidden. Installation companies shall implement a training policy that ensures that all installers are adequately trained, understand risk and safety issues, and possess the relevant skills before they commence operational duties. The installer will need to recognise and understand different metering installations, meter types and various equipment associated with those installations applicable to the successful installation of the electricity meter.

CAUTION On the supply side of the installation site, the installer must provide environment according to requirements for OVC III or lower, so proper overvoltage protection must be installed (max. overvoltage < 4 kV). The protection must be done according to local regulation. The installer must provide overcurrent protection on the supply side of installation. The cut-off current of protection must not be higher than the maximal meter current (Imax). The current capability of overcurrent protection must be according to UC rating of the meter equipment (only for direct connected meter). The overcurrent protection must be done according to local regulation as well. The installer is responsible for coordinating the rating and the characteristics of the supply side overcurrent protection devices.

WARNING In a case that local generation of energy is present, supply side protection shall comprise both: protection from supply from the distribution network and protection from supply from local generation.

The installer must consult and comply with local regulations and read the installation instructions written in this User manual before installation. This User manual provides the instructions for installing AM550 meters. The document provides a short overview of the meter, details of device installation and set-up, installation considerations, and health and safety considerations. The installer will be considered as a public face by both the power company and its customers. The installer shall adopt the highest standards of behaviour and be respectful to clients and members of the public. Before the beginning of the installation procedure, it should be checked if the metering point is correctly prepared for meter installation. The metering point must always be left clean and in order. The work location shall be defined and clearly marked. Adequate working space as well as means of access and lighting shall be provided at all parts of an electrical installation on, with, or near which any work activity is to be carried out. Where it is necessary, safe access to the work location shall be clearly marked. The metering point must not be exposed to running water or fire. Meter installation must not be performed by unauthorised and untrained personnel. Such persons are not allowed to cut the seals and open the terminal or meter cover because of contact with the live parts of the meter is dangerous for life.

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DANGER Opening the terminal, module or meter cover is dangerous for life because there are live parts inside. Installation personnel must possess the required electrical knowledge and skills, and must be authorised by the utility to perform the installation procedure. The installer is obligated to perform the installation procedure in accordance with the national legislation and internal norms of the utility. National legislation can set out the minimum age and the competence criteria for installers. In a case, there are no national requirements defined, the following criteria shall be used by assessing the competence of installers: knowledge of electricity, experiences on electrical work, understanding of the installation procedures, practical experience of that work, understanding the hazards, which can arise during the work and the precautions to be observed, ability to recognize at all times whether it is safe to continue working. According to the basic principles, either the nominated person in control of the electrical installation or the nominated person in control of the work activity shall ensure that specific and detailed instructions are given to the personnel carrying out the work before starting and on completion of the work. Before starting work, the nominated person in control of the work activity shall give notification to the nominated person in control of the electrical installation, of the nature, place, and consequences to the electrical installation of the intended work.

CAUTION It is expected that the installer fully understands the risks and safety issues involved in electrical installations. The installer shall be aware at all times of the potential hazard of electrical shock and shall exercise due caution in completing the task! Tools, equipment, and devices shall comply with the requirements of relevant National or International Standards where these exist. Tools, equipment, and devices shall be used in accordance with the instructions and/or guidance provided by the manufacturer or supplier. Any tools, equipment, and devices provided for the purpose of safe operation of, or work on, with, or near electrical installations shall be suitable for that use, be maintained, and be properly used. Personnel shall wear clothing suitable for the locations and conditions where they are working. This could include the use of close-fitting clothing or additional PPE (personal protective equipment).

CAUTION The installer must be correctly equipped with personal protection equipment (PPE) and use the appropriate tools at all times during the installation. Working procedures are divided into three different procedures: dead working, live working, and working in the vicinity of live parts. All these procedures are based on the use of protective measures against electric shock and/or the effects of short-circuits and arcing.

The installer must be informed whether the national legislation permits the work on the installation under voltage – live work, and must follow the rules of legislation.

Depending on the kind of work, the personnel working in such conditions shall be instructed or skilled. Live working requires the use of specific procedures. Instructions shall be given how to maintain tools, equipment, and devices in good working order and how to verify them before working. This subclause deals with the essential requirements (“the five safety or golden rules”) for ensuring that the electrical installation at the work location is dead and secure for the duration of the work. V3.00 – English

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This shall require clear identification of the work location. After the respective electrical installations have been identified, the following five essential requirements shall be undertaken in the specified order unless there are essential reasons for doing otherwise: disconnect completely (1.), secure against re-connection (2.), verify that the installation is dead (3.), carry out earthing and short-circuiting (4.), and provide protection against adjacent live parts (5.).

CAUTION Do not attempt to install the meter before you have isolated the installation site from the network and any other source of hazardous live voltage (local generation).

DANGER The relevant preliminary fuses must be removed before making any modifications to the installation, and kept safe until completing the work to prevent the unnoticed reinsertion.

DANGER Secondary circuit of current transformer must not be opened when current is flowing in the primary circuit. This would produce a dangerous voltage of several thousand volts at the terminals and the isolation of the transformer would be destroyed.

DANGER Connecting the meter into the network under voltage is dangerous for life so the conductors at the metering point must not be connected to any voltage source during the connection procedure. The meter connection procedure may only be performed by well-trained and adequately authorized personnel.

CAUTION Only one wire or ferrule may be connected in one terminal. Otherwise, the terminal could be damaged or the contact could not be made properly.

CAUTION Do not use those types of cable, which are not prescribed for the installation site and the power requirements!

DANGER The isolation of the connecting cable must extend over the completely visible part of the cable. There must be no further bare part of the cable visible above the terminal edge. Touching live parts is dangerous for life. The stripped part of the connecting wire should be shortened if necessary.

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CAUTION At the end of installation at the metering point, no cable should stay unconnected or hanging freely from the metering point. Module cover and terminal cover must be closed and sealed. The meter has to be mounted on a smooth vertical surface and fixed at 2 or 3 points with screws using the proper torque (the meter has two attachment holes and, optionally, a top hanger). The meter is intended for mounting at an indoor metering point, in a meter cabinet, secured against the undesired access of unauthorized persons. Only scroll push button may be accessible from the outside. Do not expose meter surface to very high temperatures even though the surface is made of non-flammable plastics to prevent fire. Electrical connection: mounting cables must be properly dimensioned and of proper shape. They must be mounted using the proper torque. The meter should be connected according to the meter connection diagram that is attached to the inner side of the meter terminal cover. Screws on the current terminal must be tightened with proper torque.

CAUTION If it is possible to install the meter without isolation from the network, i.e. on live network, then appropriate instructions and safety warnings shall be provided.

CAUTION Specific aspects and safety hazards related to external voltage and current transformers, auxiliary supplies, and local generation shall be covered.

DANGER The preliminary fuses and/or voltage arresters must be re-inserted before commissioning and functional check of the meter. Seals on the meter have to be checked at the end of the installation procedure so that the consumer (final customer) cannot come into contact with live parts of the meter.

DANGER If the terminal cover is not screwed tight, there exists a danger of contact with the connection terminals. Contact with live parts of the meter is dangerous for life.

WARNING The open position (means disconnected) of the supply control switch (SCS) or auxiliary control switch (ACS) does not provide isolation from the mains network.

CAUTION For safety reasons, place the terminal cover immediately after the installation procedure and fix it with fixing screws!

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DANGER Switch on the power. Beware of the risk of electric shock at all times!

The functional check requires voltage to be applied and load applied to all phases. Determine first the energy flow direction. If no main voltage is present, commissioning and functional check must be performed at a later date.

1.2.3. Meter maintenance No maintenance is required during the meter’s lifetime. The implemented metering technique, built-in components, and manufacturing procedures ensure high long-term stability of meters. Therefore, no recalibration is required during the entire lifetime of the meter.

In the case service of the meter is needed, the requirements from the meter installation procedure must be observed and followed. Cleaning of the meter is allowed only with a soft dry cloth. Cleaning is allowed only in upper part of the meter – in the region of the LCD. Cleaning is forbidden in the region of terminal cover, where cables are connected to the meter. Cleaning can be performed only by the personnel responsible for meter maintenance.

CAUTION Never clean soiled meters under running water, or with high-pressure devices. Penetrating water can cause short circuits. A damp cleaning cloth is sufficient to remove normal dirt such as dust. If the meter is more heavily soiled, it should be dismounted and sent to the responsible service or repair centre. Visible signs of fraud attempt (mechanical damages, presence of a liquid, etc.) must be regularly checked. The quality of seals and the state of the terminals and connecting cables must be regularly checked. If there exists a suspicion of incorrect operation of the meter, the local utility must be informed immediately.

DANGER Breaking the seals and removing the terminal cover, meter cover or module cover will lead to potential hazards because there are live electrical parts inside.

After the end of the meter’s lifetime, the meter should be treated according to the Waste Electric and Electronic (WEEE) Directive!

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2. ENERGY METERING WITH AM550 The AM550 meters are members of the fourth generation of Iskraemeco electronic one- and three-phase meters for a deregulated market of electrical energy. They are designed for up to eight-tariff measuring of active and reactive energy, in one or two energy flow directions. The meters measure consumed energy in one-phase two-wire and three-phase four-wire networks for direct connection. Meters can be connected directly or indirectly through measurement transformers. Common functional properties of AM550 meters: 

Time-of-use measurement of active energy (in up to 8 tariffs);



Load-profile registration (E-meter, 4 sub-meters);

  

Segment LCD display; Internal real-time clock, Switching device;



Two push buttons;



Optical port (IEC 62056-21 and IEC 62056-46 standards) for local meter programming and data downloading (P0 interface);



Exchangeable P1 port for sending data to in-house display (P1 interface);

  

Exchangeable or integrated communication modules for remote two way communication (P3 interface); M-Bus interface for reading up to 4 other (heat, gas, water) meters (P2 interface); Magnetic field detector for detecting external magnetic influence (manipulation);



Meter-cover, terminal-cover, and communication-module-cover opening detector.

Figure 1: Smart metering system

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3. METER INTRODUCTION The AM550 meter is developed according to IDIS Package 2 specifications. Measuring and technical characteristics of: 

direct connected meters comply with the IEC (International Electro technical Commission) 62052-11 and IEC 62053-21 international standards for electronic active energy meters, class 1 and 2, and reactive energy meters, classes 2 or 3 in compliance with IEC 62053-23 as well as a standard for time switches IEC 62052-21.



indirect connected meters (current transformer) comply with following international standards: - IEC 62052-11, - IEC 62052-21 for time switches, - IEC 62053-21 for electronic active energy meters, class 1 and 2, - IEC 62053-22 for electronic active energy meters, class 0,5 S, - IEC 62053-23 for reactive energy meters, classes 2 or 3, - IEC 62053-24 for reactive energy meters, class 1.

Meters are designed and manufactured in compliance with the standards and ISO 9001 (International Organization for Standardization) as well as more severe Iskraemeco standards. The meter utilizes the DLMS/COSEM communication protocol in compliance with IEC 62056-5-3, IEC 620566-1, IEC 62056-6-2, IEC 62056-4-7, IEC 62056-7-6, and IEC 62056-21 standards.

3.1. Standards and references DIN 43857-1 DIN 43857-2 DIN 43863-3 EN 13757-2 EN 13757-3

EN 50160 EN 50470-1 EN 50470-3 IEC 60664-1:2007 IEC-61000-4-6

IEC 60068-2-75 IEC 61000-4-2 IEC 61000-4-3 IEC 61000-4-4 IEC 61000-4-5

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Elektrizitätszähler in Isolierstoffgehäusen für unmittelbaren Anschluß bis 60A Grenzstromm; Hauptmaße für Wechselstromzähler Elektrizitätszähler in Isolierstoffgehäusen für unmittelbaren Anschluß bis 60A Grenzstromm; Hauptmaße für Drehstromzähler Elektrizitätszähler; Tarifgeräte als Zusatzeinrichtung zum Elektrizitätszähler EDIS (Energie-Daten-Identifikations-System) Communication systems for meters and remote reading of meters Part 2: Physical and link Layer Communication systems for meters and remote reading of meters Part 3: Dedicated application Layer Voltage characteristics of electricity supplied by public electricity networks Electricity metering equipment (a.c.) - Part 1: General requirements, tests and test conditions Metering equipment (class indexes A, B and C) Electricity metering equipment (a.c.) - Part 3: Particular requirements - Static meters for active energy (class indexes A, B and C) Insulation coordination for equipment within low-voltage systems - Part 1: Principles, requirements and tests Electromagnetic compatibility (EMC) - Part 4-6: Testing and measurement techniques- Immunity to conducted disturbances, induced by radio-frequency fields Environmental testing - Part 2: Tests - Test Eh: Hammer tests Electromagnetic compatibility (EMC) - Part 4-2: Testing and measurement techniques- Electrostatic discharge immunity test Electromagnetic compatibility (EMC) - Part 4-3: Testing and measurement techniques-Radiated, radio-frequency, electromagnetic field immunity test Electromagnetic compatibility (EMC) - Part 4-4: Testing and measurement techniques- Electrical fast transient/burst immunity test Electromagnetic compatibility (EMC) - Part 4-5: Testing and measurement techniques- Surge immunity test 9/184

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IEC 62052-11 IEC 62052-21 IEC 62053-21 IEC 62053-22 IEC 62053-23 IEC 62053-24 IEC 62054-21 IEC 62056-21 IEC 62056-7-6 IEC 62056-4-7 IEC 62056-5-3 IEC 62056-6-1 IEC 62056-6-2 IEC 62056-46 IEC 61334-4-32

Electricity metering equipment (AC.): General requirements, tests and test conditions - Metering equipment Electricity metering equipment (AC.) General requirements, tests and test conditions - Tariff and load control equipment Electricity metering equipment; Particular requirements; Electronic meters for active energy (classes 1 and 2) Electricity metering equipment; Particular requirements; Electronic meters for active energy (classes 0,2S and 0,5S) Electricity metering equipment (AC.); Particular requirements; Static meters for reactive energy (classes 2 and 3) Electricity metering equipment (AC.); Particular requirements; Static meters for reactive energy at fundamental frequency (classes 0,5S,1S and 1) Electricity metering (ax.) – Tariff and load control - Particular requirements for time switches Data exchange for meter reading, tariff and load control - Direct local connection (3rd edition of IEC 61107) Electricity metering data exchange - The DLMS/COSEM suite - Part 7-6: The 3-layer, connection-oriented HDLC based communication profile Electricity metering data exchange - The DLMS/COSEM suite - Part 4-7: DLMS/COSEM transport layer for IP networks Electricity metering data exchange - The DLMS/COSEM suite - Part 5-3: DLMS/COSEM application layer Electricity metering data exchange - The DLMS/COSEM suite - Part 6-1: Object Identification System (OBIS) Electricity metering data exchange - The DLMS/COSEM suite - Part 6-2: COSEM interface classes Electricity metering; Data exchange for meter reading, tariff and load control; Part 46: Data link layer using HDLC-Protocol Distribution automation using distribution line carrier systems - Data communication protocols Data link layer - Logical link control (LLC)

IEC 61334-4-512

Distribution automation using distribution line carrier systems - Data communication protocols System management using profile 61334-5-1 – Management Information Base (MIB) TP CLC/TR 50579 2012 - Severity levels, immunity requirements and test methods for conducted disturbances in the frequency range 2 kHz - 150 kHz (CLC/TR 50579:2012) IEC 60529 Degrees of protection provided by enclosures (IP code) ISO/IEC 8802.2 Information technology - Telecommunications and information exchange between systems – Local and metropolitan area networks - Specific requirements; Logical link control RFC 1321 MD5 (Message Digest algorithm 5) Message-Digest Algorithm RFC 1332 The Internet Protocol Control Protocol (IPCP) RFC 1700 Assigned Numbers RFC 3241 Robust Header Compression FIPS PUB 180-1 Secure Hash Standard (SHA-1), 1993 DLMS UA 1000-2 Ed.8, Green Book, DLMS/COSEM Architecture and Protocols 2014 DLMS UA 1000-1 Blue Book, COSEM Identification System and Interface Classes Ed.12, 2014 DLMS UA 1001-1 Ed.5, Yellow Book, DLMS/COSEM Conformance Testing Process 2015 DLMS UA 1002: Ed.1, White Book, COSEM Glossary of Terms 2003 DSRM5 P1 Dutch Smart Meter Requirements, 2016 - 2020 SMR5 Meters – P1 companion standard Specification VDEW – specification for “Electronic Meters with load curve“ Version 2.1.2 7th November 2003 IP (Internet Protocol) Header Compression over PPP 3GPP TS 27.007 3GPP TS 27.010 3GPP TS 23.040

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3.2. AM550 meter type designation Meter type designation can be found on the meter nameplate on the front side of the meter (see chapter 4.7. Nameplate). In Table 1, explanation of the AM550 type designation can be found. Example: AM550-ED0.11 A

M

5 50

-

E D0

.

1

1

Program AM: Advanced Metering Series 5: SMART Family 50: Standard SMART meter Separator: - (minus) Number of phases, Number of measurement elements and wires E: Single phase electronic meter 1 measurement element 2 wires T: Three phase electronic meter 3 measurement elements 4 wires Current range, standard and connection type B2: Current range up to 100 A, BS, Direct connection D0: Current range up to 60 A, DIN, Direct connection D1: Current range up to 85 A, DIN, Direct connection D2: Current range up to 100 A, DIN, Direct connection D3: Current range up to 120 A, DIN, Direct connection T1: Current range up to 6 A, DIN, Indirect connection (CT/VT) T2: Current range up to 10A, DIN, Indirect connection (CT/VT) Separator: . (dot) * Generation * 0..9: Generation of the device Version within the generation * 1..9: Version related to re-approval

* Type designation of the 1st-generation product is written without generation (and version within generation). Table 1: Description of the AM550 type designation

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3.3. Meter appearance 3.3.1. One-phase meter appearance

sliding track for antenna coupler communicationmodule cover

P1 port

modul- cover sealing screw

module-cover sealing screw

liquid crystal display (LCD)

accuracy test LED for active energy

IR optical interface

scroll (upper) and switching device (lower) button switching-device status LED

terminal-cover sealing screw

terminal-cover sealing screw

terminal cover

Figure 2: Appearance of AM550 one-phase meter (example)

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3.3.2. Three-phase meter appearance

sliding track for antenna coupler communicationmodule cover

P1 port

module cover sealing screw

module cover sealing screw

accuracy test LED for active energy

liquid crystal display (LCD)

scroll (upper) and switching device (lower) button

IR optical interface

switching device status LED

terminal cover sealing screw

terminal cover sealing screw

terminal cover

Figure 3: Appearance of AM550 three-phase meter (example)

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3.4. Main meter properties 









Direct connected meter of: - active energy accuracy class A or B (EN 50470-3), class 2 or 1 (IEC 62053-21), - reactive energy accuracy class 2 (IEC 62053-23) Indirect connected meter (current transformer) of: - active energy accuracy class A, B or C (EN 50470-3), class 2 or 1 (IEC 62053-21), class 0.5 S (IEC 62053-22), - reactive energy accuracy class 2 or 3 (IEC 62053-23), class 1 (IEC 62053-24) Modes of energy measurement and registration: - one-phase meters: for two-way energy flow direction; - three-phase meters: for two-way energy flow direction, three-phase energy is a vector or arithmetical sum of energies registered in all phases. Meter connection: - direct or indirect connection of the meter; - 3-phase 4-wire - the three-phase meter can function as a single-phase or a two-phase meter as well. Meter quality: - due to high accuracy and long term stability of metering elements, no meter re-calibration over its life-time is required; - high meter reliability; - high immunity to EMC.



Additional meter functions: - measurement and registration of under- and over-voltage; - triggering of alarms and their transmitting via the P3 interface; - time-of-use registration (up to 8 tariffs); - load-profile recording.



Communication channels: - WAN interface (P3 port) for remote access; - infrared optical port (P0 port ; IEC 62056-21 or DLMS) for local meter programming and data downloading; - built-in wired M-Bus communication interface (P2 port); - modular consumer interface (P1 port).



Segment LCD display.



Data display modes: - automatic cyclic data display with display time of 5 seconds; - manual data display mode (by pressing the Scroll push-button); - service mode (mode with added objects for service personnel). Metrological LED: red (or other, depending on customer’s decision)

 

Communication protocols: - optical port: IEC 62056-21, mode E or DLMS (in compliance with IEC 62056-7-6); - DLMS/COSEM application layer: IEC 62056-5-3; - OBIS identification system: IEC 62056-6-1; - COSEM organization of data: IEC 62056-6-2; - M-Bus: EN 13757-2 and EN 13757-3; - RS-485: IEC 62056–21 (IEC 1107), IEC 62056-46 (DLMS UA) - Ethernet (IEEE 802.3u): TCP/UDP, IPv4, IEC 62056-46 (DLMS UA).



Programming of the meter, as well as FW upgrade, can be done locally (via the optical port) or remotely, in compliance with the predefined security levels.



Detection of meter and terminal-block cover and communication-module cover removal.



Simple and fast meter installation.

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

  

Current terminals: - assured good contact with current conductors regardless of their design and material; - do not damage conductors. Voltage terminals: - internal and/or external connection. U-I calibration link access protection slider, which can be sealable. Compact plastic meter case: - made of high quality fire-extinguishing UV stabilized material that can be recycled; - IP54 protection against dust and water penetration (by IEC 60529).

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3.5. Connection diagram A connection diagram shows the correct connection of a device into the electrical network. Each meter has the appropriate connection diagram attached to the inner side of the meter terminal cover. To each connection diagram, corresponding identification number (IS number) is assigned and it is also printed on the nameplate (see chapter 4.7. Nameplate). Connection diagrams of the AM550 meters are shown in Figure 4, Figure 5 (one-phase meter), and Figure 6 (three-phase meter).

3.5.1. One-phase meter connection diagram 3.5.1.1. DIN connection

Figure 4: Connection diagram of the AM550 – one-phase meter – DIN connection

3.5.1.2. BS connection

Figure 5: Connection diagram of the AM550 – one-phase meter – BS connection

NOTE For explanation of I/O groups, see chapter 4.2.2.2. Terminal block – I/O area.

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3.5.2. Three-phase meter connection diagram 3.5.2.1. Direct connected meter

Figure 6: Connection diagram of AM550 – direct connected three-phase meter

NOTE For explanation of I/O groups, see chapter 4.2.2.2. Terminal block – I/O area.

3.5.2.2. Indirect connected meter

Figure 7: Connection diagram of AM550 – indirect connected three-phase meter

NOTE For explanation of I/O groups, see chapter 4.2.2.2. Terminal block – I/O area.

NOTE The AM550-TT2 allows only a current transformer (CT) connection.

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4. METER CONSTRUCTION 4.1. Technical figures and dimensions 4.1.1. One-phase meter

Figure 8: Overall and fixing dimensions of the AM550 – one-phase meter (in mm)

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4.1.2. Three-phase meter 4.1.2.1. Three-phase meter with regular terminal cover

Figure 9: Overall and fixing dimensions of the AM550 three-phase meter with regular terminal cover (in mm).

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4.1.2.2. Three-phase meter with extended terminal cover

Figure 10: Overall and fixing dimensions of the AM550 three-phase meter with extended terminal cover (in mm).

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4.2. Terminal block Under the terminal cover of the AM550 meter, a terminal block is placed. The terminal block complies with the DIN 43857 or BS 7856 standard. It is made of self-extinguishing high quality polycarbonate. The terminal block provides:  Current and voltage terminals;  Other terminals;  Terminal-cover-opening detector;  U-I calibration link (only at three-phase meter).

4.2.1. Current and voltage terminals 4.2.1.1. One-phase meter current and voltage terminals 4.2.1.1.1. DIN connection I/O area *

communication area *

terminal-coveropening detector *

(1) L-in

(4) N-in

(3) L-out

M-Bus area *

(6) N-out

(5) N – optional

(2) L – optional * see corresponding upcoming chapter

Figure 11: Terminal block – example of one-phase meter with DIN connection

Terminal number Function

Reference voltage

Max. current

Diam. [mm] Note

Wire [mm2] *

Screw head type and size

Torque [N m]

D0: 60 A 8.5 current 4-25 Combi Pozidriv (2) + Slot 2.5 D1: 85 A D0: 60 A 3 L – out 230 V 8.5 current 4-25 Combi Pozidriv (2) + Slot 2.5 D1: 85 A D0: – 4 N – in – 8.5 neutral 4-25 Combi Pozidriv (2) + Slot 2.5 D1: – D0: – 6 N – out – 8.5 neutral 4-25 Combi Pozidriv (2) + Slot 2.5 D1: – 2 2 * Minimum cross section of wire shall be according to standards and it is 2.5 mm . For specific installation with 2.5 mm cross-section wire, see chapter 12.1.1. Power (main) cables 1

L – in

230 V

Table 2: Terminal data for one-phase meter – DIN connection

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4.2.1.1.2. BS connection terminal-coveropening detector *

communication area *

(M) L-in

(M) N-in

I/O area *

M-Bus area *

(L) N-out

(L) L-out

Figure 12: Terminal block – example of one-phase meter with BS connection

Terminal number Function M M L L *

L – in N – in N – out L – out

Reference voltage

Max. current

Diam. [mm] Note

Wire [mm2] *

Screw head type and size

Torque [N m]

230 V – – 230 V

100 A – – 100 A

9.5 9.5 9.5 9.5

6-35 6-35 6-35 6-35

Combi Pozidriv (2) + Slot Combi Pozidriv (2) + Slot Combi Pozidriv (2) + Slot Combi Pozidriv (2) + Slot

2.8–3.0 2.8–3.0 2.8–3.0 2.8–3.0

current neutral neutral current

Minimum cross section of wire shall be according to standards and it is 2.5 mm2. For specific installation with 2.5 mm2 cross-section wire, see chapter 12.1.1. Power (main) cables

Table 3: Terminal data for one-phase meter – BS connection

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4.2.1.2. Three-phase meter current and voltage terminals 4.2.1.2.1. Direct connected meter communication area *

Aux Voltage termi- (1) nals L and N L1-in

(3) L1-out

(4) L2-in

I/O area *

(7) L3-in

(6) L2-out

(9) L3-out

(10) N-in

M-Bus area *

(12) N-out

terminal-cover-opening detector *

* see corresponding upcoming chapter Figure 13: Terminal block – example of a three-phase meter with direct connection

Terminal number 1

3

4

6

7

9

10

12 2 11

Reference Max. voltage current D0: 60 A D1: 85 A L1 – in 230 V D2: 100 A D3: 120 A D0: 60 A D1: 85 A L1 – out 230 V D2: 100 A D3: 120 A D0: 60 A D1: 85 A L2 – in 230 V D2: 100 A D3: 120 A D0: 60 A D1: 85 A L2 – out 230 V D2: 100 A D3: 120 A D0: 60 A D1: 85 A L3 – in 230 V D2: 100 A D3: 120 A D0: 60 A D1: 85 A L3 – out 230 V D2: 100 A D3: 120 A D0: – D1: – N – in D2: – D3: – D0: – D1: – N – out D2: – D3: – Aux Voltage L (optional) 230 V – Aux N (optional) – – Function

Diam. [mm]

Note

8.5

Wire [mm2] *

Torque [N m]

Combi Pozidriv (2) + Slot

2.8–3.0

Combi Pozidriv (2) + Slot

2.8–3.0

Combi Pozidriv (2) + Slot

2.8–3.0

Combi Pozidriv (2) + Slot

2.8–3.0

Combi Pozidriv (2) + Slot

2.8–3.0

Combi Pozidriv (2) + Slot

2.8–3.0

Combi Pozidriv (2) + Slot

2.8–3.0

Combi Pozidriv (2) + Slot

2.8–3.0

Combi Pozidriv (1) + Slot Combi Pozidriv (1) + Slot

0.6 0.6

4-25 current

9.5

6-35

8.5

4-25 current

9.5

6-35

8.5

4-25 current

9.5

6-35

8.5

4-25 current

9.5

6-35

8.5

4-25 current

9.5

6-35

8.5

4-25 current

9.5

6-35

8.5

4-25 neutral

9.5

6-35

8.5

4-25 neutral

9.5 3.0 3.0

Screw head type and size

6-35 voltage neutral

0.5-2.5 0.5-2.5

* Minimum cross section of wire shall be according to standards and it is 2.5 mm2. For specific installation with 2.5 mm2 cross-section wire, see chapter 12.1.1. Power (main) cables

Table 4: Terminal data of three-phase meter with direct connection V3.00 – English

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4.2.1.2.2. Indirect connected meter

I/O area *

communication area *

Aux Voltage terminals L and N

(1) IL1-in

(2) UL1

(3) (4) IL1-out IL2-in

(5) (6) (7) UL2 IL2-out IL3-in

(8) UL3

(9) IL3-out

M-Bus area *

(11) N-out

terminal-coveropening detector *

* see corresponding upcoming chapter Figure 14: Terminal block – example of a three-phase meter with indirect connection

Terminal number

Function

Reference Max. voltage current

Diam mm

Note

Wire mm2

Screw head Type and size

Torque Nm

1

IL1 – in

–

1(10) A

5.0

current

1.5-6

Combi Pozidriv (1) + Slot

1.2

2

UL1

230 V

–

5.0

voltage

1.5-6

Combi Pozidriv (1) + Slot

1.2

3

IL1 – out

–

1(10) A

5.0

current

1.5-6

Combi Pozidriv (1) + Slot

1.2

4

IL2 – in

–

1(10) A

5.0

current

1.5-6

Combi Pozidriv (1) + Slot

1.2

5

UL2

230 V

–

5.0

voltage

1.5-6

Combi Pozidriv (1) + Slot

1.2

6

IL2 – out

–

1(10) A

5.0

current

1.5-6

Combi Pozidriv (1) + Slot

1.2

7

IL3 – in

–

1(10) A

5.0

current

1.5-6

Combi Pozidriv (1) + Slot

1.2

8

UL3

230 V

–

5.0

voltage

1.5-6

Combi Pozidriv (1) + Slot

1.2

9

IL3 – out

–

1(10) A

5.0

current

1.5-6

Combi Pozidriv (1) + Slot

1.2

11

N

–

–

5.0

neutral

1.5-6

Combi Pozidriv (1) + Slot

1.2

2

Aux voltage L (optional) 230 V

–

3.0

voltage

0.5-2.5

Combi Pozidriv (1) + Slot

0.6

11

Aux N (optional)

–

3.0

neutral

0.5-2.5

Combi Pozidriv (1) + Slot

0.6

–

Table 5: Terminal data of three-phase meter with indirect connection

NOTE The AM550-TT2 allows only a current transformer (CT) connection.

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4.2.2. Other terminals (options) Other terminals are chosen by customers as an option. They are placed on top of the (one- and three-phase meter) terminal block (see Figure 11, Figure 12, and Figure 13) and arranged in the following areas: 

communication area,

 

input/output area, M-Bus area.

4.2.2.1. Terminal block – communication area 4.2.2.1.1. RS-485 (option) RS-485 communication interface enables communication with external communication devices. It is integrated on the top of the terminal block in the communication area. The RS-485 consists of 5 terminals (two of them are doubled terminals – parallel – for easier connection between several meters) and a switch, which enables termination of the last meter in RS-485 network with 120 Ω. (See Figure 15, Table 8, and Table 9.)

Figure 15: RS-485 terminals with terminating resistor switch

Terminal number 27 28 29

Diam. [mm] 2.5 2.5 2.5

Function RS-485 RS-485 RS-485

Note A GND B

Wire [mm2] * 0.5-2.5 0.5-2.5 0.5-2.5

Screw head type and size Regular (0.6×3.5) Regular (0.6×3.5) Regular (0.6×3.5)

Torque [N m] 0.6 0.6 0.6

* Minimum cross section of wire shall be according to standards. Table 6: Terminal data of RS-485 interface

Function Kind of a circuit Kind of voltage Nominal voltage Maximum voltage Nominal current Minimum current Continuous current Short time maximum current Burden Nominal and maximum frequency Insulation from other circuits Clamping of overvoltage

Communication NA DC NA NA NA NA NA NA RS-485 devices / Double insulation CAT III Zener diode

Table 7: Electrical characteristics of RS-485

Meaning of terminal markings is described in Table 8. Terminal name 27 28 29

Description A (data transmission) GND - Common B (data transmission)

Table 8: RS-485 terminals

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Figure 16: Terminating-resistor switch – positions 0 and 1

Meaning of the switch positions is described in Table 9. Switch position Description 0

RS-485 line is not terminated

1

RS-485 line is terminated with resistor 120 Ω

Using on  All slave devices, except the last slave device in RS-485 communication line  Last meter – slave device – in the communication line  Standalone device

Table 9: RS-485 switch position

NOTE The switch must be in position 1 on the last meter in line.

4.2.2.1.2. Ethernet (option) As an option, the meter can be equipped with Ethernet interface, which enables communication with HES. The interface is integrated on the top of the terminal block in the communication area. (See Figure 17.) The Ethernet interface is standardised to IEEE 802.3. The Ethernet interface permits connection to the WAN (Wide Area Network) by means of the transmission control protocol TCP/IP (Transmission Control Protocol/Internet Protocol). The transmission speed is 10/100 Mbps. The Ethernet connection of the communication module is made via an RJ45 socket with the pin assignment as it is shown in Table 10 (see Figure 18).

Ethernet LEDs:  Link Status (left)  TX/RX Activity (right) Ethernet interface – RJ45 socket

Figure 17: Ethernet interface

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Figure 18: Pin numbering of RJ45 socket

Pin No.

Terminal

Signal

1

TxD+

Transmitted Data +

2

TxD-

Transmitted Data -

3

RxD+

Received Data +

6

RxD-

Received Data -

Table 10: RJ45 socket pin assignment

NOTE In a case the meter is equipped with integrated Ethernet interface, a shielded cable must be used. For more information, see chapter 12.1.3. Ethernet cable.

The meter is equipped with two green LED diodes located on front side of the meter cover (see Figure 17). These LED diodes indicate Ethernet link status and Ethernet TX/RX activities (see Table 11). Ethernet link status (left LED)

Ethernet TX/RX activity (right LED)

OFF – link is not established

OFF – no activity

ON (lit) – link is established

BLINK – data transmission from / reception to the meter

Table 11: Ethernet LED diodes

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4.2.2.2. Terminal block – I/O area Inputs/outputs are integrated in the meter. They are placed in the I/O area on top of the terminal block. Which inputs and/or outputs are integrated in the meter depends on customer choice related meter configuration. I/O GROUP

I/O GROUP

A

B

Figure 19: Terminal block – I/O area – example

WARNING In a case of common terminal, there is no galvanic insulation between other two terminals.

Terminal number Function 15 Common terminal for terminals 13 and 33

Diam. Wire Screw head type Torque [mm] Note [mm2] * and size [N m] 1.2 High voltage input 0.5-1.0 Regular (0.6x3.5) 0.6

13

Energy tariff input T1/2

1.2

High voltage input 0.5-1.0

Regular (0.6x3.5) 0.6

33

Energy tariff input T3/4

1.2

High voltage input 0.5-1.0

Regular (0.6x3.5) 0.6

55

Common terminal for terminals 50 and 51

1.2

Low voltage input

0.5-1.0

Regular (0.6x3.5) 0.6

50

External key 1

1.2

Low voltage input

0.5-1.0

Regular (0.6x3.5) 0.6

51

External key 2

1.2

Low voltage input

0.5-1.0

Regular (0.6x3.5) 0.6

85

Common terminal for terminals 80 and 81 ** 1.2

Low voltage input

0.5-1.0

Regular (0.6x3.5) 0.6

80

Alarm input 1

1.2

Low voltage input

0.5-1.0

Regular (0.6x3.5) 0.6

81

Alarm input 2

1.2

Low voltage input

0.5-1.0

Regular (0.6x3.5) 0.6

* **

Minimum cross section of wire shall be according to standards. 85 is default terminal number for common terminal, where two inputs of different input groups are used

Table 12: Terminal data of input terminals

Terminal number Function

Diam. [mm] Note

35

Common terminal for terminals 36 to 38

1.2

output – Optomos

0.5-1.0 Regular (0.6x3.5) 0.6

36

Alarm output 1

1.2

output – Optomos

0.5-1.0 Regular (0.6x3.5) 0.6

38

Alarm output 2

1.2

output – Optomos

0.5-1.0 Regular (0.6x3.5) 0.6

37

Measurement period output

1.2

output – Optomos

0.5-1.0 Regular (0.6x3.5) 0.6

40

Common terminal for terminals 41 to 48 ** 1.2

output – Optomos

0.5-1.0 Regular (0.6x3.5) 0.6

41-48

Digital output **

1.2

output – Optomos

0.5-1.0 Regular (0.6x3.5) 0.6

75

Common terminal for terminals 71 to 73

1.2

output – Relay ***

0.5-1.0 Regular (0.6x3.5) 0.6

71

Load control output 1

1.2

output – Relay ***

0.5-1.0 Regular (0.6x3.5) 0.6

72

Load control output 2

1.2

output – Relay ***

0.5-1.0 Regular (0.6x3.5) 0.6

73

Load control output 3

1.2

output – Relay ***

0.5-1.0 Regular (0.6x3.5) 0.6

*

Wire Screw head type Torque [mm2] * and size [N m]

Minimum cross section of wire shall be according to standards.

** Metrological output *** ACS type of relay Table 13: Terminal data of output terminals

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NOTE For defining terminal number of digital (metrological) outputs, Iskraemeco recommends to use following combinations of terminal numbers and functions: Terminal number 41 42 43 44 45 46 47 48

Function Metrological output for +A Metrological output for -A Metrological output for +R (programmable R1+R2 or R1+R4) Metrological output for –R (programmable R3+R4 or R2+R3) Metrological output for reactive energy QI Metrological output for reactive energy QII Metrological output for reactive energy QIII Metrological output for reactive energy QIV

4.2.2.2.1. Electrical characteristics of inputs and outputs

Function Kind of a circuit Kind of voltage Nominal voltage Maximum voltage Nominal current Minimum current Continuous current Short time maximum current Burden Nominal and maximum frequency Insulation from other circuits Clamping of overvoltage

High voltage input Input Resistor/Optocoupler AC 230 V 264.5 V NA NA NA NA NA 50 Hz / 60 Hz Double insulation CAT III Varistor

Low voltage input Input Optocoupler DC 4.7 V 4.7 V NA NA NA NA NA / Double insulation CAT III Zener diode

Table 14: Inputs – electrical characteristics

Function Kind of a circuit Kind of voltage Nominal voltage Maximum voltage

Relay (ACS) Output Relay AC or DC 250 V AC / 30 V DC 250 V AC

Nominal current Minimum current Continuous current

Max. 5 A NA Max. 5 A / 250 V AC or max. 5 A / 30 V DC

Short time maximum current Burden Nominal and maximum frequency Insulation from other circuits Clamping of overvoltage Type of the contacts Contact impedance Withstand voltage across open contacts Duty cycle Number of operating cycles

NA Max. 5 A / 250 V AC or max. 5 A / 30 V DC 50 Hz / 60 Hz Double insulation CAT III Thyristor Normally open Contact resistance: max. 100 mOhm 1 kV AC / 60 s

100% Mechanical endurance: 107 operations Electrical endurance: 105 operations Table 15: Outputs – electrical characteristics

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Optomos Output SSR AC or DC Max. 400 V AC or DC Permissible switching voltage: 400 V peak Permissible switching current: 120 mA NA Permissible switching current: 120 mA Continuous load current: 0.12 A Peak load current: 0.3 A 120 mA / 400 V AC 50 Hz / 60 Hz Double insulation CAT III Thyristor Normally open Max. 35 Ohm at max. load current I/O isolation voltage: 4250 V AC / 60 s 100% NA

4. METER CONSTRUCTION

AM550 User manual

4.2.2.3. Terminal block – M-Bus area The meter can be equipped with a wired M-Bus. The M-Bus interface is used to connect sub-meters (gas, heat, and water) and other devices that are designed according to the M-Bus standard. A wired M-Bus is placed in the M-Bus area on top of the terminal block.

4.2.2.3.1. Wired M-Bus (option) M-Bus devices can be connected to terminals 90/91 (based on the M-Bus standard, see Figure 20). The maximum number of connected wired M-Bus devices is four. See Table 16. Connecting polarity is not important.

Figure 20: Terminal block – M-Bus area

Terminal number Function 90 M-Bus 91

* **

Reference voltage

Max. current

38 V

24 mA **

Diam. [mm] 2.5

Note M-Bus

Wire [mm2] * 0.5-2.5

Screw head type and size Regular (0.6x3.5)

Torque [N m] 0.6

2.5

M-Bus

0.5-2.5

Regular (0.6x3.5)

0.6

Minimum cross section of wire shall be according to standards. The maximum number of wired M-Bus devices associated to one electricity meter is four (each with current consumption of max. 4 unit load = 6 mA; in total 24 mA). Maximum current consumption of all connected M-Bus devices is 16 unit loads.

Table 16: Terminal data of M-Bus

Function Kind of a circuit Kind of voltage Nominal voltage Maximum voltage Nominal current Minimum current Continuous current Short time maximum current Burden Nominal and maximum frequency Insulation from other circuits Clamping of overvoltage

Communication NA DC 38 V 40 V NA NA NA NA M-Bus devices / Double insulation CAT III Varistor

Table 17: Electrical characteristics of M-Bus

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4.2.3. Terminal-cover-opening detector The AM550 meter is equipped with a terminal-cover-opening detector. At the one-phase meter (DIN and BS connection), the terminal-cover-opening detector is located on the top left side of the terminal block (Figure 21), while at the three-phase meter it is located on the top right side of the terminal block (Figure 22).

Figure 21: Position of the terminal-cover-opening detector at one-phase meter

Figure 22: Position of the terminal-cover-opening detector at three-phase meter

4.2.4. U-I calibration link A U-I calibration link (only on AM550 three-phase direct connected meters) is intended for fast and simple separation of meter current and voltage circuits used for calibration or accuracy testing. The U-I link access protection slider is located on the right side of the terminal block (Figure 23). It can be shifted left and right (with a screwdriver). For position meaning and usage, see Table 18). NOTE The U-I link access-protection slider can be sealed with a calibration seal (see Figure 24).

U-I link access protection slider

sealing point of the slider Figure 23: U-I link access-protection slider

Position

Meaning

Usage During meter testing and calibration, R – Right Access to the U-I link is available. the protection slider should be in the “R-Right” position. This is the normal state of the slider and L – Left Access to the U-I link is not possible. can be sealed with a calibration seal. Table 18: U-I link access protection slider – position meaning

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Figure 24: U-I link access-protection slider – sealing example

4.3. Terminal cover The meter’s terminal block is covered by a terminal cover (Figure 25). It is made of non-transparent or transparent (optional) high quality self-extinguishing UV-stabilized polycarbonate that can be recycled. The AM550 meter is equipped with terminal-cover-opening detector (see chapter 4.2.3. Terminal-cover-opening detector). Customarily, the terminal cover is made in the colour of the meter – white (RAL9010).

Figure 25: Terminal cover – example for three-phase meter

On the inner side of the terminal cover, the connection diagram is placed. The connection diagram is in the form of a label.

Figure 26: Terminal cover with attached meter hanger and connection-diagram label – example for three-phase meter

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4.4. Communication-module part of the meter The top of the meter is reserved for modular communication modules. This area is occupied with FEM1 module via P* interface, and FEM2 for consumer interface. See chapter 6. METER MODULES for further information.

4.4.1. Communication-module-cover opening detector The AM550 meter is equipped with a terminal-cover-opening detector (see Figure 27).

Figure 27: Position of the communication-module-cover opening detector

4.5. Communication-module cover The communication-module cover (see Figure 28) protects the meter field-exchangeable modules block. It is made of non-transparent high quality self-extinguishing UV-stabilized polycarbonate that can be recycled.

Figure 28: Communication module cover

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4.6. Sealing 4.6.1. Sealing of terminal and communication covers The AM550 one- and three-phase meters can be sealed with four sealing screws, two of which are on the communication module cover and two on the terminal cover.

Figure 29: Positions of sealing points at AM550 one-phase meter

Under the terminal cover of three-phase meter, the sealing point for U-I link access-protection slider is located (see Figure 23).

Figure 30: Positions of sealing points at AM550 three-phase meter

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4.6.2. Sealing of U-I link Under the terminal cover of the AM550 three-phase meter, the U-I calibration link can be sealed (see Figure 23).

4.6.3. Sealing of lower button (option) As an option, the lower button on the front plate of the AM550 meter (one- and three-phase) can be sealable.

Figure 32: Example of sealed button

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4.7. Nameplate 4.7.1. Nameplate according to IEC Basic data and type designation of the meter can be found on the nameplate.

4.7.1.1. Three-phase meter nameplate (IEC) country of origin and year of manufacture product family brand name

accuracy test LED for active (kWh) / reactive (kvarh) energy

reference number of connection diagram

manufacturer identifier

meter type designation

– CE mark (Conformité Européenne)

reference voltage

– WEEE Directive symbol for disposal/recycling electronic equipment

basic and max. current software package accuracy class (active energy)

– bidirectional meter

accuracy class (reactive energy)

– three-phase four-wire connection

reference frequency

– protective class – DLMS/COSEM compliance M-Bus – wired M-Bus

Figure 33: Example of an AM550 three-phase meter nameplate (IEC)

NOTE Figure 33 presents an example of a nameplate. The nameplate is customer-specific.

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4.7.2. Nameplate according to MID 4.7.2.1. One-phase meter nameplate (MID) accuracy test LED for active (kWh) / reactive (kvarh) energy country of origin and year of manufacture product family brand name

reference number of connection diagram

manufacturer identifier

– CE mark (Conformité Européenne) – year of approval – code of approval institute – operation temperature range – MID approval number

reference voltage

– WEEE Directive symbol for disposal/recycling electronic equipment

transition, reference and max. current

– bidirectional meter

accuracy class (reactive energy)

– accuracy class (active energy, MID)

reference frequency

– one-phase two-wire connection

meter type designation

– protective class – DLMS/COSEM compliance – M-Bus communication – G3-PLC communication

Figure 34: Example of an AM550 one-phase meter nameplate (MID)

NOTE Figure 34 presents an example of a nameplate. The nameplate is customer-specific.

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4.7.2.2. Three-phase meter nameplate (MID)

country of origin and year of manufacture product family brand name

accuracy test LED for active (kWh) / reactive (kvarh) energy

reference number of connection diagram

manufacturer identifier

– CE mark (Conformité Européenne) – year of approval – code of approval institute – operation temperature range

meter type designation

– MID approval number

reference voltage transition, reference and max. current

– WEEE Directive symbol for disposal/recycling electronic equipment

accuracy class (reactive energy)

– bidirectional meter

reference frequency

– accuracy class (active energy, MID) – one-phase two-wire connection – two-phase three-wire connection – three-phase four-wire connection – protective class – DLMS/COSEM compliance – M-Bus communication – G3-PLC communication

Figure 35: Example of an AM550 three-phase meter nameplate (MID)

NOTE Figure 35 presents an example of a nameplate. The nameplate is customer-specific.

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4.8. Label for CT ratio Label for CT ratio is used only at CT type (indirect connected) of AM550 meter. Current transformer ratio can be written on the dedicated CT-ratio label. The label can be inserted on front side of the meter, where a small plate with two pins is available for fixing and sealing CT-ratio label. If needed, the label can be sealed through both pins.

Figure 36: Label for CT ratio

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5. CONSOLE 5.1. Display The seven-segment liquid crystal display (LCD) complies with the VDEW requirements.

1

5

8

4 9 10

7 3 T1

T2

T3

T4

MB 6

SD

COM

DRO 2

CI FD/FM FF

1. Alphanumeric field, 1 – 6 small digits (6 mm in height) – OBIS identification code presentation 2. Alphanumeric field, 2 – 8 large digits (10 mm in height) – Data value presentation 3. Power flow direction cursors 4. Indicators of voltage presence by phases 5. Physical unit field of the currently displayed data 6. Cursors * 7. No load indicator (P-Active energy below starting current, Q-Reactive energy below starting current) * 8. Local currency indicator ** 9. Battery status ** 10. Units for submetering (gas, heat, water) * Cursors are customer-specific ** Segment available but not supported yet Figure 37: All segments of LCD display

Alphanumeric fields Alphanumeric field 1 is used for presentation the OBIS identification codes of the displayed data (in accordance with DIN 43863-3; see chapter 5.2. OBIS code on the display). The character size is 6 mm. Alphanumeric field 2 is used for presentation the data value. The character size is 10 mm. Available characters In Alphanumeric field 1 and Alphanumeric field 2, following characters can be presented: “-”, “ ” “0”, “1”, “2”, “3”, “4”, “5”, “6”, “7”, “8”, “9”, “A”, “B”, “C”, “D”, “E”, “F”, “G”, “H”, “I”, “J”, “K” *, “L”, “N”, “O”, “P”, “R”, “S”, “T”, “U”, “Y”, “Z” (Letters: B, D, N, O, R, T, U will be displayed as: b, d, n, o, r, t, u) “a”, “b”, ”c”, “d”, “e”, “f”, “g”, “h”, “i”, “j”, “k” *, “l”, “n”, “o”, “p”, “r”, “s”, “t”, “u”, “y”, “z” (Letters: a, e, f, g, j, l, p, s, y, z will be displayed as: A, E, F, G, J, L, P, S, Y, Z) * see the note below

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NOTE Characters “K” and “k” are displayed on LCD as the same character. It is displayed as:

The “K”/”k” character is available in FW Core version ISK550TC03304000.

Power flow direction cursors There are four power flow direction cursors on the display:  Positive active power flow (+P),  Positive reactive power flow (+Q),  Negative active power flow (-P),  Negative reactive power flow (-Q). Power flow direction cursors at simultaneous Import and Export of energy Here are some examples that show which segment on the quadrant cross is displayed when Import and Export of the energy occurs simultaneously: 

Active Energy: SUM = L1 + L2 + (-L3) > 0; arrow on display 



Active Energy: SUM = L1 + L2 + (-L3) < 0; arrow on display 

 

Reactive Energy: SUM = L1 + L2 + (-L3) > 0; arrow on display  Reactive Energy: SUM = L1 + L2 + (-L3) < 0; arrow on display 

The Phases indicator Segments L1, L2 and L3 show indicated phases on meter. Blinking single segment indicates neutral and phase conductor mix in 3-phase meter (priority 1). Blinking all segments represents wrong phase sequence connection (priority 2). Physical unit field shows units currently displayed data. Physical unit field Physical unit field shows the unit of currently displayed data. Cursors On the front plate below the LCD display, the meter has laser-printed markings that belong to the cursors on the LCD. Cursors show the state of a certain function that they represent. In Table 19, the meaning of available cursors is described. NOTE The selection of cursors is customer-specific (factory settable parameter) and their number is limited to 10. Defined configuration of LCD cursors can be accessible by Display cursors configuration (0-0:196.1.4*255).

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Meaning

T1/T5

Tariff indicator:

T2/T6

T3/T7

T4/T8



Lit – T1 active



Blinking – T5 active

Tariff indicator: 

Lit – T2 active



Blinking – T6 active

Tariff indicator: 

Lit – T3 active



Blinking – T7 active

Tariff indicator: 

Lit – T4 active



Blinking – T8 active

MB

Multi-utility interface active (one of multi-utility devices is installed on the interface)

SD

Switching device: 

Lit – disconnected



Blinking – ready for connection

COM

Communication – registered in network

DRO

Data readout in progress (WAN or optical interface)

CI

Consumer Interface – P1 interface activated

FD/FM

FD – Fraud detection 

Lit when the terminal cover is open, off when the terminal cover is closed

 Lit when a magnet is in the vicinity of the meter, off otherwise FM – Factory mode cursor is blinking when the meter is in TEST mode TM

TEST mode (simple variant of FD/FM flag) – Lit when state of Test mode is active.

FF

FF – Fatal failure

LC1

Relay control 1 – output state – Lit when current state is “Connected”.

LC2

Relay control 2 – output state – Lit when current state is “Connected”.

CLK

Clock invalid – Lit when clock is invalid

Table 19: LCD – meaning of available cursors

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5.2. OBIS code on the display On the left side of the display, 6 digits are reserved for OBIS code presentation (see field 1 in Figure 37). OBIS code is always displayed from the first digit on the left. By default, for presenting OBIS codes on the display, short OBIS code format is used: C.D.E. Using Display configuration object (0-0:196.1.3*255), it can be forced to display all objects as extended OBIS name format: A.B.C.D.E. (See Figure 38)

Figure 38: Show full OBIS code attribute in Display configuration object

In a case extended OBIS name format is not forced, there are some exceptions when extended OBIS name is displayed: 

A.B.C.D.E format is used for presentation of the following objects: - Core identification: Active firmware identifier (LRFW) (1-0:0.2.0*255) - Application identification: Active firmware identifier 1 (NLRFW) (1-1:0.2.0*255) - FEM1 identification: Active firmware identifier 2 (FEM1) (1-2:0.2.0*255) - FEM2 identification: Active firmware identifier 3 (FEM2) (1-3:0.2.0*255) - CLR identification: Active firmware identifier 5 (CLRFW) (1-5:0.2.0*255) - Bootloader identification: Active firmware identifier 6 (bootloader) (1-6:0.2.0*255) - Core signature: Active firmware signature (LRFW) (1-0:0.2.8*255) - Application signature: Active firmware signature 1 (NLRFW) (1-1:0.2.8*255) - FEM1 signature: Active firmware identifier 2 (FEM1) (1-2:0.2.8*255) - FEM2 signature: Active firmware identifier 3 (FEM2) (1-3:0.2.8*255) - CLR signature: Active firmware identifier 5 (CLRFW) (1-5:0.2.8*255) - Bootloader signature: Active firmware identifier 6 (bootloader) (1-6:0.2.8*255)



B.C.D.E format is used for presentation of the objects with field B ≠ 0.

In a case mirror objects are enabled (see Figure 77), and A=1 and B ≠ 0, short OBIS name format (C.D.E) is used.

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On the display, up to 6 characters of OBIS code can be presented. For the specific multi-character fields of OBIS, some abbreviation characters codes are used (see Table 20).

Multi-character field 96 97 98 99 128

Abbreviation character C F L P U

Table 20: OBIS Code Abbreviation Characters

5.3. Console modes of operation The meter has several modes to show data on the display:  



General display readout – Auto scroll mode (by default); Alternate display readout – Manual scroll mode with two different console types: - Normal, - Reduced; Service mode.

All scroll sequences are configurable with parameters at meter run time.

5.3.1. General Display Readout mode (auto-scroll sequence) The General display readout mode is implemented in the following way:  General display readout mode is a general meter mode, where the items listed in the General display readout object (0-0:21.0.1*255) are cyclically displayed on the LCD. 

General display readout time is a configurable parameter and is set to 5 seconds by default.

General display readout object (0-0:21.0.1*255) is an instance of a COSEM Profile Generic class, where only the Capture Objects attribute is relevant (or other attributes are not used).

5.3.2. Alternate Display Readout mode (manual-scroll sequence) Alternate display readout mode is implemented in the following way:    

Alternate display readout mode is used for manual data review on display. Displayed items are listed in Alternate display readout mode sequence list, defined by Alternate display readout object (0-0:21.0.2*255). Alternate display readout mode is accessible by appropriate pressing of the Scroll button. The next item from the sequence list is displayed by a short press on the Scroll button.



At the end of sequence, the End notice is displayed.



Escape in General display readout mode is performed by an extended press on the Scroll button, when tip ‘Esc’ is shown. General display readout mode is automatically accessed after Exit period while no button is pressed.

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5.3.2.1. Reduced console menu type Reduced console menu type can be activated by executing Script 12 (via configuration tool, e.g. Iskraemeco SEP2 MeterView), which can be found in the Function activation control script table – 0-0:10.0.111*255 (class_id: 9).

Button press

Press duration - Tp

Tip on display

Short press

Tp < 1 s

Perform the LCD test. Enter the Alternate display readout mode from the LCD test mode. Scroll forward to the next item in Alternate display readout mode.

/

Medium press

1 s ≤ Tp < 2 s

Scroll forward and skip the previous values in Alternate display readout mode.

/

Long press

2 s ≤ Tp < 5 s

Escape from the Consumer message code presentation (0-0:96.13.1*255)

ESC

Extended press

5 s ≤ Tp < 8 s

Escape from the Alternate display readout mode to the General display readout mode

ESC

Triggering event

Table 21: Usage of the Scroll button in the reduced console menu type

Press duration - Tp

Tip on display

5 s ≤ Tp < 10 s

EntEr

10 s ≤ Tp < 15 s

diSconn

Table 22: Usage of the Switching device button regardless of console mode

5.3.2.2. Normal console menu type Normal console menu type can be activated by executing the Script 11 (via configuration tool, e.g. Iskraemeco SEP2 MeterView), which can be found in the Function activation control script table – 0-0:10.0.111*255 (class_id: 9).

Button press

Press duration - Tp

Triggering event

Tip on display

Scroll push-button Short press

Tp < 1s

Medium press

1s ≤ Tp < 2s

Long press

Extended press

2s ≤ Tp < 5s

5s ≤ Tp < 8s

Scroll forward / Go to the next item Scroll forward and skip the previous values (General display readout mode, Alternate display readout mode) Enter to the current item / Go to the lower layer Return to the upper layer at the End of list / Return to the upper layer from the lowest layer Return to the General display readout mode at the End of list in Set menu / Data menu Escape from the Consumer message code presentation (0-0:96.13.1*255) Escape to the General display readout mode from any mode

/ / EntEr LAYEr UP ESC ESC ESC

Table 23: Usage of the Scroll button in the normal console menu type

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5.3.3. Service mode (service manual-scroll sequence) Service mode is similar to manual scroll but it is accessible only to authorized persons (installers, technicians), and is not intended for the consumer. 

It is used for manual review of detailed information about the meter on the display.



The meter enters the service mode when the terminal cover is opened, and it exits the service mode when the terminal cover is closed.

 

In service mode, only the closing of the terminal cover causes access to any other mode. The next item from the service sequence list is displayed by a short press on the Scroll button.



At the end of the service sequence list, the “End sequence” is displayed, which is not a part of the service display readout sequence. With another press on the Scroll button, first sequence from the service sequence list is displayed.

In service mode, displayed items are listed in the sequence list, defined by the Service display readout sequence (0-0:21.0.3*255). Service display readout object (0-0:21.0.3*255) is an instance of COSEM Profile Generic class, where only the Capture Objects attribute is relevant (or other attributes are no used).

5.4. Display format Display format objects are used to configure format for energy and demand presentation on the display. The display format is supported for Energy and Demand registrations. Units for displayed data are represented as:      

Active energy in kWh, Reactive energy in kvarh, Apparent energy in kVAh, Demand in kW, Current in A, Voltage in V.

5.4.1. Display format for energy Display format for energy COSEM object (0-0:196.1.0*255) holds the value WP, which follows these rules:  

Definition of value: WP W = Width: - Width is a number of digits for energy presentation on display. - It is a sum of integer digits and decimal digits. - First nibble of object’s value (upper half of byte). - Maximum width value is 8 digits.



P = Precision: - Precision is a number of decimal digits for energy presentation on display. - Last nibble of object’s value (lower half of byte). - Precision value (number of decimal digits) should be between 0 and 3.



Default value: WP = 60 - Width: 6 digits - Precision: 0 digits - Resulting format form: 000000

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Example: Width = 8 digits WP = 82  Width: 8 digits  Precision: 2 digits  Resulting format form: 000000.00

88888888 Precision = 2 digits

NOTE Not all combinations of Width and Precision are valid. Energy registers: The value of energy registers is limited to maximum 999.999.999 before it overflows to 0. By default, the energy registers have a span up to 1 G[unit]h (default value of Results energy scaler (0-0:196.0.4*255) is 0). If scaler of unit is higher of 0, the span can increase up to 10 G[unit]h (for more information, see chapter 7.5.1. Energy). Display: Since all energy registers on the display are shown in k[unit]h, their maximum span has to be taken into consideration when choosing the Energy display format (e.g: 00000000.0 is thus not allowed). When choosing Energy display format, take into consideration value of scaler unit as well.

5.4.2. Display format for demand Display format for demand COSEM object (0-0:196.1.1*255) holds the value WP, which follows these rules:  





Definition of value: WP W = Width: - Width is a number of digits for demand presentation on display. - It is a sum of integer digits and decimal digits. - First nibble of object’s value (upper half of byte). - Maximum width value is 8 digits. P = Precision: - Precision is a number of decimal digits for demand presentation on display. - Last nibble of object’s value (lower half of byte). - Precision value (number of decimal digits) should be between 0 and 3. Default value: WP = 62 - Width: 6 digits - Precision: 2 digits - Resulting format form: 0000.00

Example: WP = 53  Width: 5 digits  Precision: 3 digits  Resulting format form: 00.000

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5.5. Other supported display functions 5.5.1. Display consumer message text Consumer message text - Consumer information (object: 0-0:96.13.0*255) is sent to the display (and P1 port) without any further interpretation, with a maximum of 1024 characters in ASCII format. Messages that exceed the maximum size will be cleared and will not be stored.

5.5.2. Signature on display There are two meter-firmware signatures and they are displayed with horizontal scroll (display row length is 8 characters):  Core firmware signature: Active firmware signature (LRFW) (1-0:0.2.8*255)  Application firmware signature: Active firmware signature 1 (NLRFW) (1-1:0.2.8*255) Additional firmware signatures:  Communication module 1 firmware signature: Active firmware signature 2 (FEM1) (1-2:0.2.8*255) 

Communication module 2 firmware signature: Active firmware signature 3 (FEM2) (1-3:0.2.8*255)

There is no horizontal scroll to display additional firmware signatures. If a signature is larger than the display row length (16 characters), only the first 16 characters of the signature are displayed.

5.5.3. Neutral - Phase wrong connection indication In 3-phase meters, when phase and neutral conductor are mixed up, dedicated phase indicator (L1, L2 or L3) blinks and fixed text (no specific object) is displayed on LCD (for example, see Figure 39):

n-L(phase) Err

Figure 39: Example of wrong Neutral-Phase connection indication text on display

In this state, fixed text on the LCD can be escaped by an extended press (> 5 sec) on the upper button (before releasing the button, tip ‘Esc’ is displayed on the LCD). The dedicated phase indicator that is misconnected is still blinking. This alarm state has the highest priority to be shown on display as a matter of the greatest importance.

5.5.4. Switching device disconnection indication With extended press on lower button (> 10 s < 15 s) tip ‘Disconn’ is displayed and if we release button in during that tip, the switching device is disconnected (considering appropriate disconnection controlling mode). In the case of permission for reconnection, the Switching device disconnection alarm is displayed on the LCD:

ConnEct

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Figure 40: Connect text on display

This alarm state has a higher priority than the auto scroll mode.

5.6. Practical cases NOTE The order of the displayed items listed in individual modes is defined in corresponding object as follows:  General display readout mode (Auto scroll mode) in object General display readout (00:21.0.1) 

Alternate display readout mode (Manual scroll mode) in object Alternate display readout (0-0:21.0.2)



Service mode (service manual-scroll sequence) in object Service display readout (0-0:21.0.3)

NOTE A place number of the register in the Std dAtA and Ser dAtA menu is already set and can be changed.

5.6.1. Reading firmware version, signature and hash on LCD NOTE The FW Core (LRFW) hash values can be read only when both of conditions are fulfilled:  

meter power-up sequence active SERVICE console menu type (removed terminal cover).

1. Remove the terminal cover. On the LCD SEr dAtA appears. 2. To enter the SEr dAtA menu long press the Scroll button until EntEr appears. By short pressing the Scroll button, manually listing between registers is now available. 3. Press the Scroll button repeatedly until the desired register (appropriate register’s code can be found below this procedure or in the object lists) can be seen on the top left side of the LCD. The value of this register is displayed below. In case of signature/hash, the value is automatically scrolled on the LCD. 4. By next short press on the Scroll button, the value for next register appears (if at the end of the register list, instead of a register, End is displayed; the list is cyclic). Press the Scroll button repeatedly until the desired register appears. Then, read its value. 5. If there is no need to read a value of any other register, exit Service mode. Put the terminal cover back on the meter and tighten screws. Active firmware identifier (LRFW) can be found by the register 1-0:0.2.0*255. Active firmware signature (LRFW) can be found by the register 1-0:0.2.8*255. Active firmware identifier 5 (CLRFW) can be found by the register 1-5:0.2.0*255. Active firmware signature 5 (CLRFW) can be found by the register 1-5:0.2.8*255. V3.00 – English

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5.6.2. Reading load profile values on LCD

NOTE The load profile values can be read only in NORMAL console menu type.

1. Short press the Scroll button (< 1 s); the display test mode displays. 2. Short press the Scroll button; Std dAtA appears. 3. Short press the Scroll button repeatedly until the register P.0x (x stands for load profile number; x = 1, 2, 3 or 4) can be seen on the LCD. 4. To enter the desired register, long press the Scroll button until EntEr shows – release the button then. On the LCD, the register’s value is displayed. 5. To scroll between the Load profile’s values, short press the Scroll button. To read all the values keep short pressing the button until End is displayed. 6. If there is no need to read a value of any other register, exit by extended press (≥ 5 s < 8 s) on the Scroll button until ESC is displayed. The transition from Manual to Auto scroll mode can happen automatically; the transition time is configurable.

5.6.3. Reading the certification log (P.99) values on LCD

NOTE The certification log values can be read only in NORMAL console menu type.

1. 2. 3. 4.

Short press the Scroll button (< 1 s); the display test mode displays. Short press the Scroll button; Std dAtA appears. Short press the Scroll button repeatedly until the register P.99 can be seen on the LCD. To enter the desired register, long press the Scroll button until EntEr shows – release the button then. On the LCD, the date value of P.99.09 is displayed. 5. To scroll between the certification log’s date values (P.99.0x; x stands for certification log number; x = 9, 8, 7… or 1), short press the Scroll button. To read all the values keep short pressing the button until End is displayed. 6. To read the date’s corresponding time value, long press the Scroll button until EntEr shows – release the button then. To return to the date value list (which is one layer up), long press the Scroll button until LAYEr uP shows – release the button then. 7. If there is no need to read a value of any other register, exit by extended press (≥ 5 s < 8 s) on the Scroll button until ESC is displayed. The transition from Manual to Auto scroll mode can happen automatically; the transition time is configurable.

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5.7. Metrological LED The meter is provided with a red-coloured (or other – customer’s decision) metrological LED on the front plate. It is intended for checking the meter accuracy (for active (kWh) / reactive (kvarh) energy). Impulse constant depends on the meter type (see Table 25). In normal meter operation mode, the LED emits pulses with a frequency that is proportional to the measured energy and is intended for meter calibration and testing. The LED is permanently on and lit if the present current is lower than the starting current of the meter.

Figure 41: Metrological LED on front plate of AM550 meters (left one-phase meter, right three-phase meter))

5.8. Buttons and Switching device status LED On the meter’s front side, there are two buttons (Figure 42):  Scroll button – its primary function is to scroll data in the Manual scroll mode and Service mode sequences (short press). It is also used for disconnect/reconnect control of switching device (extended press).  Switching device button is used to connect/disconnect switching device.

Scroll button Switching device button

Switching device status LED Figure 42: Scroll button, switching device button and switching device status LED

Short press means pressing a button less than 1 second. Extended press means pressing a button at least 5 seconds or more. When the buttons are first time pressed (in auto scroll and manual scroll modes), the display backlight lits. Switching device status LED is placed just below the buttons (see Figure 42). It is used to indicate switching device status information. When the LED:  lights, the switching device is disconnected,  blinks, the switching device is ready to connect, 

off, the switching device is connected.

5.8.1. Sealable lower button (option) By customer order, the lower button can be sealable (see Figure 32).

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6. METER MODULES A meter module is an exchangeable, plug-in hardware unit, which can be fitted on the top side of the meter, under the communication module cover. The module can be moved (replaced) even when the meter is in full operational state. WARNING For safety reason, use only modules approved by Iskraemeco. Use of unconfirmed modules can cause electric shock. WARNING Due to general safety issues, it is recommended that meter is unplugged from the electricity network before removal of module cover and communication modules! WARNING Electro Static electricity on P1 port's contacts can harm P1 communication module but it causes no influence on the metrological functionality of the electronic meter. To prevent static damage, discharge static electricity from your body before you touch the contacts. You can do so by touching an unpainted grounded metal surface. WARNING FEM connector is not isolated from hazardous live voltage. Do not touch bare parts of connector while connecting the module to the meter. NOTE When modular communication (exchangeable module inserted in FEM1) is active, integrated communication (in terminal block) is disabled.

For information on the communication module you own, see the technical description of the module (contact the meter manufacturer for more information).

6.1. P* interface AM550 meter supports field exchangeable communication modules on a so-called P* interface. P* interface is intended to be a universal communication interface for various communication modules supporting different communication technologies. Communication modules that comply with P* are easily exchangeable.

Figure 43: P* interface (left: FEM1, right: FEM2)

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6.2. Communication module – WAN (P3) – (option) A WAN communication module is fitted on top of the meter, under the removable communication module cover. It can be plugged only in the FEM1 interface (see Figure 43 and Figure 44). For AM550 meters, several communication modules with different supported WAN communication technologies are available (and technical descriptions of each).

Figure 44: Position of the communication module in the meter (example for GPRS module)

6.3. Communication module – Consumer interface (P1) – (option) The P1 communication module is optional (chosen by the customer). If a meter is equipped with the P1 communication module, it is fitted in the communication module cover and FEM2 in the meter. The module is removable.

Figure 45: P1 communication module

Figure 46: P1 module fitted in communication module cover

The P1 port socket is closed with clamped rubber lid. NOTE If the P1 port is not in use, make sure to close the rubber lid properly to fulfil IP-protection requirements and comply with the ESD standard.

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Figure 47: P1 socket (left: closed, right: opened)

P1 port is a read-only interface for connecting external devices. The module is equipped with RJ12 female socket, which provides power supply and information data for In-House Display (IHD) Data, exchanged with IHD, are configurable on users demand. (See chapter 12.1.4. P1 port connector.)

NOTE If the P1 communication module is not present, for ensuring proper IP protection, the place must be fulfilled with a P1 “dummy” module. For more information, see chapter 13.1. Removing the P1 module out of the meter cover.

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7. MEASUREMENT PLATFORM 7.1. Measuring configuration The AM550 meters contain one measurement element (AM550-E) or three measurement elements (AM550-T) for the currents and voltages. The meters use different current sensors:   

one-phase meter (AM550-E) uses shunt directly connected three-phase meter (AM550-T) uses an air coil based on the Rogowski principle indirectly connected three-phase meter (AM550-T) uses current transformer.

The voltage sensor is a resistive voltage divider. The resistive dividers have different attenuations. Voltage and current analog signals are fed into the A/D (analog to digital) converters.

7.2. Measurement principle Current and voltage samples, obtained from the measurement system, are then processed in the firmware to record:  

Consumed/generated energy (active, reactive and apparent separately) – per-phase and total values. Vector or arithmetical method is used to calculate the total energy. Instantaneous power (active, reactive and apparent separately) – per-phase and total values.



Instantaneous RMS currents and voltages – per-phase RMS values of phase currents and voltages only.



Instantaneous power-line frequency. The calculated frequency is the average value of the measured frequency of all three phases.



Power factor measurements (as an option)

NOTE The method (vector/arithmetical) is selected during the production phase and cannot be changed in the field. In a case of 1-phase meter, the calculated per-phase energy and power values (phase 1) and total values evaluate to the same value. All calculated values are available to the rest of the system through the measurement platform API functions. Measurement system also generates the metrology pulses, which are used to drive Energy LED and Digital outputs. The frequency of the generated pulses is proportional to the selected instantaneous power and the output’s metrology constant, while their number in the specified time window is proportional to the consumed/generated energy in this time window. The energy LED and the digital output operation mode is configurable.

7.3. Direct/indirect connection of the meter According to the meter type, three-phase AM550 meters can be connected directly to the power supply network, or indirectly through the (external) current measurement transformer. If the meter is connected indirectly, it must be configured properly to take into account the external transformer ratio in the measurement process. Transformer measurement type object (0-0:196.0.1*255) defines if the current transformer ratio is used in measuring process or not (only for transformer type of AM550-T meters). Definitions are:  

0 – Secondary (default): transformer ratio is not used 1 – Primary – transformer ratio is used

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Explanation: If Transformer measurement type of CT meter is set to: 

“0 – secondary”, transformer ratio is not used. In this case, values measured by the meter are registered.



“1 – primary”, transformer ratio K is used for calculation. In this case, values measured by the meter are transformed/calculated using transformer ratio K, and registered.

7.3.1. The ratio of the external measurement transformer If the meter is connected through the external current measurement transformer, its ratio must be specified. The Transformer ratio objects are used for this purpose:  

Transformer ratio – current (numerator) – 1-0:4.0.2*255 Transformer ratio – current (denominator) – 1-0:4.0.5*255

The transformer ratio K is calculated by equation

𝐾=

𝑁𝑢𝑚𝑒𝑟𝑎𝑡𝑜𝑟 𝐷𝑒𝑛𝑜𝑚𝑖𝑛𝑎𝑡𝑜𝑟

It is used to calculate primary current (power supply network current) from the secondary current (current at the meter’s terminal) according to equation

𝑃𝑟𝑖𝑚𝑎𝑟𝑦 𝑐𝑢𝑟𝑟𝑒𝑛𝑡 = 𝐾 ∗ 𝑠𝑒𝑐𝑜𝑛𝑑𝑎𝑟𝑦 𝑐𝑢𝑟𝑟𝑒𝑛𝑡 Some examples of transformer ratio values (numerator, denominator and K) are listed in Table 24. Numerator 100 200 300 600 1000 1600

Denominator 5 5 5 5 5 5

Transformer ratio K 20 40 60 120 200 320

Table 24: Examples of current transformer ratio values

NOTE In most cases, K value is whole number (not decimal).

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7.4. Energy (Metrological) LED and digital output constants These parameters define the energy LED and digital output constants. They are stored in an array constants of six elements. They are divided into two sets:  Energy LED constants 

Digital output constants

Each set contains the parameters for the active, reactive, and apparent energy. Their default values are shown in Table 25.

Output

LED

digital output

Array index Energy

Default value * 60 and 85 A meters

100 and 120 A meters

10 A meter (CT)

500

10000

0

active

1000

1

reactive

1000

500

10000

2

apparent

1000

500

10000

3

active

250

250

5000

4

reactive

250

250

5000

apparent

250

250

5000

5 * output constant is configurable

Table 25: Default values for the energy output constants

These parameters define the energy LED and digital output constants. One metrological LED and (depends on HW) different number of digital outputs are integrated in the AM550 meter. The LED and the digital outputs can be configured to show: Source energy Symbol Active energy combined ||+A| + |-A|| Active energy import +A Active energy export -A Reactive energy combined ||+R| + |-R|| Reactive energy import +R Reactive energy export -R Reactive energy QI QI Reactive energy QII QII Reactive energy QIII QIII Reactive energy QIV QIV Apparent energy combined ||+VA| + |-VA|| Apparent energy import +VA Apparent energy export -VA Table 26: Source energy valid values, their meaning and the default value

Source energy can be set in Field settable parameters object (0-0:128.5.11*255) (in the first position). NOTE In addition to pulse outputs, the meter also supports measurements period outputs.

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7.4.1. Energy (Metrology) LED constants The LED constants can be read through the following objects:  for active energy – Metrological LED constant – active energy (1-0:0.3.0*255)  for reactive energy – Metrological LED constant – reactive energy (1-0:0.3.1*255) 

for apparent energy – Metrological LED constant – apparent energy (1-0:0.3.2*255)

7.4.2. Energy (Metrological) digital output constants The energy pulse-output constants can be read through the following objects:   

for active energy – Energy pulse-output constant – active energy (1-0:0.3.3*255) for reactive energy – Energy pulse-output constant – reactive energy (1-0:0.3.4*255) for apparent energy – Energy pulse-output constant – apparent energy (1-0:0.3.5*255)

7.5. Measured values Three-phase meters measure and record the following total electric energies:   

positive and negative active energy (A+, A-) separately, positive and negative reactive energy (R+, R-) separately, positive and negative apparent energy (S+, S-) separately,

  

absolute active energy A++ |A-|, net active energy |A+| - |A-|, reactive energy per quadrants (QI, QII, QIII, QIV).

Meters are provided with a single LED on the front plate. The LED is intended for checking the meter accuracy. Impulse constant depends on the meter version. Demand (power) is measured inside a measuring period. The measuring period is a meter parameter and can be configured. Values that can be set are 1, 5, 10, 15, 30 and 60 minutes. After termination of the measuring period, the measured meter value is transferred from current measuring period registers to registers for previous measuring period that can be later used for the formation of billing values.

NOTE By a customer request (as an option), OBIS codes of energy and demand objects can be “mirrored”. For more information, see chapter 8.16. Mirrored objects (option). Averaging is calculated within a measuring period of 10 minutes. At the end of the corresponding measuring period, the measured meter value is transferred from current values to previous values. Previous values are used to store data in different profiles – if the profile period and measuring period coincide.

7.5.1. Energy The electrical meter stores energy in respective cumulative energy registers (A+ or A-) expressed in Wh. The value attribute of energy register class instances is limited to maximum 999.999.999 before it overflows to 0. The registers can be accessed via communication interface in form of DLMS/COSEM objects with dedicated logical name, value, unit, and scaler of unit. Alternatively, energy registers can be shown on display or P1 port in k[unit]h (where unit stands for W, var or VA) and formatted with specific/configurable width and precision format (Display format for energy 0-0:196.1.0*255; see chapter 5.4.1. Display format for energy).

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NOTE Energy registers have resolution according to the unit-scaler parameter 1, 10, 100, 1,000, 10,000 [Wh, varh, VAh]. The scaler parameter is set in object Results energy scaler (0-0:196.0.4*255). For more information, see chapter 7.5.1.1. Energy scaler.

NOTE For A+, A-, R+, R-, S+, S-, |A+|+|A-|, Qi+, Qi-, Qc+, Qc- energy registers, the register value can be from 0 to 999.999.999 [Wh, varh, VAh]. When register value goes over this maximum value (overflow), the register turns to 0 and counts from there. For |A+|-|A-| energy register, the value can be from -1.000.000.000 to 999.999.999 [Wh]. The micro-computer records different types of energy (active, reactive, apparent) for all phases in one or more tariffs and stores these values in various registers according to energy direction and active tariff. The following Energy registers are supported: Active energy import (+A) and per Tariff  +A Active energy export (-A) and per Tariff  -A 

+R

Reactive energy import (+R) and per Tariff

   

-R +VA -VA ABS

Reactive energy export (-R) and per Tariff Apparent energy import (+VA) and per Tariff Apparent energy export (-VA) and per Tariff Active energy combined (|+A|+|-A|) and per Tariff

 

Net Reactive per quadrants

Active energy combined (|+A|-|-A|) and per Tariff * Reactive energy per quadrants and per Tariff

* NET – Active Energy per Tariff (1-0:16.8.x*255 (x=1…8)) is an option and is not available in all AM550 firmware versions. NOTE Not all AM550 firmware versions/variants have all presented functionalities available.

7.5.1.1. Energy scaler By raising energy scaler-unit, a span of energy registers increased up to 10 G[unit]h. As an option, energy scaler is factory-settable parameter, defined in object Results energy scaler (0-0:196.0.4*255). A value of energy scaler object parameter can be 0, 1, 2, 3, or 4 (Table 27). By default, value of the scaler is set to 0. Value of energy scaler object parameter

Energy register resolution

0

1 [Wh, varh, VAh]

1

10 [Wh, varh, VAh]

2

100 [Wh, varh, VAh]

3

1000 [Wh, varh, VAh]

4

10000 [Wh, varh, VAh]

Table 27: Energy scaler – value of object meter and energy register solution

The scaler and a value form final value of energy register.

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Figure 48: Different set energy scaler (example), where display format for energy is WP=80

NOTE By a customer request, the scaler can be factory-specific setting. Energy scaler value can be seen in every energy register under Scaler unit.

Figure 49: Read-only scaler in energy object (example)

7.5.2. Demand (power) After completion of the measuring period, current average value (x.4.0) is stored to the register for previous measuring period (x.5.0) and compared with highest maximum value stored in the relevant register (x.6.0). If new value is larger, it is stored as new maximum value at corresponding position. At the same time, time stamp is stored representing the time conclusion of measuring period. At the end of the billing period, maximum demand registers (x.6.y) are recorded to billing profiles (if profile is being properly configured). Maximum demand values (x.6.y) are added to cumulative maximum demand registers (x.2.y) before they are being cleared (set to zero). Also billing period counter is being increased by one. The following Demand (power) registers are supported: 

+A o o o o

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Cumulative maximum demand register - Active energy import (+A) and per Tariff (1.2.x) Demand register - Active energy import (+A) (1.4.0) Last average demand register - Active energy import (+A) (1.5.0) Maximum demand register - Active energy import (+A) and per Tariff (1.6.x)

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













-A o o o o

Cumulative maximum demand register - Active energy export (-A) and per Tariff (2.2.x) Demand register - Active energy export (-A) (2.4.0) Last average demand register - Active energy export (-A) (2.5.0) Maximum demand register - Active energy export (-A) and per Tariff 1 (2.6.x)

o o o o

Cumulative maximum demand register - Reactive energy import (+R) and per Tariff Demand register - Reactive energy import (+R) Last average demand register - Reactive energy import (+R) Maximum demand register - Reactive energy import (+R) and per Tariff

o o o o

Cumulative maximum demand register - Reactive energy export (-R) Demand register - Reactive energy export (-R) Last average demand register - Reactive energy export (-R) Maximum demand register - Reactive energy export (-R) and per Tariff

+R

-R

+VA o o o o

Cumulative maximum demand register - Apparent energy import (+VA) and per Tariff Demand register - Apparent energy import (+VA) Last average demand register - Apparent energy import (+VA) Maximum demand register - Apparent energy import (+VA) and per Tariff

-VA o Cumulative maximum demand register - Apparent energy export (-VA) and per Tariff o Demand register - Apparent energy export (-VA) o Last average demand register - Apparent energy export (-VA) o Maximum demand register - Apparent energy export (-VA) and per Tariff ABS o Cumulative maximum demand register - Active energy combined (|+A|+|-A|) and per Tariff o Demand register - Active energy combined (|+A|+|-A|) o Active demand last combined (|+A|+|-A|) o Maximum demand register - Active energy combined (|+A|+|-A|) and per Tariff Other demand registers o Demand register - Active energy import (+A) per phase o Demand register - Active energy export (-A) per phase o Demand register - Reactive energy import (+R) per phase o Demand register - Reactive energy export (-R) per phase NOTE Not all AM550 firmware versions/variants have all presented functionalities available.

7.5.3. Average values There are two measurement periods in use:  Measurement period 1 (MP1) – Measurement period 1, for average value 1 (1-0:0.8.0*255) is used for demand measurements (recommended periods are 5 min, 15 min, 30 min and 60 min).  Measurement period 3 (MP3) – Measurement period 3, for instantaneous values (1-0:0.8.2*255) is used for COSEM objects mandated by averaging scheme 3 (average voltage and current). The following average values are supported:   

Average total power (|+A|+|-A|) Average voltage per phase Average current per phase

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7.5.4. Instantaneous values The following instantaneous values are supported:               

Instantaneous current per phase Instantaneous current (sum over all phases) Instantaneous net frequency: any phase Instantaneous active import power (+A) Instantaneous active export power (-A) Instantaneous reactive import power (+R) and per phase Instantaneous reactive export power (-R) and per phase Instantaneous apparent import power (+VA) Instantaneous apparent export power (-VA) Instantaneous active power combined (|+A|+|-A|) Instantaneous voltage L1 and per phase Instantaneous active power combined (|+A|-|-A|) Instantaneous active import power (+A) L1 and per phase Instantaneous active export power (-A) L1 and per phase Instantaneous active power combined (|+A|-|-A|) L1 and per phase

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES 8.1. RTC Backup AM550 meters support Supercap (super capatitor), which guarantees operation of real time clock (RTC) and tamper functionality during power loss. The Supercap enables operation for 7 days, when meter is previously charged for 24 h continuously at nominal voltage by ambient temperature of 25°C.

8.2. Time Time in the meter is defined according to local time/date, time zone and daylight savings time (DST). Time and date data format contains the meter’s local date and time, its deviation to UTC (Coordinated Universal Time) in minutes and the status showing if DST is active or not. For providing the local date and time information (year, month, day, day in a week, hour, minute, second and lap year), the RTC integrated circuit is built in the meter.

8.3. Communication The device supports several communication technologies for local and remote communication. Communication is provided via integrated communication interface, or via field-exchangeable communication module (shortly communication module). For more information about the modules, see chapter 6. METER MODULES of this document, and technical descriptions of the modules.

8.3.1. Local communication 8.3.1.1. Optical interface (P0) The optical interface operates according to IEC 62056–21 standard as well as DLMS (IEC 62056-46). Every meter has built-in optical interface on the front plate of the meter. The optical interface provides 2-way communication (read and write), and is used for local meter data readouts and settings via PC, laptops or HHU (Hand Held Units) devices by optical probe.

Figure 50: Optical interface

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Figure 51: Optical probe

The IEC 62056-21 optical port communication profile is intended to be used by older HHU devices, where the DLMS protocol is not supported. The DLMS/COSEM communication profile, which operates via IEC 62056-21 optical port, is added to the meter to ensure usage of the same protocol via different communication media. Supported mode is “E” according to the IEC 62056-21 standard.

8.3.1.2. P1 interface (P1) (option) P1 interface is a 1-way read-only communication interface, which operates according to DSMR5 P1 Specification. Meter has one physical field P1 port, on which it is possible to connect more than one OSM (Other Service Module) devices via splitter. The P1 port is mainly intended to connect the In-House Display (IHD) to the E-meter. P1 interface supports three different modes of sending data, depending on the choice of communication mode attribute in a dedicated IEC local port setup object. The default baud rate setting is 115200. Using IEC 62056-21 (IEC 1107) as communication mode, and also IEC 62056-46 (DLMS UA), the E-meter can send data out with the following predefined with objects:   

General local port readout (0-0:21.0.0.*255) Used for defining objects sent out over P1 port. Up to 64 objects can be defined. Consumer message text - Consumer information (0-0:96.13.0*255) Consumer message text is sent to port P1 only. Maximum of 1024 characters in ASCII format. Consumer message code - Meter display (0-0:96.13.1*255) Consumer message code can be shown on P1 port and on the meter display. Maximum size value is 64 (characters).

The AM550 supports IEC 62056-46 (DLMS UA) over P1 which is used as communication protocol. In this case, the E-meter sends data using Consumer Information Push (CIP) functionality according to IDIS Package 2 specification and predefined settings of dedicated CIP objects:  Push setup - Consumer Information (0-6:25.9.0*255)  Push script table (0-0:10.0.108*255)  Push action scheduler – Consumer Information (0-4:15.0.4*255) 

Security Setup – CIP Client Association (0-0:43.0.1*255)



Consumer message text – Consumer information (0-0:96.13.0*255)

The port is activated by activating (raising) the request signal (~5 V). While receiving data the requesting device must keep the request port activated (raised). Using IEC 62056-21 (IEC 1107) or IEC 62056-46 with extensions as communication mode, the E-meter sends data to the P1 port with a period defined in capture_time attribute of the P1 Port Readout list object. When more than one OSM (ex. In-house display) is connected to the meter, each OSM may request data input and all OSM will receive the same data sent by the meter. There is no address for P1 devices and more than one OSM can be connected, activated or not. Dropping the request line by connecting to ground is not allowed, to prevent short circuit. Modulating the request signal is not allowed. Data transfer will stop immediately after the request signal is dropped. V3.00 – English

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8.3.1.3. M-Bus interface (P2) The M-Bus is an interface for gas meter (G-meter), gas valve, thermal (heat/cold) and water meters (W-meter). There is no separate interface for electricity meters (E-meter), since these meters are technically part of the metering system. It enables the communication between several types of meter and an E-meter, to which they are connected. The communication bus is based on the M-Bus standard. The E-meter functions as the communication Master, the other devices connected to the M-Bus function as Slaves. E-meter supports wired M-Bus communication interface and functions as a communication master, while other devices connected to the E-meter function as slaves (Figure 52).

M-Bus Slave 1

M-Bus Slave 2

M-Bus Slave 3

M-Bus Slave 4

AM500 M-Bus Master

Figure 52: M-Bus connection for wired M-Bus devices

The M-Bus is a protocol that is described for remote reading of meters in the European standard EN 13757. It is a two-wire system that provides power to the devices. The requirements for M-Bus are given in the standard EN 13757-2. The bus interfaces of the slaves are polarity independent – the two bus lines can be interchanged without affecting the operation of the M-Bus devices. No physical access for P2 port is possible by consumer. The connections to the M-Bus port are located behind the sealable terminal cover. According to the standard, the E-meter allows a total maximum current consumption of 16 unit loads where one unit load is defined as the maximum mark state current of 1.5 mA.

8.3.1.3.1. Data encryption of user data on M-Bus interface (P2) All M-Bus messages between E-meter and M-Bus devices shall have user data encrypted. Key exchange and Set new address command messages are exceptions and are always sent unencrypted. Also, during installation process, there may be messages sent unencrypted until encryption between E-meter and M-Bus device is established. Encryption modes supported by the E-meter are:  Encryption mode 0 (no encryption);  

Encryption mode 5; Encryption mode 9.

Encryption mode 0 Encryption mode 0 represents an unencrypted message where the user data is sent right after the configuration word. The structure of unencrypted data is presented in Table 28. Field

Configuration word

Unencrypted data

Size

2 bytes

…

Table 28: Structure of unencrypted part of the message, using encryption mode 0

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Encryption mode 5 The encrypted part of the message follows right after the header part. The structure of encrypted data is presented in Table 29. Encryption mode 5 uses the security mechanism AES-CBC-128.

Field

Configuration word

Decryption verification (encrypted)

Encrypted data

Unencrypted data (optional)

Size

2 bytes

2 bytes

16 * NNNN - 2

…

Table 29: Structure of encrypted part of the message, using encryption mode 5

Encryption mode 9 Encrypted part of the message is followed right after the header part. The structure of encrypted data is presented in Table 30. Encryption mode 9 uses the security mechanism AES-GCM-128. GCM is an algorithm for authenticated encryption with associated data. It uses a symmetric key block cipher with block size of 128 bits.

Field

Configuration word

Encrypted length

Unencrypted length

Invocation counter

Size 2 bytes 1 byte 1 byte 4 bytes Table 30: Structure of encrypted part of the message, using encryption mode 9

Encrypted data

GCM authentication tag

N bytes

12 bytes

8.3.2. Remote communication (P3) NOTE Integrated communication (module) and field-exchangeable communication module exclude each other. If a communication module is physically present on the FEM1, integrated communication (as RS-485 or Ethernet) is exluded and cannot be operable, because a communication module physically connected in the FEM1 has the priority over integrated communication interface.

8.3.2.1. RS-485 (option) The AM550 meter can be equipped with integrated RS-485 communication module (refer to chapter 4.2.2.1.1. RS-485 (option)). RS-485 communication interface operates according to IEC 62056–21 (IEC 1107) and IEC 62056-46 (DLMS UA) standards. The RS-485 communication interface typically uses protocol according to IEC 62056-46, which enables connection of up to 31 meters to a RS-485 master device (communicator, modem, RS-485/RS-232 converter …). Each meter in the RS-485 network must have an assigned unique HDLC (High-Level Data Link Control) address. Available HDLC addresses are from 16 to 126. If the IEC 62056–21 (modes A..D) protocol is used, then each meter must have a unique device address (8 octets). The number of connected devices to the network is thus limited by hardware. The RS-485 connection enables communication with only one meter in the RS-485 line at the same time – simultaneous communication with more meters at the same time is not possible. Maximum distance between Master device and the last meter of the RS-485 Master – Slave parallel connection is 1200 m. In some cases, there is no need to connect GND for smaller distances.

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Figure 53: RS-485 Master – Slave parallel connection diagram

8.3.2.1.1. Port setup 8.3.2.1.1.1. IEC Local Port Setup This object includes parameters for RS-485 interface communication. Attributes 1. Logical name 2. Communication mode 3. Default baud rate 4. Proposed baud rate 5. Response time 6. Device address 7. Setting password 8. Parameterization Password 9. W5 password

Data type Octet-string Enum Enum Enum Enum Octet-string Octet-string Octet-string Octet-string

Class ID 19

Code 0-2:20.0.0

Access R R/(W) R/(W) R/(W) R/(W) R/(W) (R)/(W) (R)/(W) (R)/(W)

Min.

Max.

Default

0 0 0 0

2 9 9 1

0 0 5 0 00000000 12345678 12345678 12345678

Table 31: IEC Local Port COSEM Object

Communication Mode Defines the protocol used by the meter on the port. It is possible to select between these modes:  (0) - protocol according to IEC 62056-21 (IEC 1107);  (1) - protocol according to IEC 62056-46 (DLMS UA);  (2) - protocol not specified; proposed baud rate is used for setting the communication speed. Communication Speed The default baud rate is the baud rate for the opening sequence and the proposed baud rate is the baud rate to be proposed by the meter (relevant only for communication mode 0 – IEC1107, modes A to E). Communication speed up to 115200 baud/s is possible. Selection can be made between the following rates:          

(0) – 300 baud (1) – 600 baud (2) – 1200 baud (3) – 2400 baud (4) – 4800 baud (5) – 9600 baud (6) – 19200 baud (7) – 38400 baud (8) – 57600 baud (9) – 115200 baud

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Response Time The Communication response time is the time between the reception of a request and the transmitting of the response. It defines the minimum time between the reception of a request (end of the request telegram) and the transmission of the response (beginning of the response telegram). Two response time options are available:  

(0) – 20 ms; (1) – 200 ms.

Device Address The Device address is intended to identify a meter in the group of meters. Each meter in one group must therefore have a unique number. Eight-digit numbers should be used. Passwords There are three different passwords for communication channels:  Settings password (used in IEC 1107, where the entrance password needs to match this password and one of the four authentication keys). Eight-digit numbers should be used.  Parameterization password (not used).  W5 password (not used).

8.3.2.1.1.2. IEC HDLC Setup Attributes 1. Logical name 2. Communication speed 3. Window size transmit 4. Window size receive 5. Max info field length transmit 6. Max info field length receive 7. Inter octet timeout 8. Inactivity timeout 9. Device address

Data type Octet-string Enum Unsigned8 Unsigned8 Unsigned16 Unsigned16 Unsigned16 Unsigned16 Unsigned16

Class ID 23

Code 0-2:22.0.0

Access R R/(W) R/(W) R/(W) R/(W) R/(W) R/(W) R/(W) R/(W)

Min.

Max.

Default

0 1 1 32 32 20 0 0

9 7 7 2030 2030 6000 65535 65535

5 1 1 154 154 50 120 17

Table 32: IEC HDLC COSEM Object

Communication Speed Selection can be made between the following rates:          

(0) – 300 baud (1) – 600 baud (2) – 1200 baud (3) – 2400 baud (4) – 4800 baud (5) – 9600 baud (6) – 19200 baud (7) – 38400 baud (8) – 57600 baud (9) – 115200 baud

Window Size Transmit The attribute defines the maximum number of frames that a device or system can transmit before it needs to receive an acknowledgement from a corresponding station. During logon, other values can be negotiated. Window Size Receive The attribute defines the maximum number of frames that a device or system can receive before it needs to transmit an acknowledgement to the corresponding station.

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Maximum Info Length Transmit The attribute defines the maximum information field length that a device can transmit. Maximum Info Length Receive The attribute defines the maximum information field length that a device can receive. Inter Octet Time Out The attribute defines the time, expressed in milliseconds, over which, when any character is received from the primary station, the device will treat the already received data as a complete frame. Inactivity Time Out The attribute defines the time, expressed in seconds over which, when any frame is received from the primary station, the device will process a disconnection. When set to 0, this means that the inactivity time out is not operational. Device Address The attribute contains the physical device address of a device. In the case of single byte addressing:     

0x00 0x01…0x0F 0x10...0x7D 0x7E 0x7F

No Station Address Reserved for future use Usable address space ‘Calling’ device address Broadcast address

8.3.2.2. Ethernet (option) The meter can be equipped with integrated Ethernet communication (module) with interface (refer to chapter 4.2.2.1.2. Ethernet (option)), which enables communication with HES. For Ethernet communication, TCP/IP protocol is used. Meter communicates in Ethernet network via IPv4 (internet protocol version 4). IPv6 is not supported. The operation of meter in Ethernet networks is defined and described by a set of parameters and attributes that can be accessed via following COSEM objects:  Ethernet configuration (0-0:128.20.50*255)  Ethernet filter (0-0:128.20.51*255) 

MAC address setup (0-0:25.2.0*255)

  

IPv4 Setup (0-0:25.1.0*255) Ethernet status (0-0:128.20.52*255) Ethernet module diagnostic data (0-0:128.20.53*255)

If COM cursor is defined in Display cursors configuration object – 0-0:196.1.4*255 (refer to chapter 5.1. Display), the meter display status of Ethernet communication via COM cursor on LCD. When Ethernet communication module is active, the meter’s COM cursor acts in the following way:   

it is not displayed if Ethernet link is down, it blinks if Ethernet link is up, but no valid IP address assigned, it is permanently on if meter has valid IP assigned.

Ethernet link status and data transmission/reception can be seen via green-coloured Ethernet LED diodes on front side of the meter cover. For more information, refer to chapter 4.2.2.1.2. Ethernet (option).

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8.3.2.2.1. Ethernet configuration

0-0:128.20.50*255

Ethernet configuration

Logical Name Name Attribute Parameters determination mode

Description The attribute defines if parameters will be determined automatically or manually. Attribute value is enumerated:  (0) Automatic Ethernet communication operates with automatically determined parameters among network devices.  (1) Manual A user can force Ethernet communication to operate with specific speed and duplex settings. It depends on network equipment whether forced communication parameters will be actually used or not. Ethernet The attribute defines if the communication is enabled or disabled. communication Attribute value is enumerated:  (0) Enabled Enabled mode  (1) Disabled Disabling Ethernet communication is implemented for eventual troubleshooting actions since it forces the link to go down and reinitialize after being re-enabled. In order to prevent accidental permanently disabled mode, the meter automatically switches from disabled to enabled mode after 60 seconds. Baud Communication speed attribute. Attribute value is enumerated:

Duplex

 (0) Undefined  (1) 10 Mbps  (2) 100 Mbps It shall be noted, that this speed is only valid for communication within Ethernet network. The actual speed is limited by baud rate between meter and communication module, which is set to 460800 bps for integrated Ethernet communication module. Attribute for setting two-way communication form. Attribute value is enumerated:  (0) Undefined  (1) Half duplex (not simultaneously data transmission)  (2) Full duplex (simultaneously data transmission)

Table 33: Ethernet configuration

8.3.2.2.2. Ethernet filter In heavy loaded networks, we can limit the amount of Ethernet frames coming to the meter application. This could be achieved by setting Ethernet filter mask (0-0:128.20.51*255); see Table 34. Filter mask is bit-oriented value, where specific bit set to 1 signals that frames belonging to some protocols, addresses or other parameters are filtered out by the communication module. When operating in Ethernet network using IPv4, the meter automatically activates all hosts multicast address 224.0.0.1. It means that the meter will accept unconfirmed COSEM service requests on all hosts multicast address.

Bit index

Name

0

CRCEEN

1

RUNTEEN

2 3 4 5 - 32

BROADCAST ARP DHCP ALL HOSTS 31 MCAST DISABLE Table 34: Ethernet filter

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Description If filter mask is set, packets with wrong CRC are accepted by the module (filter must be normally disabled to comply with IEEE 802.3, enable only for diagnostic). If filter mask is set, packet shorter than 64 bytes are accepted by the module (filter must be normally disabled to comply with IEEE 802.3, enable only for diagnostic). If filter mask is set, all broadcast packets are dropped by the module. If filter mask is set, all ARP packets are dropped by the module. If filter mask is set, all DHCP packets are dropped by the module. Unused If filter mask is set, the meter deactivates all hosts multicast address (224.0.0.1).

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8.3.2.2.3. MAC address setup Every Ethernet communication module is equipped with unique MAC address, which is defined during production. It can be read by MAC address setup object (0-0:25.2.0*255).

8.3.2.2.4. IPv4 Setup The meter’s behaviour inside Ethernet network also depends on configuration of IPv4 setup object (0-0:25.1.0*255). Logical Name Name Attribute DL reference

IP address

0-0:25.1.0*255

IPv4 setup

Multicast IP address

Description References a Data link layer (e.g. Ethernet or PPP) setup object by its logical name. The referenced object contains information about the specific settings of the data link layer supporting the IP layer. This attribute has impact on PUSH operation. When PUSH is to be sent via Ethernet communication, this attribute has to reference MAC address setup object. IP address (IPv4) of the meter: the attribute carries the value of the IP address (IPv4) of the meter when connected to IP network. If no IP address is assigned, the value is 0.  Static IP address: this attribute can be written to a valid IP address if static addressing is used.  Dynamic IP address: when dynamic addresses are used, this attribute present IP address assigned to the meter by external DHCP server. Static/dynamic IP address configuration is also determined by “Use DHCP flag” attribute. Used to configure one user-defined multicast IPv4 address, by which the meter can be addressed. Multicast addressing only works with unconfirmed services, therefore UDP and pre-established COSEM association must be used.

Parameters to NOT used by the meter. support the selected IP options Subnet mask Presents the subnet mask of the connected network when dynamic addressing is used, or address written in the meter when static addressing is used. Gateway IP address Use DHCP flag

Presents the IP address of a gateway in the connected network when dynamic addressing is used, or address written in the meter when static addressing is used. Used to configure the meter to operate with dynamic IP address.

 When set to True or “IP address” attribute is written with 0.0.0.0, the meter will activate DHCP client in order to get dynamically assigned IP address from external DHCP server.  When set to False (default), the meter will use “IP address” attribute value as its static IP address. Primary IP address of the primary Domain Name Server reported by the network when dynamic DNS address addressing is used or address written in the meter when static addressing is used. Secondary IP address of the secondary Domain Name Server reported by the network when dynamic DNS address addressing is used or address written in the meter when static addressing is used.

Table 35: IPv4 setup

8.3.2.2.5. Ethernet diagnostic information The Ethernet diagnostic information are provided by the meter and the data are generated from last power up and lost with power down. With meter power up, diagnostic data generation starts from the beginning. Meter presents diagnostic information in two dedicated objects:  Ethernet status (0-0:128.20.52)  Ethernet module diagnostic data (0-0:128.20.53)

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8.3.2.2.5.1. Ethernet status

0-0:128.20.52*255

Ethernet status

Logical Name Name Attribute Status

Description Indicates status of the Ethernet link. Attribute value is enumerated:  (0) Ethernet link down  (1) Ethernet link up  (255) Unknown Parameters Indicates parameters determination mode. Attribute value is enumerated: determination  (0) Automatic mode  (1) Manual Ethernet Indicates if Ethernet communication is enabled or disabled. Attribute value is enumerated: communication  (0) Enabled  (1) Disabled Baud Indicates communication speed. Attribute value is enumerated:  (0) Undefined  (1) 10 Mbps  (2) 100 Mbps Duplex Indicates communication form. Attribute value is enumerated:  (0) Undefined  (1) Half duplex (not simultaneously data transmission)  (2) Full duplex (simultaneously data transmission)

Table 36: Ethernet status (0-0:128.20.52)

8.3.2.2.5.2. Ethernet module diagnostic data

0-0:128.20.53*255

Ethernet module diagnostic data

Logical Name Name Attribute ifInOctets ifInUcastPkts

Byte index Content 0–3 The total number of octets received on the network interface of Ethernet communication module, including framing characters. 4–7 The number of subnetwork-unicast packets delivered to a higher-layer protocol by Ethernet communication module.

ifInNUcastPkts 8–11

The number of non-unicast (i.e., subnetwork-broadcast or subnetworkmulticast) packets delivered to a higher-layer protocol by Ethernet communication module.

ifInDiscards

The number of inbound packets, which were chosen to be discarded even though no errors had been detected to prevent their being deliverable to a higher-layer protocol in Ethernet communication module.

12–15

8.3.2.2.5.3. Additional diagnostic data related to IP communication Meter provides additional diagnostic information gathered from different layers of communication protocol stack. Additional diagnostic data can be read via the following dedicated objects:  Network interface diagnostic data object (0-0:128.20.60)  IP layer diagnostic data object (0-0:128.20.61)   

ICMP layer diagnostic data object (0-0:128.20.62) TCP layer diagnostic data object (0-0:128.20.63) UDP layer diagnostic data object (0-0:128.20.64)

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8.4. Push Generally, communications run from the central system (Client) to the meter (Server). In contrast, in Push operation, communication runs from the meter (Server) to the central system (Client), where the meter initiates the communication and pushes information to the central system without any request. In some cases, Push can also be requested by the central system (Client). The Push method activates the push process leading to the elaboration and the sending of the push data taking into account the values of the attributes defined in dedicated Class. For different push triggers, the following objects are implemented:            

Push setup – On Connectivity Push setup – Interval_1 Push setup – Interval_2 Push setup – Interval_3 Push setup – On Alarm Push setup – On power down Push setup – On Installation Push setup – Consumer Information Push action scheduler – Interval_1 Push action scheduler – Interval_2 Push action scheduler – Interval_3 Push action scheduler – Consumer Information



Push script table

Push setup – On connectivity (0-0:25.9.0*255) is used after the PDP context is established. The meter sends its IP address and system title, using the Data_notification service, to the HES. Push setup – Interval 1, 2, 3 (0-1:25.9.0*255; 0-2:25.9.0*255; 0-3:25.9.0*255) can be used for various periodical data reporting (profiles, billing, etc.). Push setup – On alarm (0-4:25.9.0*255) is used to send alarms and/or for sending Quality of Supply data and/or Meter supervision data to the HES using the Data_notification service. Push setup – On power down (0-5:25.9.0*255) is optional and is used to inform HES that meter is going to power down and/or for sending Quality of Supply data. Using the Data_notification service, the meter send its IP address and its system title to the HES. See chapter 8.4.1. Push on Power down (Last gasp) for more information. Push setup – On installation (0-7:25.9.0*255) is used to inform HES that meter is installed to the system (e.g. meter sends its IP address and its system title to the HES using the Data_notification service). Push setup – Consumer information (0-6:25.9.0*255) is used to transmit information to local P1 port (i.e. IHD) serving as Consumer Information Interface (CII) to support the optional Consumer Information Push (CIP) functionality. The Field Send destination and method need to be properly set. Depending on the market request, this local port may be connected to a suitable home gateway. Push action scheduler – Interval 1, 2, 3 (0-1:15.0.4*255; 0-2:15.0.4*255; 0-3:15.0.4*255) are used to periodically invoke the Push script table (0-0:10.0.108*255) with a predefined selector to trigger push method on dedicated Push setup object. Push action scheduler – Consumer information (0-4:15.0.4*255) is used for dedicated CIP functionality. The scheduler defines the time instances when the meter is pushing information to the CII. Push script table (0-0:10.0.108*255) contains scripts which are used to trigger a push method on configured Push setup objects.

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8.4.1. Push on Power down (Last gasp) Push on Power down (Last gasp) presents a functionality, which detects full power outage, generates and sends a notification message from the meter to the HES. The meter detects a full power down within 3 seconds. The push is sent only if the meter is powered-up for at least 60 minutes. This function is implemented on both, one- and three-phase meters. 

For one-phase meters, the Push on Power down message is the only message sent in case of either phase or neutral missing, or both.



For three-phase meters, the Push on Power down message will be sent only in case of full power outage. In case of partial power outage (one or two phases missing), an event is stored in the Event log. No message is sent.

Message characteristics:   

Push Alarm according to IDIS P2; the message is sent only once; it is not possible to identify whether message was delivered or not – TCP/IP. Message encryption and identification: not available. Message content: Identification of Full power outage.

NOTES     

The Push on Power down functionality is intended for meters with GSM/GPRS communication module equipped with a back-up ultracapacitor. The power good timer is started at the modem detection. Due to GSM/GPRS modem limitation, the SMS should be used as service type to successfully send Data_notification at power down. If Push on Power Down is not finished due to lack of energy, then it is suspended. If the meter runs for less than 60 minutes and power down occurs, the meter only disconnects from the GPRS network (Data_notification is not sent). If power down elapsed time is more than 40 seconds, the meter starts the disconnect-from-GPRS-network procedure.

8.4.1.1. Enabling and disabling Push on Power down (Last gasp) The Push on Power down functionality may be turned on, or off. Its usage is optional. It is enabled when all of the following is true:  Attribute “Push object list” in the Push setup – On power down (0-5:25.9.0*255) object has a value;  

Attribute “Send destination and method” in the Push setup – On power down (0-5:25.9.0*255) object has a value; The value set in object Power failure alarm filtering limit [s] (1-0:96.239.0*255) is less than 40 s.

If at least one of the above requirements is not met, Push on Power down is disabled.

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8.5. Fraud detection 8.5.1. Meter cover open, terminal cover open, communication-module cover open These detectors (switches) trigger an event and alarm that lets the user know if and when the terminal block cover, the communication module cover or the meter cover were opened. The meter-cover detector is located on the PCB (Printed Circuit Board) near the communication-module-cover detector, and it is not visible from outside, due to closed meter cover. When a certain event and alarm is triggered, the next event of the same type can be triggered after set time period (the time period is set in object Fraud detection hold-off period (1-0:96.245.10); default value is 900 seconds (15 minutes)).

Figure 54: Terminal-cover-opening detector position on one-phase meter

Figure 55: Terminal-cover-opening detector position on three-phase meter

Figure 56: Communication-module-cover opening detector

8.5.2. Magnetic field detection The Magnetic field detector (reed relay) triggers a magnetic field detected event (fraud detection log event 42) and no more magnetic field detection event (fraud detection log event 43) that is recorded in fraud detection event log if and when there was an external magnetic field near the meter. This is used for security reasons as someone might try to influence the meter’s accuracy. When the corresponding event and alarm is triggered, the next event of the same type can be triggered after set time period (the time period is set in object Fraud detection hold-off period (1-0:96.245.10); default value is 900 seconds (15 minutes)). V3.00 – English

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8.6. Load profiles A Load profile can capture any of the basic type object value present in the meter. Each profile has an internal memory space to store captured data, therefore it has a limit of stored data. The more capture objects we select, less total captured data is possible to store. After a call of the reset method, the buffer does not contain any entries, and this value is zero. Profile entries attribute specifies how many entries could be retained in the buffer. Entries in use attribute counts the number of entries stored in the buffer. In a Load profile, up to 32 objects (including clock and status) can be registered. Maximum profile capacity mainly depends on the number of capture objects set. Data in a load-profile recorder are accompanied with a timestamp and with the meter status in the last saving period as well as with a check sum. The timestamp indicates the end of a registration period. The profile is compressed type – only one (first) timestamp is shown. Compressed type allows more data to be store. Profile is implemented as FIFO (First In, First Out) buffers. Each record has associated a unique record number. Within a load profile, more records can have same timestamp (in case time is shifted back) but all have different record numbers. When reading load profiles, records are being put out according to their record number in increasing order. Each load profile has the following general structure: 1. Clock 2. Status (specific per load profile) 3. Captured values (maximum 30 objects)

NOTES  Profile is erased when new attribute capture period, capture objects, or profile entries are set. 

Demand registers should only be used in billing profiles.



When master reset is performed, profiles are not immediately reset. After power-down and power-up, the profiles are cleared and default capture objects are set.



If profile is empty (value 0), then profile cleared event (254) will not be recorded if resetting (erasing) of profile is triggered.

All supported profiles in the meter are listed in Table 37. Object name (profile name)

OBIS code

Load profile with period 1, i.e. General load profile

1-0:99.1.0*255

Load profile with period 2, i.e. Daily values profile

1-0:99.2.0*255

Data of billing period 1

0-0:98.1.0*255

Data of billing period 2

0-0:98.2.0*255

Power quality profile

1-0:99.14.0*255

M-Bus master load profile for channel 1

0-1:24.3.0*255 0-2:24.3.0*255

M-Bus master load profile for channel 2 M-Bus master load profile for channel 3

0-3:24.3.0*255

M-Bus master load profile for channel 4

0-4:24.3.0*255

Table 37: All supported profiles in meter

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8.6.1. E-meter-related load profiles (definable load profiles)   

Load profile with period 1 (1-0:99.1.0*255); 15 min values; up to 32 objects can be defined Load profile with period 2 (1-0:99.2.0*255); daily values; up to 32 objects can be defined Power Quality Profile (1-0:99.14.0*255); 10 min values; up to 32 objects can be defined NOTE Integration period and capture objects of all above listed load profiles are settable.

Capture Objects By default, capture objects of load profiles are set to:  in Load profile with period 1 (1-0:99.1.0*255): - Clock (0-0:1.0.0*255), attribute 2 - Profile status 0 - Load profile with period 1 (0-0:96.10.1*255), attribute 2 - Active energy import (+A) (1-0:1.8.0*255), attribute 2 (active energy plus) - Active energy export (-A) (1-0:2.8.0*255), attribute 2 (active energy minus) 

in Load profile with period 2 (1-0:99.2.0*255): - Clock (0-0:1.0.0*255), attribute 2 - Profile status 1 - Load profile with period 2 (0-0:96.10.2*255), attribute 2 - Active energy import (+A) Rate 1 (1-0:1.8.1*255), attribute 2 (active energy plus, tariff 1) - Active energy import (+A) Rate 2 (1-0:1.8.2*255), attribute 2 (active energy plus, tariff 2) - Active energy export (-A) Rate 1 (1-0:2.8.1*255), attribute 2 (active energy minus, tariff 1) - Active energy export (-A) Rate 2 (1-0:2.8.2*255), attribute 2 (active energy minus, tariff 2)

For capture objects of Power Quality Profile, see chapter 8.6.2. Billing load profile. Capture Period – see chapter 8.6.1.1. Capture period. Sort Method is an attribute for sorting captured data. It is fixed to FIFO (First in First Out). Sort Object attribute uses Clock object as sort object. Entries in Use attribute shows how many recordings have been made and are recorded (captured). Profile Entries attribute shows how many recordings are possible in the meter. Specific Method – Billing profile has two methods implemented: 

Reset (erases captured values)



Capture (new records are stored).

8.6.1.1. Capture period Capture period is variable, which defines the time distance between two captured data’s. It can be set to following values (in seconds):       

0 – No registration 300 – 5 minute recording period 600 – 10 minute recording period (default value of Power Quality Profile) 900 – 15 minute recording period (default value of Load profile with period 2) 1800 – 30 minute recording period 3600 – 1 hour recording period 86400 – 1 day recording period (default value of Load profile with period 1)

The period is synchronized with the hour; it always begins at completed hour. Load profiles are dynamically organized, meaning the lesser capture objects are chosen, the higher roll over time is, and vice versa.

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8.6.1.2. Profile status Profile status objects are specific according to a load profile:  Profile status 0 – Load profile with period 1 (0-0:96.10.1*255)  Profile status 1 – Load profile with period 2 (0-0:96.10.2*255)  

Profile status 2 – Data of billing period 1 (0-0:96.10.3*255) Profile status 3 – Data of billing period 2 (0-0:96.10.4*255)



Profile status 7 – Power Quality Profile (1-0:96.10.1*255)

The state and the function of all bits are described in Table 38. If one of the events defined in the Table 38 has occurred during capture period, corresponding event code is added to the profile status register. By adding event codes to the profile status register all events occurred during capture period are stored to the profile buffer at the end of capture period. After storing a value of profile status register in the profile buffer meter resets profile status register to zero value. These status notifications shown in load profile readout are listed in the Table 38 Bit B0 B1

Status Critical error Clock invalid

B2

Data not valid

B3 B4 B5 B6 B7

Daylight saving Unused Clock adjusted Unused Power down

Description A serious error such as a hardware failure or a checksum error has occurred. The power reserve of the clock has been exhausted. The time is declared as invalid. Indicates that the current entry may not be used for billing purposes without further validation, because a special event has been occurred. Indicates that daylight savings is enabled. Reserved: The reserved bit is always set to 0. The bit is set when clock has been adjusted more than the synchronization limit. Reserved: The reserved bit is always set to 0. This bit is set to indicate that an all-phase power failure occurred.

Table 38: Profile status register notifications

8.6.2. Billing load profile The Billing functionality provides a process and storage for managing billing data. There are two billing object implemented in the meter:  Data of billing period 1 (0-0:98.1.0*255); up to 32 objects can be defined  Data of billing period 2 (0-0:98.2.0*255); up to 32 objects can be defined When the capture method is executed, capture objects values are stored in billing profile. Capture Objects By default, capture objects are set to:  Clock (0-0:1.0.0*255), attribute 2 



In Data of billing period 1: Profile status 2 – Data of billing period 1 (0-0:96.10.3*255), attribute 2 or In Data of billing period 2: Profile status 3 – Data of billing period 2 (0-0:96.10.4*255), attribute 2 Active energy import (+A) Rate 1 (1-0:1.8.1*255), attribute 2 (active energy plus, tariff 1)



Active energy import (+A) Rate 2 (1-0:1.8.2*255), attribute 2 (active energy plus, tariff 2)



Active energy export (-A) Rate 1 (1-0:2.8.1*255), attribute 2 (active energy minus, tariff 1)



Active energy export (-A) Rate 2 (1-0:2.8.2*255), attribute 2 (active energy minus, tariff 2)

Capture Period is set to 0 because records are recorded according to end of billing period. Sort Method is an attribute for sorting captured data. It is fixed to FIFO (First in First Out). Sort Object attribute uses Clock object as sort object. Entries in Use attribute shows how many recordings have been made and are recorded (captured). Profile Entries attribute shows how many recordings are possible in the meter. V3.00 – English

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Specific Method – Billing profile has two methods implemented: 

Reset (erases captured values)



Capture (new records are stored). NOTE Integration period and capture objects of both above listed billing load profiles are settable.

End of billing with MDI reset / End of billing period (0-0:10.0.1*255) object can be executed:  

Manually – by executing Script 1 or Script 2 (of this object) using one of available communication channels (see Figure 57) or Automatically – using End of billing period 1 scheduler (0-0:15.0.0*255) and End of billing period 2 scheduler (0-0:15.1.0*255) objects, where for Script 1, Selector value is set to 1, and for Script 2, Selector value is set to 2.

Figure 57: Manually executing MDI reset / End of billing period

When one of the script (Script 1, Script 2) of MDI reset / End of billing period is executed, actions for Billing profiles are carried out by the meter. List of actions executed by Script 1 and list of actions executed by Script 2 can be seen in the Table 39. Action

Script 1

Script 2

Execute capture method for Billing profile

Yes

Yes

Reset maximum demand registers

Yes

No

Reset minimum power factor (value is set to 1)

Yes

No

Increment counter in the Billing period counter (1-0:0.1.0*255) object

Yes

No

Create event in event log-to-log execution of billing reset

Yes

No

Table 39: Billing profile – action list of Script 1 and of Script 2

NOTE Reset of maximum demand registers is done only when Script 1 of “MDI reset / End of billing period (0-0:10.0.1*255)” object is executed.

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8.6.3. Multi-utility-related load profiles  

Hourly load profile for each of the 4 M-Bus channels Daily load profile for each of the 4 M-Bus channels

M-Bus master load profiles have hourly interval readings of M-Bus devices. The buffer is filled monotonously, no irregular entries are allowed. Captured objects include clock, status and M-Bus value objects. M-Bus master load profile for channel x (0-x:24.3.0*255) is one object for each of four channels (x=1-4). Capture Objects can hold maximum 8 objects. Capture Period defines the time distance between two captured data. The period is synchronized with the hour; it always begins at completed hour. Default value (in seconds) is set to 3600 (min. value = 0; max. value = 86400) Sort Method attribute is used for sorting captured data. It is fixed to FIFO (First in First Out). Sort Object attribute uses Clock object as sort object. Entries in Use attribute shows how many recordings have been made and recorded (captured). Profile entries attribute shows how many recordings are possible in the e-meter. Reset method erases captured values from the profile.

NOTE M-Bus load profile is erased when new capture period or capture objects are set.

Capturing of M-Bus load profiles can be enabled or disabled by Function activation functionality (see chapter 8.15. Function activation). It can be done on demand via Function activation object (0-0:44.1.0*255) or programmed with Function activation control scheduler object (0-0:15.0.7*255).

NOTE By default, hourly M-Bus load profile is disabled by function activation.

8.6.3.1. Profile status for M-Bus load profile Profile status for M-Bus load profile is available by four objects (for each channel) named Profile status for M-Bus master load profile x (0-x:96.10.3*255, where x stands for channel 1–4) The state and the function of all bits are described in Table 38.

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8.7. Event logs Basic principle is shown in the diagram (Figure 58).

Figure 58: Event handling

Events are generated by the meter itself or by its environment. All these events are logged in several event logs. Every event has a unique code to identify the action, which has triggered it. Every event is assigned to one event log and it is only stored there. The E-meter features ten different event logs as described below. All logs, except the Security event log and Image activation log, have the same basic structure (timestamp and event code). The structure per event log is fixed, i.e. it is not possible to store different parameters per event.

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8.7.1. Event Code Objects Events are generated by the meter itself of by its environment. Each type of an event is presented with a unique code (event code) to identify the action, which has triggered it. Event codes are stored in corresponding Event code objects. Each event object holds only the most recent event. The event code object has the value of 255 until the first event is detected/generated by the meter, or every time a power up is performed. The meter provides the event code objects listed in Table 40. Event code object

Logical name

Event object – Standard event log

0-0:96.11.0*255

Event object – Fraud detection log

0-0:96.11.1*255

Event object – Disconnector control log

0-0:96.11.2*255

Event object – M-Bus event log

0-0:96.11.3*255

Event object – Power quality log

0-0:96.11.4*255

Event object – Communication event log

0-0:96.11.5*255

Event object – Communication details log

0-0:96.11.6*255

Event object – Security event log

0-0:96.11.7*255

Event object – Image activation log

0-0:96.11.8*255

Event objects – M-Bus master control logs1

0-1:96.11.4*255

Event objects – M-Bus master control logs2

0-2:96.11.4*255

Event objects – M-Bus master control logs3

0-3:96.11.4*255

Event objects – M-Bus master control logs4

0-4:96.11.4*255

Table 40: Event code objects

Attributes

Data type

Class ID

Code

Access

1. logical_name

octet_string[6]

1

0-y:96.11.x*255

R

2. value

enum

R

Min.

Max.

Default

0

255

255

Table 41: Event code objects COSEM object

8.7.2. Event Log Objects Instances of event code objects are captured in corresponding event logs. Event log objects are instances of COSEM class “profile generic” and are used to store events. They are organized as FIFO buffers, where records are sorted by time. Once the buffer is full, the oldest entry in the buffer is the first to be replaced. The capacity (maximum number of records in a buffer) of the event log objects varies from object to object. Records in the buffer are captured asynchronously, as the events occur. The majority of the supported event log objects (with the exception of Power failure event log) follow the same basic structure containing the timestamp (time of the occurrence of the event) and the event code object. A more detailed structure of the event log along with additional explanation:  Buffer: Contains a sequence of entries, where each entry contains values of the captured objects.  Captured objects: Defines the objects and the corresponding attributes, which are to be copied into the buffer (the value is event log specific).  Capture period: Set to 0, because events are triggered and recorded as they occur.  Sort method: Captured data is organized as FIFO (first in first out) and cannot be changed. 

Sort Object: Captured data is sorted using the Clock object (0-0:1.0.0*255).

  

Entries in use: Counts the number of entries in the buffer. Profile entries: Specifies how many entries can be retained in the buffer (the capacity of the event log). Specific methods: Reset and Capture methods are implemented.

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The meter features the following event log objects (see Table 42). Event log object

Logical name

Capacity

Standard event log

0-0:99.98.0*255

100

Fraud detection log

0-0:99.98.1*255

30

Disconnector control log

0-0:99.98.2*255

30

M-Bus event log

0-0:99.98.3*255

30

Power quality log

0-0:99.98.4*255

100

Communication event log

0-0:99.98.5*255

255

Communication details log

0-0:99.98.6*255

100

Security event log

0-0:99.98.7*255

100

Image activation log

0-0:99.98.8*255

100

Power failure event log

1-0:99.97.0*255

10

Certification data log

1-0:99.99.0*255

100

M-Bus master control log object 1

0-1:24.5.0*255

11

M-Bus master control log object 2

0-2:24.5.0*255

11

M-Bus master control log object 3

0-3:24.5.0*255

11

M-Bus master control log object 4

0-4:24.5.0*255

11

Captured objects 0-0:1.0.0*255 0-0:96.11.0*255 0-0:1.0.0*255 0-0:96.11.1*255 0-0:1.0.0*255 0-0:96.11.2*255 0-0:1.0.0*255 0-0:96.11.3*255 0-0:1.0.0*255 0-0:96.11.4*255 0-0:1.0.0*255 0-0:96.11.5*255 0-0:1.0.0*255 0-0:96.11.6*255 0-0:40.0.0*255 (index 1) 0-0:40.0.0*255 (index 2) 0-0:128.100.38*255 0-0:96.15.0*255 0-0:96.15.1*255 0-0:96.15.2*255 0-0:96.15.3*255 0-0:96.15.4*255 0-0:96.15.5*255 0-0:96.15.6*255 0-0:96.15.7*255 0-0:96.15.8*255 0-0:96.15.9*255 0-0:96.15.10*255 0-0:1.0.0*255 0-0:96.11.7*255 0-0:128.100.39*255 0-0:1.0.0*255 0-0:96.11.8*255 0-0:96.128.10*255 0-0:1.0.0*255 0-0:96.7.19*255 0-0:1.0.0*255 0-0:96.128.0*255 0-0:96.128.1*255 0-0:96.128.2*255 0-0:1.0.0*255 0-1:96.11.4*255 0-0:1.0.0*255 0-2:96.11.4*255 0-0:1.0.0*255 0-3:96.11.4*255 0-0:1.0.0*255 0-4:96.11.4*255

Table 42: Event log objects

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8.7.2.1. Standard event log Standard event log (0-0:99.98.0*255) contains all events that are not recorded in other special event logs, e.g. changes of the clock, changes of the configuration, clearing of profiles, all kind of self-check errors, activation of new parameters, activation of new time of use, etc. Standard event log structure consists of timestamp and event code. The Event object – Standard event log object (0-0:96.11.0*255) holds the code from the last event triggered. See Table 42.

Figure 59: Example of Standard event log buffer content

8.7.2.2. Fraud detection log Fraud detection log object (0-0:99.98.1*255) contains all events related to the detection of fraud attempts, e.g. removal of terminal cover, removal of meter cover, strong DC field detection, access with wrong password, etc. There is a 15-minute (900 s) hold-off period between two events. The hold-off period is started at fraud event, which disables another logging of same fraud event for its duration. This prevents filling the fraud detection log too quickly with repeating the same fraud events. The hold-off period between two events is set in the object 1-0:96.245.10*255. Default setting is 0. The Event object – Fraud detection log object (0-0:96.11.1*255) holds the code from the last event triggered. See Table 42.

Figure 60: Example of Fraud detection log buffer content

Example: When strong DC field is detected, the event is saved in the fraud log and time interval is started. DC field is then removed, event is saved in the fraud log, and another time interval is started. For the next 15 minutes, no such event is recorded if we apply and remove DC field. We can apply strong DC field that will not be marked with event, wait until the time interval for DC removed runs out and then remove DC field. Event will be logged in fraud log and time interval will be started again. V3.00 – English

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9:00 strong DC field detected - event 42 saved in fraud log 900s time interval for DC ON started 9:01 strong DC field removed - event 43 saved in fraud log 900s time interval for DC OFF started 9:14 strong DC field detected - logging of event 42 is blocked! Time interval for DC ON ends, time interval for DC OFF ends 9:17 strong DC field removed - event 43 saved in fraud log 900s time interval for DC OFF started

8.7.2.3. Disconnector control log Disconnector control log (0-0:99.98.2*255) contains all events related to the switching device, e.g. connect, disconnect, changing of the switching device threshold. Disconnect control log structure contains timestamp and event code. The Event object – Disconnector control log object (0-0:96.11.2*255) holds the code from the last event triggered. These codes along with timestamps are then used in event log. See Table 42.

Figure 61: Example of Disconnector control log buffer content

8.7.2.4. M-Bus event log M-Bus event log (0-0:99.98.3*255) contains errors and alarms related to M-Bus devices (e.g. changes of the clock, communication errors, fraud attempt, etc.). The buffer must be filled monotonously, i.e. no irregular entries are allowed. M-Bus Event Log structure consists of Timestamp and Event Code. See Table 42.

8.7.2.5. Power quality log Power quality log (0-0:99.98.4*255) contains all events related to power quality. The Power quality event log structure consists of timestamp and event code. The Event object – Power quality log object (0-0:96.11.4*255) holds the code from the last event triggered. See Table 42.

Figure 62: Example of Power quality log buffer content

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8.7.2.6. Communication event log Communication event log (0-0:99.98.5*255) object contains all events related to communication, e.g. no connection timeout, modem related events (modem reset, initialization failure, SIM failure, GSM/GPRS registration failure…), auto answer. Communication event log structure consists of timestamp and event code. Description of the attributes and methods for this object is the same as for standard Event object – Communication event log object (0-0:96.11.5*255). It holds the code from the last event triggered. These codes along with timestamps are then used in event log. See Table 42.

Figure 63: Example of Communication event log buffer content

8.7.2.7. Communication details log The Communication details log (0-0:99.98.6*255) registers the communication sessions (Event Object– Communication Details Log, 0-0:96.11.6*255) on the local and remote interface and provides an access statistic for different groups of attributes and methods (Event Counter Objects).

Figure 64: Example of Communication details log buffer content

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Capture Objects When an event is triggered, the timestamp and event-code set are recorded in this attribute. By default, capture objects are set to:  0-0:1.0.0*255, attribute 2 (System Time)    

0-0:96.11.6*255, attribute 2 (Event Object – Communication Details Log) 0-0:40.0.0*255, attribute 3, index 1 (Current Association Client SAP) 0-0:40.0.0*255, attribute 3, index 2 (Current Association Server SAP) 0-0:128.100.38*255, attribute 2 (Current Client System Title)

 

0-0:96.15.0*255, attribute 2 (Event counter Object 1 – E-Meter Global Total) 0-0:96.15.1*255, attribute 2 (Event counter Object 2 – E-Meter Billing Total)

  

0-0:96.15.2*255, attribute 2 (Event counter Object 3 – E-Meter Load Profile Reading Total) 0-0:96.15.3*255, attribute 2 (Event counter Object 4 – M-Bus Device 1 Billing Total) 0-0:96.15.4*255, attribute 2 (Event counter Object 5 – M-Bus Device 1 Load Profile Reading Total)

 

0-0:96.15.5*255, attribute 2 (Event counter Object 6 – M-Bus Device 2 Billing Total) 0-0:96.15.6*255, attribute 2 (Event counter Object 7 – M-Bus Device 2 Load Profile Reading Total)



0-0:96.15.7*255, attribute 2 (Event counter Object 8 – M-Bus Device 3 Billing Total)



0-0:96.15.8*255, attribute 2 (Event counter Object 9 – M-Bus Device 3 Load Profile Reading Total)

 

0-0:96.15.9*255, attribute 2 (Event counter Object 10 – M-Bus Device 4 Billing Total) 0-0:96.15.10*255, attribute 2 (Event counter Object 11 – M-Bus Device 4 Load Profile Reading Total)

Capture Period Capture period is set to 0 because events are triggered and recorded as they occur. Period different from 0 is meaningless. Sort Method Attribute for sorting captured data. It is fixed to FIFO (First in, First Out). Sort Object Clock object is used as sort object. Entries in Use This attribute shows how many recordings have been made and are recorded (captured). Profile Entries This attribute shows how many recordings are possible in the meter. This number depends on the capture period selected and number of capture objects set. Specific Methods Object has two methods implemented:  Reset (erases captured values)  Capture (not implemented)

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8.7.2.8. Security event log Security event log contains all events related to security part. It has three capture objects: Clock (0 0:1.0.0*255), Event object – Security event log (0-0:96.11.7*255), Client SAP (0-0:128.100.39*255). The Client SAP shows association number, which is attached in the event time. When the event is triggered in time of without association then the Client SAP value is set to 0. See Table 42.

Figure 65: Example of Security event log buffer content

NOTE The security-event-log buffer cannot be reset.

Events logged in the security event log and fraud event log simultaneously have same hold-off period between two events as defined for fraud events in chapter 8.7.2.2. Fraud detection log.

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8.7.2.8.1. Security event counters Each security event has a dedicated security event-counter object, which is counting the occurrence of each security related event. When number of security event occurrences overflows maximum counter value, a special overflow counter (0-0:96.15.30*255) is increased by one. Security event-counter values are stored in a dedicated COSEM objects as shown in Table 43. OBJECT NAME Event overflow Event 1 Event 2 Event 4_5 Event 6 Event 10 Event 11 Event 12 Event 13 Event 14 Event 15 Event 17 Event 18 Event 38 Event 39 Event 40 Event 41 Event 42 Event 43 Event 44 Event 45 Event 46 Event 48 Event 49 Event 50 Event 51 Event 59 Event 60 Event 61 Event 62 Event 63 Event 64 Event 105 Event 115 Event 125 Event 128 Event 135 Event 238 Event 246 Event 247 Event 248 Event 249 Event 250 Event 244 Event 245 Event 226 Event 227 Event 228

Logical name 0-0:96.15.30*255 0-0:96.15.31*255 0-0:96.15.32*255 0-0:96.15.33*255 0-0:96.15.34*255 0-0:96.15.35*255 0-0:96.15.36*255 0-0:96.15.37*255 0-0:96.15.38*255 0-0:96.15.39*255 0-0:96.15.40*255 0-0:96.15.41*255 0-0:96.15.42*255 0-0:96.15.43*255 0-0:96.15.44*255 0-0:96.15.45*255 0-0:96.15.46*255 0-0:96.15.47*255 0-0:96.15.48*255 0-0:96.15.49*255 0-0:96.15.50*255 0-0:96.15.51*255 0-0:96.15.52*255 0-0:96.15.53*255 0-0:96.15.54*255 0-0:96.15.55*255 0-0:96.15.56*255 0-0:96.15.57*255 0-0:96.15.58*255 0-0:96.15.59*255 0-0:96.15.60*255 0-0:96.15.61*255 0-0:96.15.62*255 0-0:96.15.63*255 0-0:96.15.64*255 0-0:96.15.65*255 0-0:96.15.66*255 0-0:96.15.67*255 0-0:96.15.68*255 0-0:96.15.69*255 0-0:96.15.70*255 0-0:96.15.71*255 0-0:96.15.72*255 0-0:96.15.91*255 0-0:96.15.92*255 0-0:96.15.93*255 0-0:96.15.94*255 0-0:96.15.95*255

For object names of events, see Table 44; find event number in column “IDIS event code” and read its “Event name” (example: “Event 18” = “Firmware activated”)

Table 43: Security Event Counters COSEM Objects

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8.7.2.9. Image activation data log The Image Activation Log (0-0:99.98.8*255) is special log, used for events related to the E-meter image activation. It has three capture objects:  Clock (0-0:1.0.0*255), 

Event object – Image Activation Log (0-0:96.11.8*255),



Log Image version (0-0:96.128.10*255).

In the image activation log, two events can be logged: Firmware activated Indicates that a new firmware has been activated  18 LR firmware activated Indicates that the LR firmware is activated  228 The image version of the firmware, which runs in the meter, is recorded as well. For this application, the specific object (0-0:96.128.10*255) is introduced. Log image version holds the information about new firmware version, which is activated on the meter. The following firmware versions are recorded:  LR (CORE) (C: CORE) of the meter 

Application (MODULE) (A: APP)



CLR Application (R:NATIONAL LRFW)

Capacity of this event log is 100 events. The meter image activation is not possible when log buffer is full.

Figure 66: Example of image activation log buffer content

8.7.2.10. M-Bus master control logs The M-Bus master control log (0-x:24.5.0*255), where x represents one of the M-Bus channels (from 1 to 4), indicates both states (connected, disconnected) of disconnector and valve alarm registrations. See Table 42.

8.7.2.11. Power failure event log Power failure event log (1-0:99.97.0*255) contains records of long power failure events. If there is a power outage longer than specified in object Time threshold for long power failure (0-0:96.7.20*255), a new record is logged in next power-up, consisting of timestamp and duration of last long power failure, in any phase.

Figure 67: Example of Power failure event log buffer content

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8.7.2.12. Certification data log Certification data log (1-0:99.99.0*255) is a special log, used to log modifications of critical parameters, which influence measurement values. The basic structure of the data log contains the timestamp and three additional objects:  Last modified secure parameter identifier (0-0:96.128.0*255),  Last modified secure parameter old value (0-0:96.128.1*255), 

Last modified secure parameter new value (0-0:96.128.2*255).

Figure 68: Example of Certification data log buffer content

Last modified secure parameter identifier contains the logical name of the most recently modified critical measurement parameter object. Last modified secure parameter old value and the Last modified secure parameter new value contain the last modified object’s previous and newly set values. The following critical parameters are being monitored:  Active energy, metrological LED (1-0:0.3.0*255)  Reactive energy, metrological LED (1-0:0.3.1*255)     

Apparent energy, metrological LED (1-0:0.3.2*255) Transformer ratio – current (numerator) (1-0:0.4.2*255) Transformer ratio – current (denominator) (1-0:0.4.5*255) Transformer ratio – voltage (numerator) (1-0:0.4.3*255) Transformer ratio – voltage (denominator) (1-0:0.4.6*255)



Measurement period 1, for average value 1 (1-0:0.8.0*255)

  

Active energy, output pulse meter constant [impulses/kWh] (1-0:0.3.3*255) Reactive energy, output pulse meter constant [impulses/kvarh] (1-0:0.3.4*255) Apparent energy, output pulse meter constant [impulses/kVAh] (1-0:0.3.5*255)



Nominal voltage (1-0:0.6.0*255)

The capacity of the Certification data log is set to 100 entries. When the log is full, an event is triggered. Then the critical measurement object can be changed only if first entry in log is 14 months old. If not, then change request is rejected and event is triggered.

V3.00 – English

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550 User manual

1

Power Down

2

Power Up

3

DST enabled or disabled

4

Clock adjusted (old date/time)

5

Clock adjusted (new date/time)

6

Clock invalid

7

Replace Battery

8

Battery voltage low

9

Tariff shift times (TOU) activated

10

Error register cleared

11

Alarm register cleared

V3.00 – English

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+

+

+

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description Indicates a complete power down of the device in any of the phases. Please note that this is related to the device and not necessarily to the network. Indicates that the device is completely powered again (in a case of a three-phase meter; all phases) after a complete power down in any of the phases. This event is not set when new firmware is activated or when meter is reset to factory settings. Indicates the regular change from and to daylight saving time. The time stamp shows the time before the change. This event is not set in case of manual clock changes and in case of power failures. Indicates that the clock has been adjusted. The date/time that is stored in the event log is the old date/time before adjusting the clock. This event is set only when the time is adjusted for more than value set in Clock Time Shift Limit object. Indicates that the clock has been adjusted. The date/time that is stored in the event log is the new date/time after adjusting the clock. This event is set only when the time is adjusted for more than value set in Clock Time Shift Limit object. Indicates that clock may be invalid, i.e. if the power reserve of the clock has exhausted. It is set at power up. Indicates that the battery must be exchanged due to the expected end of life time. Indicates that the current battery voltage is low. Indicates that the passive tariff shift times (TOU) has been activated. Indicates that the error register was cleared. This event is set when Error Register is set or it is cleared internally because error condition has disappeared. Indicates that the alarm register was cleared. This event is set when all bits masked by the alarm filter are cleared.

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

8.7.3. Event Codes

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

12

Program memory error

13

RAM error

14

NV memory error

15

Watchdog error

16

Measurement system error

17

Firmware ready for activation

18

Firmware activated

19

Passive TOU programmed

20 21 22 23 24 25

26

27

28

29

30

31

32

33

External alert detected End of non-periodic billing interval IF_LO_2W enabled IF_LO_2W disabled IF_WAN enabled IF_WAN disabled Communication started on remote interface I3 or I3.1 Communication ended on remote interface I3 or I3.1 Communication started on local interface IE-M Communication ended on local interface IE-M M-Bus ch1 Disconnector activity calendar activated M-Bus ch1 Disconnector passive activity calendar programmed M-Bus ch2 Disconnector activity calendar activated M-Bus ch2 Disconnector pas-

V3.00 – English

Indicates the end of an nonperiodic billing interval 2 way communication on local port enabled 2 way communication on local port disabled

+

+

+

+

+

+

+

+

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description Indicates a physical or a logical error in the program memory. Indicates a physical or a logical error in the RAM Indicates a physical or a logical error in the non-volatile memory Indicates a watch dog reset or a hardware reset of the microcontroller. Indicates a logical or physical error in the measurement system Indicates that the new firmware has been successfully downloaded and verified, i.e. it is ready for activation Indicates that a new firmware has been activated The passive structures of TOU or a new activation date/time were programed Indicates signal detected on the meter's input terminal

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

+

+

+

+

+

+

+ + + + +

WAN port enabled

+

WAN port disabled

+

Indicates that the communication was started on the remote interface I3 or I3.1

+

Indicates that the communication has ended on the remote interface I3 or I3.1

+

Indicates that the communication was started on the locale interface IE-M Indicates that the communication has ended on the local interface IE-M

+

+

Indicates that the passive Disconnector activity calendar has been activated

+

Indicates that the passive Disconnector activity calendar has been programmed

+

Indicates that the passive Disconnector activity calendar has been activated

+

Indicates that the passive Disconnector activity calendar has been programmed

+

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

34

35

36

37

38

39 40 41 42

43 44 45

46

47

48

49

50

+

Indicates that the passive Disconnector activity calendar has been programmed

+

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Indicates that the passive Disconnector activity calendar has been activated

Indicates that the passive Disconnector activity calendar has been activated

+

Indicates that the passive Disconnector activity calendar has been programmed

+

Indicates that on M-Bus channel x the FW has been M-Bus FW ready successfully downloaded and for activation verified; i.e. it is ready for activation. Indicates that on an M-Bus M-Bus FW actichannel x the FW has been vated activated Terminal cover Indicates that the terminal removed cover has been removed Terminal cover Indicates that the terminal closed cover has been closed. Indicates that a strong magStrong DC field netic DC field has been dedetected tected. Indicates that the strong No strong DC magnetic DC field has disapfield anymore peared. Meter cover re- Indicates that the meter moved cover has been removed. Meter cover Indicates that the meter closed cover has been closed. Association Indicates that a user tried to authentication gain LLS access with wrong failure password (intrusion detec(n time failed tion) or HLS access chalauthentication) lenge processing failed ntimes Indicates that configuration has changed after the meter was installed. This event is Configuration set on every set command change except set to Error register, Alarm register, Consumer message text, Clock time or TCP/UDP setup IP reference. Global key(s) One or more global keys changed changed Decryption with currently Decryption or valid key (global or dediauthentication cated) failed to generate a failure (n time valid APDU or authentication failure) tag Receive frame counter value Replay attack less or equal to the last successfully received frame

V3.00 – English

Fraud detection log

Event description

0-0:99.98.0*255

Event name sive activity calendar programmed M-Bus ch3 Disconnector activity calendar activated M-Bus ch3 Disconnector passive activity calendar programmed M-Bus ch4 Disconnector activity calendar activated M-Bus ch4 Disconnector passive activity calendar programmed

Standard event log

IDIS event code

User manual

+

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+

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+

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+

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+

+

+

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+

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

51

FW verification failed

52

Unexpected consumption

53 54 55 56 57 58

LPCAP_M1 enabled LPCAP_M1 disabled LPCAP_M2 enabled LPCAP_M2 disabled LPCAP_M3 enabled LPCAP_M3 disabled

59

Disconnector ready for manual reconnection

60

Manual disconnection

61

Manual connection

62

Remote disconnection

63

Remote connection

64

Local disconnection

65

Limiter threshold exceeded

66

Limiter threshold ok

67

Limiter threshold changed

68

Disconnect/Reconnect failure

69

Local reconnection

70

71

Supervision monitor 1 threshold exceeded Supervision monitor 1 threshold ok

V3.00 – English

+

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description counter in the received APDU Indicates the transferred firmware verification failed i.e. cannot be activated. Indicates consumption is detected at least on one phase when the disconnector has been disconnected Indicates capturing of M-Bus profile 1 is enabled Indicates capturing of M-Bus profile 1 is disabled Indicates capturing of M-Bus profile 2 is enabled Indicates capturing of M-Bus profile 2 is disabled Indicates capturing of M-Bus profile 3 is enabled Indicates capturing of M-Bus profile 3 is disabled Indicates that the disconnector has been set into the Ready_for_reconnection state and can be manually reconnected Indicates that the disconnector has been manually disconnected. Indicates that the disconnector has been manually connected. Indicates that the disconnector has been remotely disconnected. Indicates that the disconnector has been remotely connected. Indicates that the disconnector has been locally disconnected (i.e. via the limiter or current supervision monitors). Indicates that the limiter threshold has been exceeded. Indicates that the monitored value of the limiter dropped below the threshold. Indicates that the limiter threshold has been changed Indicates that the a failure of disconnection or reconnection has happened (control state does not match output state) Indicates that the disconnector has been locally reconnected (i.e. via the limiter or current supervision monitors). Indicates that the supervision monitor threshold has been exceeded. Indicates that the monitored value dropped below the threshold.

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

+

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

72

73

74

75 76

Undervoltage L1

77

Undervoltage L2

78

Undervoltage L3

79

Overvoltage L1

80

Overvoltage L2

81

Overvoltage L3

82

Missing voltage L1

83

Missing voltage L2

84

Missing voltage L3

85

Voltage L1 normal

86

Voltage L2 normal

87

Voltage L3 normal

88

Phase sequence reversal

89

Missing neutral

90

Phase Asymmetry

91

Current Reversal

V3.00 – English

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description Indicates that the supervision monitor threshold has been exceeded. Indicates that the monitored value dropped below the threshold. Indicates that the supervision monitor threshold has been exceeded. Indicates that the monitored value dropped below the threshold. Indicates undervoltage on at least L1 phase was detected. Indicates undervoltage on at least L2 phase was detected. Indicates undervoltage on at least L3 phase was detected. Indicates overvoltage on at least L1 phase was detected. Indicates overvoltage on at least L2 phase was detected. Indicates overvoltage on at least L3 phase was detected. Indicates that the voltage on at least L1 phase has fallen below the Umin threshold for longer than the time delay. Indicates that the voltage on at least L2 phase has fallen below the Umin threshold for longer than the time delay. Indicates that the voltage on at least L3 phase has fallen below the Umin threshold for longer than the time delay. Indicates that the mains voltage is in normal limits again, e.g. after overvoltage. Indicates that the mains voltage is in normal limits again, e.g. after overvoltage. Indicates that the mains voltage is in normal limits again, e.g. after overvoltage. Indicates wrong mains connection. Usually indicates fraud or wrong installation. For three-phase connection only! Indicates that the neutral connection from the supplier to the meter is interrupted (but the neutral connection to the load prevails). The phase voltages measured by the meter may differ from their nominal values Indicates phase asymmetry due to large unbalance of loads connected Indicates unexpected energy export (for devices which are configured for energy import measurement only)

0-0:99.98.0*255

Event name Supervision monitor 2 threshold exceeded Supervision monitor 2 threshold ok Supervision monitor 3 threshold exceeded Supervision monitor 3 threshold ok

Standard event log

IDIS event code

User manual

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+

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

V3.00 – English

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description Indicates that the voltage of L1 does NOT fulfill the following condition: during each period of one week 95 % of the 10 min mean r.m.s, values of the supply voltage are within the range of Un+/- 10 % and Bad Voltage 92 all 10 mín mean r.m.s. values Quality L1 of the supply voltage shall be within the range of Un + 10%/- 15%. (acc. EN50160:2010, section 4.2.2).NB: the r.m.s period of 10 min is fix and cannot be changed Indicates that the voltage of L2 does NOT fulfill the following condition: during each period of one week 95 % of the 10 min mean r.m.s, values of the supply voltage are within the range of Un+/- 10 % and Bad Voltage 93 all 10 mín mean r.m.s. values Quality L2 of the supply voltage shall be within the range of Un + 10%/- 15%. (acc. EN50160:2010, section 4.2.2) NB: the r.m.s period of 10 min is fix and cannot be changed Indicates that the voltage of L3 does NOT fulfill the following condition: during each period of one week 95 % of the 10 min mean r.m.s, values of the supply voltage are within the range of Un+/- 10 % and Bad Voltage 94 all 10 mín mean r.m.s. values Quality L3 of the supply voltage shall be within the range of Un + 10%/- 15%. (acc. EN50160:2010, section 4.2.2) NB: the r.m.s period of 10 min is fix and cannot be changed Disconnector ac- Indicates that the passive 95 tivity calendar Disconnector activity calenactivated dar has been activated Disconnector Indicates that the passive passive activity 96 Disconnector activity calencalendar prodar has been programmed grammed Load Mgmt acIndicates that the passive 97 tivity calendar Load Management activity activated calendar has been activated Load Mgmt pas- Indicates that the passive sive activity cal- Load Management activity 98 endar procalendar has been programmed grammed Indicates that on M-Bus M-Bus FW verifi99 channel x the FW verification cation failed failed Indicates a communication problem when reading the Comm. error M100 meter connected to channel Bus Ch. 1 1 of the M-Bus. This event is set when no valid M-Bus

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

101

Comm. Ok MBus Ch.1

102

Replace Battery M-Bus Ch. 1

103

Fraud attempt M-Bus Ch.1

104

Clock adjusted M-Bus Ch. 1

New M-Bus de105 vice installed Ch. 1

106

Permanent Error M-Bus channel 1

LPCAP_M4 enabled LPCAP_M4 dis108 abled LPCAP_1 ena109 bled 107

Communication 110 Error M-Bus Ch. 2

111

Comm. Ok MBus Ch. 2

V3.00 – English

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description message received in the last 6 hours. Indicates that the communication with the M-Bus meter connected to channel 1 of the M-Bus is ok again. This event is set when a valid M-Bus message has been received after “Communication error M-Bus channel 1” event. Indicates that the battery must be exchanged due to the expected end of life time. This event is set when “Battery low” bit in M-Bus status word change to value 1 is detected. Indicates that a fraud attempt has been registered. This event is set when “Tamper P2” or “Tamper P0” or “Tamper case” or “Tamper magnetic” bit in M-Bus status word change to value 1 is detected. Indicates that the clock has been adjusted. (Only in case of a large time adjustment). This event is set when “Clock sync error“ bit in M-Bus status word change to value 1 is detected. Indicates that a new M-Bus Device has been detected on channel 1 of the M-Bus. This event is set when first message from the M-Bus device is received after binding. Indicates that a Permanent error has been received from the M-Bus device. The Permanent error can be a selfcheck error, or any other fatal device error that requires a service action. This event is set when “SW error“ or “System/HW error” or “CFG Calibration error” or “Temp sensor error” bit in M-Bus status word change to value 1 is detected. Indicates capturing of M-Bus profile 4 is enabled Indicates capturing of M-Bus profile 4 is disabled Indicates capturing of Load Profile 1 is enabled Indicates a communication problem when reading the meter connected to channel 2 of the M-Bus. This event is set when no valid M-Bus message received in the last 6 hours. Indicates that the communication with the M-Bus meter connected to channel 2 of the

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

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+

+

+

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+

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

V3.00 – English

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description M-Bus is ok again. This event is set when a valid M-Bus message has been received after “Communication error M-Bus channel 2” event. Indicates that the battery must be exchanged due to the expected end of life time. Replace Battery 112 This event is set when “BatM-Bus Ch. 2 tery low” bit in M-Bus status word change to value 1 is detected. Indicates that a fraud attempt has been registered. This event is set when “Tamper Fraud attempt P2” or “Tamper P0” or “Tam113 M-Bus Ch. 2 per case” or “Tamper magnetic” bit in M-Bus status word change to value 1 is detected. Indicates that the clock has been adjusted. (Only in case of a large time adjustment). Clock adjusted 114 This event is set when Clock M-Bus Ch. 2 sync error“ bit in M-Bus status word change to value 1 is detected. Indicates that a new M-Bus Device has been detected on New M-Bus dechannel 2 of the M-Bus. This 115 vice installed Ch. event is set when first mes2 sage from the M-Bus device is received after binding. Indicates that a Permanent error has been received from the M-Bus device. The Permanent error can be a selfcheck error, or any other fatal device error that requires a Permanent Error 116 service action. This event is M-Bus Ch. 2 set when “SW error “or “System/HW error” or “CFG Calibration error” or “Temp sensor error” bit in M-Bus status word change to value 1 is detected. LPCAP_1 disa- Indicates capturing of Load 117 bled Profile 1 is disabled LPCAP_2 enaIndicates capturing of Load 118 bled Profile 2 is enabled LPCAP_2 disa- Indicates capturing of Load 119 bled Profile 2 is disabled Indicates a communication problem when reading the meter connected to channel Comm. Error M120 3 of the M-Bus. This event is Bus Ch. 3 set when no valid M-Bus message received in the last 6 hours. Indicates that the communication with the M-Bus meter connected to channel 3 of the Comm. Ok MM-Bus is ok again. This event 121 Bus Ch. 3 is set when a valid M-Bus message has been received after “Communication error M-Bus channel 3” event.

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

122

123

124

125

126

127 128 129

130

131

132

V3.00 – English

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description Indicates that the battery must be exchanged due to the expected end of life time. Replace Battery This event is set when “BatM-Bus Ch. 3 tery low” bit in M-Bus status word change to value 1 is detected. Indicates that a fraud attempt has been registered. This event is set when “Tamper Fraud attempt P2” or “Tamper P0” or “TamM-Bus Ch. 3 per case” or “Tamper magnetic” bit in M-Bus status word change to value 1 is detected. Indicates that the clock has been adjusted. (Only in case of a large time adjustment). Clock adjusted This event is set when “Clock M-Bus Ch. 3 sync error“ bit in M-Bus status word change to value 1 is detected. Indicates that a new M-Bus Device has been detected on New M-Bus dechannel 3 of the M-Bus. This vice installed Ch. event is set when first mes3 sage from the M-Bus device is received after binding. Indicates that a Permanent error has been received from the M-Bus device. The Permanent error can be a selfcheck error, or any other fatal device error that requires a Permanent Error service action. This event is M-Bus Ch. 3 set when “SW error“ or “System/HW error” or “CFG Calibration error” or “Temp sensor error” bit in M-Bus status word change to value 1 is detected. IF_MU enabled Multiutility port enabled IF_MU disabled Multiutility port disabled reserved for future use Indicates a communication problem when reading the meter connected to channel Comm. Error M4 of the M-Bus. This event is Bus Ch. 4 set when no valid M-Bus message received in the last 6 hours. Indicates that the communication with the M-Bus meter connected to channel 4 of the Comm. Ok MM-Bus is ok again. This event Bus Ch. 4 is set when a valid M-Bus message has been received after “Communication error M-Bus channel 4” event. Indicates that the battery must be exchanged due to the expected end of life time. Replace Battery This event is set when “BatM-Bus Ch. 4 tery low” bit in M-Bus status word change to value 1 is detected.

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

+

+

+

+

+

+

+ +

+

+

+

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

133

134

135

136

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description Indicates that a fraud attempt has been registered. This event is set when “Tamper Fraud attempt P2” or “Tamper P0” or “TamM-Bus Ch. 4 per case” or “Tamper magnetic” bit in M-Bus status word change to value 1 is detected. Indicates that the clock has been adjusted. (Only in case of a large time adjustment). Clock adjusted This event is set when “Clock M-Bus Ch. 4 sync error“ bit in M-Bus status word change to value 1 is detected. Indicated the meter (M-Bus New M-Bus de- master) has registered a Mvice installed Ch. Bus device connected to 4 channel 4 with a new serial number Severe error reported by MPermanent Error Bus device (Bit3 in MBUS M-Bus Ch. 4 status EN13757

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

+

+

+

+

+

137 reserved for future use 139 There has been no remote communication on application layer for a predefined period of time; i.e. meter could not be reached remotely. Modem's response to initialiModem Initializa- zation AT command(s) is in141 tion failure valid or ERROR or no response received SIM card is not inserted or is 142 SIM Card failure not recognized SIM card has been correctly 143 SIM Card ok detected Modem's registration on GSM registration 144 GSM network was not sucfailure cessful Modem's registration on GPRS registra145 GPRS network was not suction failure cessful PDP context es146 PDP context is established tablished PDP context de147 PDP context is destroyed stroyed PDP context fail- No Valid PDP context(s) 148 ure retrieved Modem SW re- Modem restarted by SW re149 set set Modem restarted by HW reModem HW re- set (this event is not issued 150 set after a general power resume) Modem is successfully conGSM outgoing 151 nected, initiated by an outconnection going call. Modem is successfully conGSM incoming 152 nected, initiated by an incomconnection ing call 153 GSM hang-up Modem is disconnected Modem's response to diagDiagnostic fail154 nostic AT command(s) ure ("+CPIN?", "+CSQ", No connection 140 timeout

V3.00 – English

+

+

+ + +

+ + + + +

+

+

+ + +

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

V3.00 – English

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description "+CREG?", "+CGREG?", "+COPS?", "+CGACT?", "+CPMS?") is invalid or ERROR or no response received. Modem's initialization AT command(s) – specified in atUser initialization tribute 3 of the modem con155 failure figuration object - is invalid. Error message or no response from the modem. Signal quality Signal strength too low, not 156 low known, or not detectable Number of calls has exAuto Answer ceeded (in mode (1) or mode 157 Number of calls (2) ) the values given in the exceeded attribute number_of_calls. Indicates a successful comLocal communi158 munication on any local port cation attempt has been initiated. reserved for fu159 ture use Manual discon- Indicates that the discon160 nection M-Bus nector has been manually channel 1 disconnected. Manual connec- Indicates that the discon161 tion M-Bus chan- nector has been manually nel 1 connected. Remote discon- Indicates that the discon162 nection M-Bus nector has been remotely channel 1 disconnected. Remote connec- Indicates that the discon163 tion M-Bus chan- nector has been remotely nel 1 connected. Valve alarm M- Indicates that a valve alarm 164 Bus channel 1 has been registered. Local disconnec- Indicates that the discon165 tion M-Bus chan- nector has been locally disnel 1 connected. Indicates that the disconLocal connection 166 nector has been locally conM-Bus channel 1 nected. 167 reserved for future use 169 Manual discon- Indicates that the discon170 nection M-Bus nector has been manually channel 2 disconnected. Manual connec- Indicates that the discon171 tion M-Bus chan- nector has been manually nel 2 connected. Remote discon- Indicates that the discon172 nection M-Bus nector has been remotely channel 2 disconnected. Remote connec- Indicates that the discon173 tion M-Bus chan- nector has been remotely nel 2 connected. Valve alarm M- Indicates that a valve alarm 174 Bus channel 2 has been registered. Local disconnec- Indicates that the discon175 tion M-Bus chan- nector has been locally disnel 2 connected. Indicates that the disconLocal connection 176 nector has been locally conM-Bus channel 2 nected.

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

+

+

+

+

+

+

+

+ + +

+

+

+

+

+ + +

+

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AM550

Indicates that the disconnector has been manually disconnected. Indicates that the disconnector has been manually connected. Indicates that the disconnector has been remotely disconnected. Indicates that the disconnector has been remotely connected. Indicates that a valve alarm has been registered. Indicates that the disconLocal disconnecnector has been locally dis185 tion M-Bus chanconnected. nel 3 186

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

+

+

+ +

+

+

187 reserved for future use 189 Manual discon190 nection M-Bus channel 4 Manual connec191 tion M-Bus channel 4 Remote discon192 nection M-Bus channel 4 Remote connec193 tion M-Bus channel 4 Valve alarm M194 Bus channel 4 Local disconnec195 tion M-Bus channel 4

V3.00 – English

0-0:99.98.8*255

+

Indicates that the disconLocal connection nector has been locally conM-Bus channel 3 nected.

Indicates that the disconnector has been manually disconnected. Indicates that the disconnector has been manually connected. Indicates that the disconnector has been remotely disconnected. Indicates that the disconnector has been remotely connected. Indicates that a valve alarm has been registered. Indicates that the disconnector has been locally disconnected. Indicates that the disconLocal connection 196 nector has been locally conM-Bus channel 4 nected. 197 reserved for future use 199 Indicate that G3-PLC device 200 G3-PLC joined joined network Indicate that G3-PLC device 201 G3-PLC kicked was kicked from or left the network G3-PLC disIndicate that G3-PLC device 202 cover requested PAN discover Image activation Indicate that the Image acti203 log is full vation log is full Firmware golden Indicate that the firmware 204 copy activated golden copy is activated Limiter 1 actiIndicate that the limiter 1 limi205 vated tation is activated. Limiter 1 deacIndicate that the limiter 1 limi206 tivated tation is deactivated.

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description

0-0:99.98.0*255

Event name 177 reserved for future use 179 Manual discon180 nection M-Bus channel 3 Manual connec181 tion M-Bus channel 3 Remote discon182 nection M-Bus channel 3 Remote connec183 tion M-Bus channel 3 Valve alarm M184 Bus channel 3

Standard event log

IDIS event code

User manual

+

+

+

+ + +

+

+ + + + +

+ + +

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

209

Opt out Deactivated (Opt IN)

Indicates that E-meter is opt IN

210

Opt out Activated

211

Limiter 2 threshold exceeded

212

Limiter 2 threshold ok

213

Limiter 2 threshold changed

214

IF_DISP_TYP_N ORM_enabled

215

IF_DISP_TYP_N ORM_disabled

Indicates that E-meter is Opt OUT Indicates that the limiter 2 threshold has been exceeded. Indicates that the monitored value of the limiter 2 dropped below the threshold. Indicates that the limiter 2 threshold has been changed Indicates that display shows LPs and Certification Logbook (Console Normal mode) Indicates that display does not show LPs and Certification Logbook (Console Reduced mode) Indicates that display is turned on Indicates that display is turned off Indicates that switching device functionality is enabled Indicates that switching device functionality is disabled (switching device is always connected) Indicates that the HAN is enabled Indicates that the HAN is disabled

IF_DISPLAY_enabled IF_DIS217 PLAY_disabled SWITCH_DEV_ 218 enabled 216

219

220 221 222 223 224 225 226

227 228 229

230

231 232

SWITCH_DEV_ disabled IF_HAN_enabled IF_HAN_disabled LPCAP3_enabled LPCAP3_disabled LPCAP4_enabled LPCAP4_disabled

Indicates capturing of Load Profile 3 is enabled Indicates capturing of Load Profile 3 is disabled Indicates capturing of Load Profile 4 is enabled Indicates capturing of Load Profile 4 is disabled Indicates that the transferred LR firmware verLR firmware verification failed ification failed i.e. cannot be activated) LR firmware Indicates that the LR firmready for activaware is ready for activation tion LR firmware acti- Indicates that the LR firmvated ware is activated Certification log Indicate that the certification book is full log book is full Indicates any of errors have been set:  Program memory error Fatal error  RAM error  NV memory error  Measurement system error Billing reset Indicates billing reset Indicates power loss / power Power failure L1 disconnected on phase L1

V3.00 – English

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description Indicate that the limiter 2 limitation is activated. Indicate that the limiter 2 limitation is deactivated.

0-0:99.98.0*255

Event name Limiter 2 acti207 vated Limiter2 deac208 tivated

Standard event log

IDIS event code

User manual

+ + + + +

+ + +

+

+ + +

+

+ + + + + + +

+

+

+

+

+

+

+

+

+ +

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550

233 Power failure L2 234 Power failure L3 235 Power returned L1 236 Power returned L2 237 Power returned L3 Disconnector 238 physical connect 239 Manufacturer specific 243 Module cover 244 opened Module cover 245 closed M-Bus Channel 246 1 key change 247

M-Bus Channel 2 key change

M-Bus Channel 3 key change M-Bus Channel 249 4 key change Decryption or 250 authentication successful 248

251

LP restriction date set

252

Display settings change

Reverse phase neutral Load profile 254 cleared 253

255

Event log cleared

0-4:24.5.0*255

M-Bus control log 4

0-3:24.5.0*255

M-Bus control log 3

0-2:24.5.0*255

M-Bus control log 2

0-1:24.5.0*255

M-Bus control log 1

0-0:99.98.8*255

Image activation log

0-0:99.98.7*255

Security event log

0-0:99.98.6*255

+ + + + + +

Indicate that the module cover has been opened Indicates that that the module cover has been closed Indicates change of the key on the M-Bus Channel 1 Indicates change of the key on the M-Bus Channel 2 key change Indicates change of the key on the M-Bus Channel 3 Indicates change of the key on the M-Bus Channel 4

+

+

+

+

+ + + + +

Logging of a successful user authentication. LPs on display show only records after restriction date (Date_DS) Indicates that the display configuration object's settings are changed

Communication details log

0-0:99.98.5*255

Communication event log

0-0:99.98.4*255

Power quality event log

0-0:99.98.3*255

M-Bus event log

0-0:99.98.2*255

Disconnector control log

0-0:99.98.1*255

Fraud detection log

Event description Indicates power loss / power disconnected on phase L2 Indicates power loss / power disconnected on phase 3 Indicates power restored / power connected on phase L1 Indicates power restored / power connected on phase L2 Indicates power restored / power connected on phase L3 Indicates that Switching device is physically connected

0-0:99.98.0*255

Event name

Standard event log

IDIS event code

User manual

+

+

+

Indicate reverse phase neutral

+

Any of the profiles cleared.

+

Indicates that the event log was cleared. This is always the first entry in an event log. It is only stored in the affected event log.

+

+

+

+

+

+

+

+

+

+

+

+

Table 44: List of events

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550 User manual

8.8. Errors The meter uses its automatic supervision mechanism to detect and log different types of events related to meter operation. These events can be a part of meter's internal functionality or can occur due to changes in the meter's environment. When an event, which indicates a malfunction in meter operation, is triggered, the appropriate flag in the error register is set (see Table 46). Depending on the type of error, some errors clear themselves if the reason for the error has disappeared. Others must be cleared via the management client (object 0-0:97.97.0*255) Once a flag in the Error register object is set, it remains active even after the corresponding error condition has disappeared. The Error register (0-0:97.97.0*255) object has to be cleared manually (using supported communication interfaces). NOTE Exception: FF errors (B8–B11 in Table 46) cannot be cleared in any case.

If, after the flag in the error register has been cleared, the corresponding error-condition still remains, the flag in the error register is re-set by the meter. During operation, the meter performs tests of individual functions. In a case of an error, it is represented with corresponding error bit in the Error Object register. Depending on the capabilities of the system and the policy of the utility errors can be filtered. The Error Object value register is 32 bits long and is organized in three groups of errors (see Table 46).

8.8.1. Other errors Clock invalid The current time is compared with internal time and if there is any deviation, error “Clock invalid” will be set. When the meter time is set, the meter will reset the invalid time bit in error register. The energy registers are not affected by the “Clock invalid” error.

8.8.2. Critical errors Program memory error Program memory is checked by verifying the integrity of stored program code. The program code is signed by the ECDSA algorithm during build time. The signature is stored together with program code in program memory. In run time, the meter calculates the signature over program code and compares it with the previously stored one. If differ, the “Program memory error” flag is set. RAM error The entire data memory (RAM) is checked during the initialization process of the meter, which is started after power-up or firmware upgrade. During the initialization procedure, the meter performs a test of the RAM through the whole address range. The test is executed for every memory location and it is non-destructive. The original content of the memory location under test is loaded to the CPU register, then, the inverted content is stored to the same memory location and compared with the inverted content stored in the CPU register. Upon successful comparison of the inverted content, the original content of the memory location is restored and compared with its copy sorted in CPU register at the beginning of the test. If the test fails, the meter sets the “RAM error” flag. Otherwise, during the normal operation, the meter checks the integrity of data structures where critical data is stored. Each time when such a data structure is intentionally changed, a new signature is calculated and

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550 User manual

stored. Later on, when the data is accessed again by the program, the integrity can be checked by comparing the newly calculated signature with the one calculated during last intentionally change. If signatures do not match, the meter sets the “RAM error” flag. That way, continuous monitoring of RAM is achieved. NV memory error The non-volatile memory is used to retain the stored information, even when the meter is not powered. It is used as a long-term persistent storage for periodical historical data, billing data, event logs, register back-up copies, parameters, and any other data that the meter needs for a normal start. Data-integrity checking is performed periodically or randomly, during data access. Checking of data, which is the result of meter processes and changes more often, is done during data access. The meter-configuration parameters are checked periodically with a period of one hour. If any of the checks fail, the “NV memory error” is set in the error register. Measurement system error Checking of undisturbed operation and accuracy of the meter is, to a certain extent, performed by the meter by itself. If any error is detected, the meter reports it by setting the “Measurement system error” flag. Fraud attempt Events that trigger the “Fraud attempt” flag: meter cover open, terminal cover open, communication module cover open, magnetic field detect, replay attack, decryption or authentication failure. The following critical errors remain permanent on the meter and cannot be cleared (bit positions in Table 46):  

B8 Program memory error B9 RAM error

 

B10 NV memory error B11 Measurement system error

If one of the above listed errors appears, also FF (Fatal Fault) error is raised on the meter.

8.8.3. M-Bus errors M-Bus-related fraud attempt and communication errors.

8.8.4. Error Register AM550 meters contain sets of error register. Attributes 1. Logical name 2. Value

Data type Octet-string Unsigned32

Class ID 1

Code 0-0:97.97.0*255

Access R R/W

Min.

Max.

Default

0

4294967295

0

Table 45: Error IDIS Register COSEM Object

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550 User manual

Table 46 gives an overview of all errors IDIS and their assignments.

Critical Errors

Other Errors

Group

Byte

1 (LSB)

2

M-Bus Errors

3

4 (MSB)

Bit

Meaning

Events

0

Clock invalid

6

1

Replace battery

7

2

Not used

3

Not used

4

Not used

5

Not used

6

Not used

7

Not used

8

Program memory error

12

9

RAM error

13

10

NV memory error

14

11

Measurement system error

16

12

Watchdog error

15

13

Fraud attempt

40, 42, 44, 46, 49, 50, 244

14

Not used

15

Not used

16

Communication error M-Bus Ch1

100

17

Communication error M-Bus Ch2

110

18

Communication error M-Bus Ch3

120

19

Communication error M-Bus Ch4

130

20

Fraud attempt M-Bus Ch1

103

21

Fraud attempt M-Bus Ch2

113

22

Fraud attempt M-Bus Ch3

123

23

Fraud attempt M-Bus Ch4

133

24

Permanent error M-Bus Ch1

106

25

Permanent error M-Bus Ch2

116

26

Permanent error M-Bus Ch3

126

27

Permanent error M-Bus Ch4

136

28

Battery low M-Bus Ch1

102

29

Battery low M-Bus Ch2

112

30

Battery low M-Bus Ch2

122

31

Battery low M-Bus Ch3

132

Table 46: IDIS Error Codes

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550 User manual

8.8.5. Error codes interpretation Example: The register or meter’s LCD displays the code 97.97.0, which represents the Error register object. To determine the error: 1. Read its value (a decimal number) from the LCD (or register). Example: 00002801 2. Convert the decimal number into a binary one 00002801dec = 10 1000 0000 0001bin 3. Write out the positions of digit 1 (bits). In Table 47, we can see the positions of digit 1. It stands on B0, B11, and B13.

NOTE Positons in binary numbers are always counted from right to left, starting with 0. The error code in binary format has 32 digits. Normally, the calculator does not display leading zeroes, so we need to add them in order to get the 32-digits number. See Table 47.

Table 47: Error code interpretation

4. Use the error codes table (see Table 47) to interpret what the bits represent: B0 – Clock invalid B11 – Measurement system error (FF) B13 – Fraud attempt (FF)

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550 User manual

8.9. Alarms When some special events occur in meter, internal alarm is generated in meter, which can be sent to the central system. The alarm parameters are predefined. The priority levels of alarms are adjustable. Alarms are then registered and handled by the utility HES.

Figure 69: Alarm reporting process

Each bit in the alarm register represents a different alarm. If any bit is set, corresponding alarm was recorded. Value of the alarm register is a 32-bit value of all active and inactive alarms. Depending on the capabilities of the HES and the utility policy, it is possible to mask unwanted alarms through the alarm filter. Alarm monitoring is also supported. Alarm monitor is a special implementation of the Register monitor functionality, which is used to trigger action up, when any new alarm occurs in the meter.

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550 User manual

In following tables, two sets of alarm codes are represented; Alarm Register 1 bits in Table 48 and Alarm Register 2 bits in Table 49

Critical Alarms

Other Alarms

Group

Byte

1 (LSB)

2

M-Bus Alarms

3

4 (MSB)

Bit

Meaning

Events

0

Clock invalid

6

1

Replace battery

7

2

Not used

3

Not used

4

Not used

5

Not used

6

Not used

7

Not used

8

Program memory error

12

9

RAM error

13

10

NV memory error

14

11

Measurement system error

16

12

Watchdog error

15

13

Fraud attempt

40, 42, 44, 46, 49, 50, 244

14

Not used

15

Not used

16

Comm. error M-Bus Ch1

100

17

Comm. error M-Bus Ch2

110

18

Comm. error M-Bus Ch3

120

19

Comm. error M-Bus Ch4

130

20

Fraud attempt M-Bus Ch1

103

21

Fraud attempt M-Bus Ch2

113

22

Fraud attempt M-Bus Ch3

123

23

Fraud attempt M-Bus Ch4

133

24

Permanent error M-Bus Ch1

106

25

Permanent error M-Bus Ch2

116

26

Permanent error M-Bus Ch3

126

27

Permanent error M-Bus Ch4

136

28

Battery low on M-Bus Ch1

102

29

Battery low on M-Bus Ch2

112

30

Battery low on M-Bus Ch3

122

31

Battery low on M-Bus Ch4

132

Table 48: Bits of Alarm Register 1

A Fraud attempt alarm is generated in the following cases:  

Meter cover is removed, Terminal cover is removed,

 

Strong DC field is detected, Authentication on communication fails more than N times (N is set in 0-0:196.98.2*255),

  

Decryption on communication fails more than N times (N is set in 0-0:196.98.2*255), Replay attack on communication is detected, Communication module cover removed.

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8. DESCRIPTIONS OF MAIN METER FUNCTIONALITIES AND FEATURES

AM550 User manual Bit

Alarm

Description

Events

0

Total Power Failure

Set when power-down on meter occurs.

01

1

Power Resume

Set when meter power returns.

02

Set when voltage on at least L1 phase has fallen below the Umin threshold for longer than time delay. Set when voltage on at least L2 phase has fallen below the Umin threshold for longer than time delay. Set when voltage on at least L3 phase has fallen below the Umin threshold for longer than time delay.

2

Voltage Missing Phase L1

3

Voltage Missing Phase L2

4

Voltage Missing Phase L3

5

Voltage Normal Phase L1

Set when the mains voltage on L1 is in normal limits again.

85

6

Voltage Normal Phase L2

Set when the mains voltage on L2 is in normal limits again.

86

7

Voltage Normal Phase L3

Set when the mains voltage on L3 is in normal limits again.

87

8

Missing Neutral

Set when the neutral connection from the supplier to the meter is interrupted.

89

9

Phase Asymmetry

Set when large unbalance loads is present

90

10

Current Reversal

Set when unexpected energy export is present (for energy import configured devices only).

91

11

Wrong Phase Sequence

Set when wrong mains connection or fraud (three-phase meters only).

88

12

Unexpected Consumption

Set when consumption is detected on at least one phase when disconnector has been disconnected.

52

13

Key Exchanged

Set when one or more global keys changed.

48

14

Bad Voltage Quality L1

15

Bad Voltage Quality L2

16

Bad Voltage Quality L3

17

External Alert

Set when L1 voltage is not within ranges for defined period of time (see EN50160:2010). Set when L2 voltage is not within ranges for defined period of time (see EN50160:2010). Set when L3 voltage is not within ranges for defined period of time (see EN50160:2010). Set when signal is detected on meter’s INPUT terminal. Set when communication on any local port is detected (i.e. unauthorized access) Set when new M-Bus device is registered on the Ch1 with new serial number. Set when new M-Bus device is registered on the Ch2 with new serial number. Set when new M-Bus device is registered on the Ch3 with new serial number. Set when new M-Bus device is registered on the Ch4 with new serial number.

82 83 84

92 93 94 20

18

Local Communication Attempt

158

19

New M-Bus Device Installed Ch1

20

New M-Bus Device Installed Ch2

21

New M-Bus Device Installed Ch3

22

New M-Bus Device Installed Ch4

23

Reserved for future use

24

Reserved for future use

25

Reserved for future use

26

Reserved for future use

27

M-Bus Valve Alarm Ch1

Set when ALARM STATUS bit is received from device on Ch1.

164

28

M-Bus Valve Alarm Ch2

Set when ALARM STATUS bit is received from device on Ch2.

174

29

M-Bus Valve Alarm Ch3

Set when ALARM STATUS bit is received from device on Ch3.

184

30

M-Bus Valve Alarm Ch4

Set when ALARM STATUS bit is received from device on Ch4.

194

31

Disconnect/Reconnect Failure

Set when disconnector failed to connect/disconnect.

68

105 115 125 135

Table 49: Bits of Alarm Register 2

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8.9.1. Alarm Filter Alarms can be masked through the Alarm Filter object. To mask out an unwanted alarm, the corresponding bit in the alarm filter register must be cleared (unchecked - value set to logical 0). By default, no alarm is enabled (all bits are set to 0). The structure of the Alarm filter is the same as for the Alarm register. Attributes

Data type

Class ID

Code

Access

Min.

Max.

Default

1. Logical name 2. Value

Octet-string Unsigned32

1

0-0:97.98.10

R R/W

0

4294967295

0

Table 50: Alarm Filter 1 COSEM Object

Attributes

Data type

Class ID

Code

Access

Min.

Max.

Default

1. Logical name 2. Value

Octet-string Unsigned32

1

0-0:97.98.11

R R/W

0

4294967295

0

Table 51: Alarm Filter 2 COSEM Object

8.9.2. Alarm Register A selection of events that are to be treated as alarms can be made (alarm filter). If one of these selected events occurs, the corresponding flag in the alarm register is set and an alarm is then raised via the P3 port. Typically, critical errors are selected as alarm triggers. Normally, power outages cannot be selected since the communication network is also down in case of a power outage. All fraud attempts are grouped, therefore, for alarming, it is not necessary to see the exact type of fraud, which caused the alarm. This can be found out by checking the error register or the appropriate event log. Attributes Data type Class ID 1. Logical name Octet-string 1 2. Value Unsigned32 Table 52: Alarm Register 1 COSEM Object

Attributes 1. Logical name 2. Value

Data type Octet-string Unsigned32

Class ID 1

Code 0-0:97.98.0

Code 0-0:97.98.1

Access R RW

Min.

Max.

Default

0

4294967295

0

Access R RW

Min.

Max.

Default

0

4294967295

0

Table 53: Alarm Register 2 COSEM Object

NOTE Specific bits of alarm registers may be automatically cleared – reset by the meter internally, if the “condition for alarm” has disappeared. Alternatively, all bits i.e. all alarms may be externally reset via communication, by executing a SET service to the attribute value of the alarm register object. In the latter case, those bits, for which the “condition for alarm” still exists, will immediately be set to 1 again and an alarm will be issued. Clearing of critical alarms (bit 8 to 15 of Alarm Register 1 – see Table 49) is only possible from the HES, by invoking SET with all bits to 0 in the alarm register object. Otherwise, the command will be rejected and an error will be returned.

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8.9.3. Alarm Status The Alarm status register shows, which alarm has been triggered. There is a separate register for the ON and OFF statuses:  Alarm on status 1, 1-0:96.242.0*255  

Alarm off status 1, 1-0:96.243.0*255 Alarm on status 2, 1-0:96.242.10*255



Alarm off status 2, 1-0:96.243.10*255

Each bit represents the corresponding alarm. Recorded bit remains active until it is cleared by the client. These registers cannot be cleared by the device. Structure of the Alarm status is the same as for the Alarm register.

8.9.4. Alarm Descriptor Whenever a bit in the Alarm Registers changes from 0 to 1, the corresponding bit of the Alarm Descriptors is set to 1. The structure of the Alarm Descriptor is the same as for the Alarm Register. There are two Alarm Descriptor objects:  Alarm descriptor 1, 0-0:97.98.20*255; 

Alarm descriptor 2, 0-0:97.98.21*255.

Resetting the Alarm Registers does not affect the Alarm Descriptors; their bits are not reset. The set bits of the Alarm Descriptors can only be reset explicitly, by the client (HES). The Alarm Descriptors are used by client (HES) to identify those past alarms that have already been cleared from the Alarm registers.

8.9.5. Alarm Register Monitor Using the Alarm Register Monitor, the meter can be triggered by an alarm, for example, to setup a WAN connection. If an alarm (monitored value) is raised, the associated script is executed and the Push Setup object will trigger the connection management. There are two Alarm Register Monitor objects:  Alarm monitor 1, 0-0:16.1.0*255; 

Alarm monitor 2, 0-0:16.1.1*255.

The Register Monitor attribute “Actions” defines the action when the content of “Monitored value” crosses the “Thresholds” in the upwards or/and downwards direction. If the Register Monitor functionality is not used, the “Actions” array will be empty. In order to prevent that execution of the script is aborted because of a power-down, comparison of the monitored value is done every time the meter is powered up. This will result in the triggering of the “Actions” again when one or more alarms in the alarm register are still active after a power down.

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8.10. Activity calendar and TOU registration Activity calendar is time of use (TOU) object for tariff control. It allows modelling and handling of various tariff structures in the meter. A Tariff program is implemented with set of objects that are used to configure different seasons or weekly and daily programs, to define which tariff should be active. Different actions can be performed with tariff switching, like registering energy values in different tariffs. The Tariff-program-illustration concept can be seen in Figure 70.

Figure 70: Graphical tariff program

TOU capabilities (object 0-0:13.0.0*255) are the following:       

up to 8 tariffs, up to 8 masks for configuring different combinations of tariff registers, up to 12 seasons tariff programs, up to 12 week tariff programs, up to 12 day tariff programs, up to 16 actions per day tariff program, up to 105 special day date definitions.

Tariff program configures different seasons or weekly and daily programs to define when a certain tariff should be active. Different actions can be performed with tariff switching like registering energy values in different tariffs. Activity calendar is time of use (TOU) object for tariff control. It allows modelling and handling of various tariff structures in the meter. It is used to store energy and demand according to tariff rate schedule. Scheduled actions are defined inside the meter. They follow the classical way of calendar-based schedules by defining seasons, weeks, and days. After a power failure, only the last action missed from Activity calendar is executed (delayed). This is to ensure proper tariff after power up. In the Activity Calendar (0-0:13.0.0*255), Active and Passive tariff programs are set. The meter uses the tariffication schema, which is set with the Active tariff program. The Passive tariff program is activated by overwriting the Active tariff program. This can be done with method Activate passive calendar using time schedule. Activation of Passive schema is recorded in the Standard Event log (event 9-TOU activated).

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NOTE First action start time in a day must be set to 0:00:00. NOTE When multiple actions exist for the same time, only first action is executed.

8.10.1.External tariff inputs Tariff switching can be controlled by one of the next tariff switch sources (Tariff switch source – 0-0:128.10.0*255):  Tariff input (default)  

Internal tariff program Internal tariff program and manual request

If the meter is equipped with energy tariff input terminals (terminals 13, 15, 33; see chapter 4.2.2.2. Terminal block – I/O area) and parameter Tariff switch source is set to Tariff input, up to four energy tariffs can be driven with energy tariff inputs. External tariff inputs for energy tariffication are configurable (Figure 71). To each pair of tariff inputs belongs a coding table. A coding table defines specific script from tariffication script table through which a required mask in register activation becomes active at specific combination of two inputs. Therefore, Tariff external inputs connection object (0-0:128.10.2*255) is implemented to correctly switch tariffs with inputs.

Figure 71: Tariff external input connections

Physical external tariff inputs (terminals 13 and 33; see Table 12) are marked as TE1/2 and TE3/4 (depends on configuration in objects Configurable IO 8 (0-0:196.3.8*255) and Configurable IO 9 (0-0:196.3.9*255), where terminals 13 and 33 can be configured as Tariff input 1/2 and Tariff input 3/4). As presented in Figure 71, four combinations of active/passive TE1 and TE2 are available (if check box is checked, TEn (n = 1/2 or 3/4) is active). To each of the four combination, any of available script can be selected (actions of the scripts are defined in object Tariffication script table – 0-0:10.0.100*255). Maximum four tariffs can be driven through external inputs.

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8.10.2.Activity calendar Disconnector Activity calendar – Disconnector is time of use used to drive disconnector. This meter function is used when integrated meter switching device (SD) is used for the specific switching actions. There is supported configuration of switching table with set of objects that are used to configure different seasons, or weekly and daily programs, to define when SD should be activated. TOU capabilities (object 0-0:13.0.1*255) of this specific activity calendar is the following:  up to 4 seasons tariff programs,  up to 4 week tariff programs,  up to 4 day tariff programs, 

up to 8 actions per day tariff program,



up to 48 special day date definitions.

8.11. Power quality AM550 meter provides the following set of functions to monitor the power quality for single- and three-phase meters. For single phase, only L1 events are recorded.

8.11.1.Voltage sag A Voltage sag is a phase voltage drop in the interval between the Threshold for voltage sag and the Threshold for voltage cut, for a period shorter than the Time threshold for voltage sag. The objects related to voltage sags are described in the following subsections. Voltage sag events are counted per-phase and for any phase. 8.11.1.1. Threshold for voltage sag The value set in object Threshold for voltage sag (1-0:12.31.0*255) is the upper voltage limit of the interval for the voltage sag. 8.11.1.2. Time threshold for voltage sag If the duration (in seconds) of the voltage sag is shorter than the value defined in object Threshold for voltage sag (1-0:12.31.0*255), than voltage sag is counted, if longer, under-voltage is logged. 8.11.1.3. Counter for voltage sag As soon as voltage drops below the Time threshold for voltage sag for a period longer than 100 ms and shorter than the Time threshold for voltage sag, the value in Counter for voltage sag (1-0:12.32.0*255) will be incremented. 8.11.1.4. Number of voltage sags (per phase) The number of voltage sags in phases L1, L2 and L3 is counted; each has its own counter:  Number of voltage sags in phase L1, 1-0:32.32.0*255;  Number of voltage sags in phase L2, 1-0:52.32.0*255;  Number of voltage sags in phase L3, 1-0:72.32.0*255.

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8.11.2.Voltage swell A Voltage swell is a phase voltage increase above the Threshold for voltage swell, for a period shorter than the Time threshold for voltage swell. The objects related to the voltage swells are described in the following subsections. Voltage swell events are counted per-phase and for any phase. 8.11.2.1. Threshold for voltage swell The value set in object Threshold for voltage swell (1-0:12.35.0*255) is the lower voltage limit for the voltage swell. 8.11.2.2. Time threshold for voltage swell The value set in object Time threshold for voltage swell (1-0:12.44.0*255) is the duration (in seconds) of the voltage swell until it is detected. 8.11.2.3. Counter for voltage swell As soon as voltage rises above the Threshold for voltage swell for a period longer than 100 ms and shorter than the Time threshold for voltage swell, the value in Counter for voltage swell (1-0:12.36.0*255) will be incremented. 8.11.2.4. Number of voltage swells (per phase) The number of voltage swells in phases L1, L2, and L3 is counted; each has its own counter:  Number of voltage swells in phase L1, 1-0:32.36.0*255;  Number of voltage swells in phase L2, 1-0:52.36.0*255;  Number of voltage swells in phase L3, 1-0:72.36.0*255.

8.11.3.Voltage cut A Voltage cut is a phase voltage drop below the value defined in object Threshold for missing voltage (voltage cut) (1-0:12.39.0*255) for a period longer than the Time threshold voltage cut (1-0:12.45.0*255). The voltage cut is recorded as the per-phase missing voltage event.

8.11.4.Under-voltage An Under-voltage is a phase voltage drop in the interval between the Threshold for voltage sag and the Threshold for voltage cut, for a period longer than the Time threshold for voltage sag. Every under-voltage is recorded in the Power quality log as an undervoltage event and for the last undervoltage, its magnitude and duration is recorded. In addition, long-lasting under-voltage conditions are counted per-phase and for any phase, separately for every voltage drop interval (for counters see Table 54). NOTE Register values are updated when the voltage goes back to its normal value.

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8.11.5.Over-voltage An Over-voltage is a phase voltage increase above the Threshold for voltage swell, for a period longer than the Time threshold for voltage swell. Every over-voltage is recorded in the Power quality log as an overvoltage event and for the last over-voltage, its magnitude and duration is recorded. In addition, long-lasting over-voltage conditions are counted perphase and for any phase, separately for several voltage drop intervals (for counters see Table 54). NOTE Register values are updated when the voltage goes back to its normal value.

8.11.5.1. Actual voltage values The following voltage measurements are supported (x = 1, 2, 3):        

Daily peak voltage – current Lx, 0-0:128.8.x0*255 Daily peak voltage – previous Lx, 0-0:128.8.x1*255 Daily minimum voltage – current Lx, 0-0:128.8.x2*255 Daily minimum voltage – previous Lx, 0-0:128.8.x3*255 ALL phases average voltage daily peak – current, 0-0:128.8.0*255 ALL phases average voltage daily peak – previous, 0-0:128.8.1*255 ALL phases average voltage daily minimum – current, 0-0:128.8.2*255 ALL phases average voltage daily minimum – previous, 0-0:128.8.3*255

8.11.6.Voltage level At the start of aggregation, the interval meter starts to sample phase Urms voltages with a basic time interval and averages them. At the end of the aggregation period, calculated average phase voltage is compared to defined thresholds. If the voltage depth value obtained at the end of aggregation time interval falls below the one of threshold voltages presented in Table 54, the corresponding counter is incremented. The depth is the difference between the reference voltage (nominal phase voltage) and the average Urms value measured on particular phase during the aggregation interval. Threshold levels Level 1 Level 2 Level 3 Level 4 Level 5 Level 6 Level 7

Threshold voltage depths U > +10% +5% < U < +10% 0% < U < +5% -5% < U < 0% -10% < U < -5% -15% < U > -10% U < -15%

Threshold level counters

Corresponding objects (x = 1,2,3)

Counter 1 over voltage Counter 2 over voltage Counter 3 over voltage Counter 4 under voltage Counter 5 under voltage Counter 6 under voltage Counter 7 under voltage

Level 1 U > +10% Lx Level 2 +5% < U < +10% Lx Level 3 0% < U < +5% Lx Level 4 -5% < U < 0% Lx Level 5 -10% < U < -5% Lx Level 6 -15% < U > -10% Lx Level 7 U < -15% Lx

0-0:128.7.x1*255 0-0:128.7.x2*255 0-0:128.7.x3*255 0-0:128.7.x4*255 0-0:128.7.x5*255 0-0:128.7.x6*255 0-0:128.7.x7*255

Table 54: Under and Over Voltage Detection Model

8.11.7.Daily peak and minimum Meters measure and records daily peaks and minimums of the phase voltages and the peak and minimum of the average voltage of all three phases. Measured voltage values are aggregated and averaged during a settable aggregation period Voltage peak and minimum aggregation period [s] (0-0:128.8.50*255). The default setting is 600 s. At the end of the aggregation period, the measured value is compared with the value stored in the current register. If it is greater or lower than existing, the old value in the appropriate register is overwritten with respect to it being a peak or minimum. At the end of the day, values are copied from the current registers (set of voltage daily peak and minimum current registers) to the previous registers (set of voltage daily peak and minimum previous) and the current registers are reset.

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8.11.8.Voltage asymmetry The meter measures voltages and compares them with the average voltage of all three phases. If the difference is greater than the predefined threshold, then alarm bit in ALARM ON register is set. When a symmetry is re-established, the alarm bit in the ALARM OFF register is set. Two thresholds, upper and lower threshold, can define the level of asymmetry, which triggers the alarm. NOTE Voltage asymmetry is valid only for three phase meters.

8.11.9.Power failure The AM550 meter registers the following aspects of power failure events:  Power failures are counted in (x = 1,2,3): - Number of power failures, in all three phases, 0-0:96.7.0*255; - Number of power failures, in phase Lx, 0-0:96.7.x*255; - Number of power failures, in any phase, 0-0:96.7.21*255.  Times of power failures are recorded in (x = 1,2,3): - Time of power failure, in all three phases, 0-0:96.7.10*255; - Time of power failure, in phase Lx, 0-0:96.7.1x*255; - Time of power failure, in any phase, 0-0:96.7.14*255. 

Short power failures are registered when the voltage level reaches a value below 10% of the nominal voltage level (230V) for a period longer than 100ms but shorter than 180 seconds. Short power failures are counted in object Number of short power failures (0-0:128.6.1*255).



Long power failures are registered when the power fail time reaches the threshold defined (in seconds) in object Time threshold for long power failure, 0-0:96.7.20*255. Long power failures are counted in: - Number of long power failures, in all three phases, 0-0:96.7.5*255; - Number of long power failures, in phase L1, 0-0:96.7.6*255; - Number of long power failures, in phase L2, 0-0:96.7.7*255; - Number of long power failures, in phase L3, 0-0:96.7.8*255; - Number of long power failures, in any phase, 0-0:96.7.9*255. Durations of long power failures are recorded in: - Duration of last long power failure, in all three phases, 0-0:96.7.15*255; - Duration of last long power failure, in phase L1, 0-0:96.7.16*255; - Duration of last long power failure, in phase L2, 0-0:96.7.17*255; - Duration of last long power failure, in phase L3, 0-0:96.7.18*255; - Duration of last long power failure, in any phase, 0-0:96.7.19*255.



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8.12. Switching device (option) The switching device (SD) is used to disconnect individual consumers from the grid. Disconnect control can be performed locally (from the meter functionality) or remotely, from the control centre HES over primary communication. The AM550 meter has a built-in switching device. Disconnect and reconnect can be requested: 

Remotely (via a communication): remote disconnect, remote reconnect;



Locally (limiter, prepayment, register monitor, single action scheduler, etc.): local disconnect, local reconnect; Manually (using push button, external key): manual disconnect, manual reconnect.



The SD state diagram and available state transitions are shown in Figure 72.

Figure 72: Disconnect state control diagram

Table 55 shows and describes all available switching device transitions. Transi- Transition Description tion name Remote Moves the Disconnect control object from the Disconnected (0) state directly to the Connected (1) state a reconnect without manual intervention. Remote Moves the Disconnect control object from the Connected (1) state to the Disconnected (0) state. b disconnect c

Remote Moves the Disconnect control object from the Ready for reconnection (2) state to the Disconnected (0) state. disconnect

d

Remote reconnect

Moves the Disconnect control object from the Disconnected (0) state to the Ready for reconnection (2) state. From this state, it is possible to move to the Connected (2) state via the manual reconnect transition (e).

e

Manual reconnect

Moves the Disconnect control object from the Ready for connection (2) state to the Connected (1) state.

f

Manual Moves the Disconnect control object from the Connected (1) state to the Ready for connection (2) state. disconnect From this state, it is possible to move back to the Connected (2) state via the manual reconnect transition (e)

g

Local From this state, it is possible to move back to the Connected (2) state via the manual reconnect transition (e). disconnect

Moves the Disconnect control object from the Connected (1) state to the Ready for connection (2) state. Transitions f) and g) are essentially the same, but their trigger is different.

h

Local reconnect

Moves the Disconnect control object from the Ready for connection (2) state to the Connected (1) state. Transitions e) and h) are essentially the same, but their trigger is different.

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8.12.1.Disconnect control The disconnect control function is used for the connection and disconnection of the premises of the consumer. The Disconnect control object (0-0:96.3.10) controls the connection and disconnection of the premises of the consumer. Attributes 1. Logical name 2. Output state 3. Control state 4. Control mode Specific methods 1. remote disconnect 2. remote reconnect

Data type Octet-string Boolean Enum Enum

Class ID 70

Code 0-0:96.3.10

Access R R R R/W

Min.

Max.

Default

0 0 0

1 2 6

1 1 1

Table 56: Disconnect control object

Object settings are:   

Output state Control state Control mode

Output state The Disconnect Output state shows the actual physical state of the switching device.  

FALSE – Open – The consumer is disconnected from the network - (0) TRUE – Closed – The consumer is connected to the network - (1)

Control State Control state defines the internal logical state of the switching device. Possible control states are:   

Disconnected – (0) Connected – (1) Ready for reconnection – (2)

When the switching device is in the Ready for reconnection control state, it is possible to perform manual connection on the meter by holding the Switching device button (lower meter button; see Figure 42) until ConnEct is shown on display.

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Control Mode Control mode defines available transitions in Disconnect control class (see Table 57). Mode Description 0

None. The disconnect control object is always in ‘connected’ state

Disconnection 1 Reconnection

Disconnection 2 Reconnection Disconnection 3 Reconnection Disconnection 4 Reconnection

Disconnection 5 Reconnection

Disconnection 6 Reconnection

Remote (b, c) Manual (f) – Press and hold the switching device button until dISconn appears and then release the button. Switching device status: LED is blinking. Local (g) Remote (d) Manual (e) – Press and hold the switching device button until EntEr appears and then release the button. Switching device status: LED turns off. Remote (b, c) Manual (f) – Press and hold the switching device button until dISconn appears and then release the button. Switching device status: LED is blinking. Local (g) Remote (a) Manual (e) – Press and hold the switching device button until EntEr appears and then release the button. Switching device status: LED turns off. Remote (b, c) Local (g) Remote (d) Manual (e) Remote (b, c) Local (g) Remote (a) Manual (e) – Press and hold the switching device button until EntEr appears and then release the button. Switching device status: LED turns off. Remote (b, c) Manual (f) – Press and hold the switching device button until dISconn appears and then release the button. Switching device status: LED is blinking. Local (g) Remote (d) Manual (e) – Press and hold the switching device button until EntEr appears and then release the button. Switching device status: LED turns off. Local (h) Remote (b, c) Local (g) Remote (d) Manual (e) – Press and hold the switching device button until EntEr appears and then release the button. Switching device status: LED turns off. Local (h)

Table 57: Disconnect control modes

Depending on the mode selected, manual reconnection and disconnection is possible by pressing the switching device button.

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Manual reconnection (all control modes): Display shows ConnEct (see Figure 73). Press the button for 5 seconds (until EntEr (see Figure 74) appears on the display) and then release it. If Extended key behaviour is configured in the Display configuration object (0-0:196.1.3*255), manual reconnection is performed immediately.

Figure 73: ConnEct on the display

Figure 74: EntEr on the display

Manual disconnection (control modes: 1, 2, 5): Press the button for 10 seconds (until dISconn (see Figure 75) appears on the display) and then release it.

Figure 75: dISconn on the display

8.12.2.Additional disconnection control functions AM550 supports the following additional disconnection-related functions:  

Disconnect control scheduler, which identifies, shows, and sets the dedicated time point for connection or disconnection; Disconnect control script table, which is used for remote reconnect and remote disconnect;



Disconnection control status, which is used for manipulation with different physical disconnect control devices e.g. electricity switching device, relay;



Disconnect control delay mode, which adds configurable delay mode on a switching device connection.

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8.13. Limitation In addition to collecting and processing energy consumption data, the AMI system offers load balancing and control. To achieve this, a current and demand limitation is implemented in the meter. During the short time period when the power consumption excides the contractual value for a specified time interval, the consumer is disconnected from the grid until normal conditions are achieved or penalty time ends. To handle consumption monitoring and disconnection of consumer premises, the following principles are used:  Phase current measurement,  Disconnection from the grid is performed by the switching device,  Threshold level settings in accordance with consumer contract and local regulator rules. The supported limitation type is implemented as defined by IDIS (average phase current monitoring).

8.13.1.Limiter Limiter functions are used to monitor the electrical network for exceeding maximum energy (power) in a predefined period of time. The Limiter object handles normal current and instantaneous power monitoring, as well as the emergency settings. The meter supports two limiter objects. The consumer can (after correcting the exceeding level) reconnect the network manually (by pressing the scroll button on the meter) or with remote connection (depending on the disconnector mode used). The threshold value can be a normal or an emergency threshold. The emergency threshold is activated via the emergency profile, which is defined by the emergency profile id, activation start time, and duration. The emergency profile id element is matched to the emergency profile group ID: this mechanism enables the activation of the emergency threshold only for a specific emergency group. The limitation or disconnection functionality can be activated in the meter itself or by remote action. The meter disconnects the network (via the switching device) if a maximum current or power limit has been exceeded during a predefined period of time. The current or power levels with the allowed exceeding periods are set in the meter. AM550 supports two limiter instances with OBIS codes 0-0:17.0.0*255 and 0-0:17.0.1*255. The IDIS specification defines only one limiter instance.

Figure 76: Limiter diagram

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8.13.2.Supervision monitor - IDIS AM550 meter features phase current limitation with three Register monitor objects:  

Supervision monitor 1 – Fuse supervision L1, 1-0:31.4.0*255; Supervision monitor 2 – Fuse supervision L2, 1-0:51.4.0*255;



Supervision monitor 2 – Fuse supervision L3, 1-0:71.4.0*255.

Every RM monitors the corresponding phase demand register. When the monitored value passes the threshold in the upward or downward direction, action up or action down is taken, respectively. For the AM550 meters, two thresholds are allowed to be set. IDIS specifies Supervision monitor objects 1-0:31.4.0*255 (SM1), 1-0:51.4.0*255 (SM2), and 1-0:71.4.0*255 (SM3) for a monitored value. This is not a directly measured phase current RMS (root mean square), but the averaged value over the number of periods. An action defines scripts to be executed when the monitored value of the reference object crosses the corresponding threshold:  

action up defines the action when the attribute value of the monitored register crosses the threshold in the upwards direction, action down defines the action when the attribute value of the monitored register crosses the threshold in the downwards direction.

8.14. Counters AM550 supports the following counters presented in Table 58. Object name Number of power failures, in any phase Number of long power failures, in any phase Watchdog resets Image Transfer Counter

Description The number of power failures in any phase represents the number of power outages shorter than the long-power-failure-time threshold (3 minutes) in any phase. The number of long power failures in any phase represents the number of power outages longer than the long-power-failure-time threshold (3 minutes) in any phase. The number of watchdog resets. The number of successfully transferred images (e.g. meter module image, modem image, M-bus device image).

OBIS code 0-0:96.7.21*255

0-0:96.7.9*255

0-0:128.6.0*255 0-0:96.63.10*255

Table 58: AM550 counters

8.15. Function activation With Function activation object (0-0:44.1.0*255), it is possible to enable or disable different functions, which are supported by the meter device. The AM550 firmware supports the following functions, which can be controlled through the Function activation interface:            

Activate or deactivate the capturing in Load profile 1 (function LPCAP_1) Activate or deactivate the capturing in Load profile 2 (function LPCAP_2) Activate or deactivate the capturing in Load profile 3 (function LPCAP_3) Activate or deactivate the capturing in Load profile 4 (function LPCAP_4) Activate or deactivate the capturing in M-Bus master load profile for channel 1 (function LPCAP_M1) Activate or deactivate the capturing in M-Bus master load profile for channel 2 (function LPCAP_M2) Activate or deactivate the capturing in M-Bus master load profile for channel 3 (function LPCAP_M3) Activate or deactivate the capturing in M-Bus master load profile for channel 4 (function LPCAP_M4) Activate or deactivate CIP on P1 port (function IF_HAN_1) Activate or deactivate display (function IF_DISPLAY) Activate or deactivate normal mode functionality on the display (function IF_DISP_TYP_NORM) Activate or deactivate switching device functionality (function SWITCH_DEV)

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8.16. Mirrored objects (option) By a customer request, it is possible that OBIS codes of energy and demand objects can be “mirrored” and they are displayed as mirrored objects. This means that “B” field of OBIS codes (A-B:C.D.E*F) of energy and demand objects is translated from “1-0:x.x.x.x” to “1-1:x.x.x.x”. The translation is also true for objects, which are used as configurable parameter settings (e.g. load profile capture objects, display list capture objects, etc). If “Mirror objects” is enabled, in System options object (0-0:128.90.1*255), B0 is set to 1 (see Figure 77).

Figure 77: Enabled Mirror objects in System options object

Example of mirrored object of Active energy import (+A):

1-0:1.8.0*255  1-1:1.8.0*255. NOTE The functionality Mirrored objects is an option and only factory settable.

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9. SECURITY The coarse partitioning of the E-Meter security devised into: 

physical security; and



logical security.

9.1. Physical security Physical security is comprised of:  sealing protection (see chapter 4.6 Sealing); and 

tamper detection.

9.1.1. Sealing protection There are two different sets of seal protection:  

first set protects terminal cover; the second protects exchangeable-communication module.

Locations of sealing points are presented in chapter 4.6 Sealing. Under a terminal cover of a three-phase meter, there is one more sealing point for sealing a U-I link accessprotection slider. The slider can be sealed with a calibration seal. (See chapter 4.2.4. U-I calibration link and Figure 24.)

9.1.2. Tamper detection If seals are tampered with and either of the covers is removed (terminal or communication module cover), then the corresponding tamper is detected and events are recorded in the Fraud detection event log (see chapter 8.7.2.2. Fraud detection log). In a case of terminal cover opening, the dedicated counter (Cover opening counter) is incremented as well.

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9.2. Logical security Logical security is divided into the following entities: 

DLMS/COSEM Security (Suite 0 level; see table below), which is divided into: - data access security, which controls access to the data held by a DLMS/COSEM server, - data transport security, which allows the sending party to apply cryptographic protection to ensure confidentiality and integrity.



Additional Communication Security - There are several Iskraemeco add-ons to DLMS/COSEM security. Foremost, a “DLMS channel options” object, for every channel on which the COSEM server is present, is introduced in order to cater different market requirements.



Secure Storage - Secure storage is a reserved space in the MCU memory, which is cryptographically protected. In secure storage, E-Meter stores all the necessary global-encryption, authentication, and master keys.

Security suite id 0

Authenticated encryption AES-GCM-128

Digital signature -

Key agreement -

Hash -

Key transport AES-128 key wrap

1

AES-GCM-128

ECDSA P-256

ECDH P-256

SHA-256

AES-128 key wrap

Table 59: Security suite

9.2.1. Roles Current Association (0-0:40.0.0*255) is an object in the meter, which contains the list of association objects and additional information of the current association on the local and/or remote interface. Roles (additional associations) are customer-specific associations used for different access levels for managing the device and retrieving the data from the device. There are up to ten additional customer-specific associations (roles) supported in the meter. Available roles are presented in Table 60. Their corresponding functions are listed in Table 61.

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COSEM Application Associations A5 A6 A7 A8 A9 A 10 A 11 A 12 A 13 A 14

Role 1 – Central System Read Write Role 2 – Central System Read Only Role 3 – Installer Role 4 – Admin Role 5 – Security Officer Role 6 – Calibration and Testing Role 7 – Maintenance Role 8 – Display Role 9 – Customer Role 10 – not used; reserved for future use

Client SAP

L – Local/ Enabled/ Accessible meter functions R – Remote/ Disabled (Designations described in Table 61) S – Specific

17 18 19 20 21 22 23 24 25 26

Enabled Enabled Enabled Enabled Enabled Enabled Enabled Enabled Enabled Disabled

a, b, c, g, t a, b, f, g, t a, b, c, d, e, f, g, h, t a, b, c, d, e, f, g, h, j, m, n, o, p, t i, j, k, q, s, t a, b, c, d, e, f, g, h, m, n, o, t a, b, c, d, e, f, g, h, j, t a, t N/A

L L L L+R L+R L R L L N/A

Table 60: List of available Roles

b

List of available functions for Roles Reading meter registers:  Reading meter registers  Reading billing registers  Reading meter objects (parameter scheme)  Reading measurement registers Reading load profiles, logbooks

a

Assignment of Role n (n = 1, 2, 3 … 9) 1, 2, 3, 4, 6, 7, 8

1, 2, 3, 4, 6, 7

c

Activating/deactivating display

1, 3, 4, 6, 7

d

Activating/deactivating load profile

3, 4, 6, 7

e

Activating/deactivating Consumer interface (P1)

3, 4, 6, 7

f

Switching device on/off

2, 3, 4, 6, 7

g

Setup date and time

1, 2, 3, 4, 6, 7

h

Meter parameterization and configuration 3, 4, 6, 7 (including sw. device):  Meter parameterization and configuration  Change parameters for local (P0), consumer (P1) interface  Change communication parameters  Change other meter parameters  Tariff setup  FW activation Change meter security parameters 5

i j

4, 7

k

Parameterization of sub-metering devices:  Pairing E-meter with G-meter Download of meter NLRFW (Application)

l

Download of meter LRFW (Core)

5

m

Delete content of load profiles, logbooks

4, 6

n

Set meter to test mode

4, 6

o

Reset meter registers

4, 6

p

ADMIN self-exclusion

4

q

ADMIN unblocking

5

r

IDIS Association self-exclusion

IDIS Management association *

s

IDIS Association unblocking

5

t Access to exclusive COSEM SAP * IDIS Management association is disabled Table 61: List of available functions for Roles

5

1, 2, 3, 4, 5, 6, 7, 8

NOTE If any of additional customer-specific associations (roles) are defined for use, see corresponding appendix of this document, where the roles are described.

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10. FIRMWARE UPDATE The AM550 meter supports FW upgrade of the E-meter, communication modules, and external sub-meters. This provides the possibility to add new functionalities or patch bugs after the device is already in the field. According to COSEM/DLMS specification, AM550 utilizes the Image Transfer COSEM class (class_id = 18) for transferring binary files, called Images, to COSEM servers (E-meter). Image upgrade usually takes place in several steps: Step 1: (Optional): Client checks image block size with server Step 2: Client initiates Image transfer Step 3: Client transfers Image blocks Step 4: Client checks completeness of the Image Step 5: Server verifies the Image (Initiated by the client or on its own) Step 6: (Optional): Client checks the information on the images to activate Step 7: Server activates the Image(s) (Initiated by the client or on its own) AM550 meters offer the possibility to upgrade the firmware during operation. Please note that a FW update is only possible in compliance with national laws and/or regulations.

NOTE Image upgrade supports only one M-Bus-device upgrade at the same time.

10.1. Type of images The AM550 meter supports upgrading the following devices: 

E-meter itself: - Legally Relevant FW (LRFW) part and - Legally Non-Relevant FW (LNRFW) part. These two parts are physically separate programs, placed in separate memory locations of the memory inside the meter. However, they are both stored in the flash memory of the MCU.



WAN communication module Firmware

In the measuring system, the following entities can be upgraded with new FW (see Figure 78):  Electrical Meter Legally Non-Relevant Part of Firmware – BLUE.  Electrical Meter Legally Relevant Part of Firmware – WHITE. 

WAN communication module Firmware (or just a part of it) – RED.



wM-Bus communication module Firmware inside the E-Meter (if wM-Bus exists) – PURPLE.



Sub-meters (Gas, Heat, Water...) Firmware, possible form different manufacturers. – ORANGE, LIGHT-GREEN, GREEN.

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Figure 78: Different approaches/options to FW Upgrade

There are two general types of images. 

Images, which are verified by the E-Meter. These images can have a source from different manufactures (E-Meter producer, communication module (e.g. GPRS modem)). Those images, together with their Identification, are then signed by the E-Meter manufacturer with an ECDSA signature for integrity checking and for authenticity.



Sub-Meter Images. These images are just transferred with Image Upgrade COSEM methods to E-Meter’s temporary storage. They are not modified in any way by the E-Meter producer. Verification and activation is executed in Sub-Meter devices.

The E-Meter uses the Identification value provided at the time of Image Transfer Initiate method execution to differentiate between the two types of images. See Table 62. Image type

OBIS code version

E-Meter LRFW 1-0:0.2.0*255 (CORE) E-Meter LNRFW 1-1:0.2.0*255 (Application) E-Meter LRFW 1-5:0.2.0*255 (CLR Application) WAN communica- 1-2:0.2.0*255 tion module Table 62: Image types

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ID example

Signature type

ISK550EC0103001

OBIS code signature 1-0:0.2.8*255

ISK550EA0103001

1-1:0.2.8*255

ECDSA over SHA2-256

ISK550ER0103001

1-5:0.2.8*255

SHA2-256

ISKMO6HL6528006

1-2:0.2.8*255

ECDSA over SHA2-256

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11. ASSOCIATION The communication between two devices can be established on several peer protocol layers. This section presents different Application associations between the E-meter (the server) and the COSEM client. In order for effectively exchange information within an Application association, the pair of AE-invocations shall be mutually aware of and follow a common set of rules that govern the exchange. This common set of rules is called the application context of the application association. COSEM objects that contain the information about the current application association with the application context are described in details. Within the current application association different parameters may be changed, thus the number of programming accesses is registered along with the timestamp of the last attempt.

11.1. SAP assignment SAP assignment list contains the list of all logical devices and their SAP addresses within the physical device. The interface class “SAP assignment list” contains the information about the assignment of the logical devices in the physical device. Example: Iskraemeco meter with the “COSEM Logical Device Name” ISK550TM12345678 has the SAP assignment shown in Table 63. SAP Assignment

Physical device name

1

ISK550TM12345678

Table 63: COSEM SAP assignment example

Device ID is used in the last part of the COSEM Logical Device Name, thus guaranteeing uniqueness of the name. The COSEM Logical Device Name is used to construct the System Title, which is used in COSEM security. The Client dictates the type of the association because Server SAP is always 1. The next section briefly encapsulates the core features of the respective association. The firmware inside the meter supports Application Associations, indicated in Table 64.

COSEM Application Associations A0 A1 A2 A3 A 5 – A 14

Enabled Interface /Disabled Local/Remote/Specific Enabled P1 CIP specific 103 Enabled Local + Remote 16 Enabled Local + Remote 1 Enabled Pre-established push specific 102 For more information, see chapter 9.2.1. Roles. Client SAP

IDIS CIP Association IDIS Public Association IDIS Management Association IDIS Pre-established Association Roles (additional associations) – (OPTION)

Table 64: COSEM Application Associations

CIP association supports the CIP functionality. (For more information, see chapter 8.4. Push.) Public association is used for reading basic device configuration information (e.g. SAP, COSEM logical device name, association, serial numbers ...). It is not strongly secured. The Public association is available on remote communication and as well on local interface. Public association is also used to read the invocation counter. Management association is used for management of the device, retrieving the data from the device and authorizing actions in the meter. The Management association is available on remote communication as well as on local interface i.e. optical port. Pre-established association is used for PUSH notifications via data-notification service.

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12. INSTALLATION PROCEDURE WARNING Minimum cross section of a wire shall be according to standards and national regulations. The installer is obligated to perform the installation procedure in accordance with the national legislation and internal norms of the utility. For more information, see chapter 1. SAFETY INFORMATION. The meter should be installed according to the enclosed connection diagram (see chapter 3.5. Connection diagram). The Connection diagram can be found on the inner side of the terminal cover (see chapter 4.3. Terminal cover).

12.1. Preparation of cables WARNING Usage of cable end sleeves is mandatory.

Figure 79: Properly prepared cables

12.1.1.Power (main) cables CAUTION See warning in the chapter 12. INSTALLATION PROCEDURE. Use cables with a cross section from 4 mm2 up to 25 mm2 (diameter of 8.5 mm) or 6 mm2 up to 35 mm2 (diameter of 9.5 mm). See Table 2, Table 3, or Table 4. Remove approx.18 mm of insulation on the power (main) cables.

Figure 80: Power cables preparation for AM550 meter

WARNING It is dangerous for life, if cable insulation is removed in too long length.

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If minimum allowed wire cross-section (2.5 mm2) for main terminals is used, the instructions described in following subchapters must be followed. For easy and reliable installation of cable with 2.5 mm2 wire cross-section, terminal reducing insert (Figure 82) can be used. Installation without the reducer can lead to the decentralization of installed wires (see incorrect part of Figure 81). Nevertheless, the installation of cable with 2.5 mm2 wire cross-section can be done with or without terminal reducing insert.

12.1.1.1. Installation without terminal reducing insert WARNING Possible hazard due overheating if cables are not fitted with adequate torque. In case of two screws, both of them must be screwed with adequate torque. Possible hazard due overheating, if only one screw is tightened. 1. Insert properly prepared cable with 2.5 mm2 wire cross-section into the centre of terminal busbar. 2. Screw the terminal screw with appropriate torque (see Table 2, Table 3, or Table 4).

terminal screw wire

terminal busbar

Figure 81: Properly inserting and fixing cable with 2.5 mm2 wire cross-section in main terminal

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12.1.1.2. Installation with terminal reducing insert WARNING Possible hazard due overheating if cables are not fitted with adequate torque. In case of two screws, both of them must be screwed with adequate torque. Possible hazard due overheating if only one screw is tightened. Terminal reducing insert (Figure 82) is size limiter, which helps an installer to centralize cable of 2.5 mm 2 wire cross-section into the centre of terminal busbar. The reducing insert is made of high quality self-extinguishing UV-stabilized polycarbonate that can be recycled. It is made in one piece of eight inserts and if needed, it can be split into individual inserts. NOTE Terminal reducing insert can be delivered only upon customer request.

Figure 82: Terminal reducing insert (option)

Installation of the reducing insert is presented in Figure 83: 1. Correctly orient the insert – printed UP is on top side. 2. Push into the terminal hole/holes to the end.

Figure 83: Installation of terminal reducing insert

When the terminal reducing insert is correctly inserted, insert cables and screw the terminal screws with appropriate torque (see chapter 4.2.1. Current and voltage terminals).

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12.1.2.Cables for Auxiliary terminals For these terminals, cables with a cross section of maximum 2.5 mm2 can be used (see Table 2, Table 3, or Table 4). Maximum 8 mm of cable isolation should be removed.

12.1.3.Ethernet cable For Ethernet interface, refer to chapter 4.2.2.1.2. Ethernet (option). NOTE In a case the meter is equipped with integrated Ethernet interface, a shielded cable must be used.

Pin No.

Terminal

Signal

1

TxD+

Transmitted Data +

2

TxD-

Transmitted Data -

3

RxD+

Received Data +

6

RxD-

Received Data -

Table 65: RJ45 pin assignment of mail connector

Figure 84: RJ45 male connector (example of shielded cable) and pin designation

12.1.4.P1 port connector For connection to P1 port, a standard RJ12 male connector with the appropriate 6-core cable should be used. (See Figure 85, Figure 86, and Table 66).

Figure 85: P1 port – RJ12 female socket

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AM550 User manual Pin # 1 2 3 4 5 6

Signal name +5 V Data Request Data GND n.c. Data Data GND

1

Passive P1

2

Active P1

Description +5 V Data Request Data Ground Not connected Data Line Data Ground

Remark Input – from external device 1 / Output – for external device 2 Input

Output. Open collector Power supply line IN 1 / Power supply line OUT 2

Table 66: Pin designation of RJ12 connector (for passive P1)

NOTE Data Ground (pin 3) and Power Ground (pin 6) are internally connected (applies to the both connectors, active and passive).

Figure 86: RJ12 male connector and pin designation

NOTE If the P1 port is not in use, make sure to close the rubber lid properly to fulfil IP-protection requirements and comply with the ESD standard.

12.2. Mounting and installation procedure NOTE Electrostatic electricity can harm some parts of the electronic meter. To prevent electrostatic damage, discharge static electricity from your body before the procedure. You can do so by touching an unpainted grounded metal surface. 1. Disconnect the power cables from the electricity network, if applicable. 2. Remove the terminal cover. 3. Mount the meter to the wall or other vertical surface. For fixing dimensions, see chapter 4.1. Technical figures and dimensions. 4. Connect the power cables to the meter; screws on the terminals should be tightened with a corresponding torque (see chapter 4.2.1. Current and voltage terminals). 5. Connect other terminals (inputs/outputs, M-Bus…) as needed (see chapter 4.2.2. Other terminals (options)). 6. Connect other devices via P1 port (see chapters 6.3. Communication module – Consumer interface (P1) and 12.1.4.P1 port connector), if needed. 7. Check whether the meter is properly connected. 8. Check the quality of the cable connection. 9. Close the terminal cover and seal the meter. 10. Connect the meter to the electricity network; consider the accurate energy flow direction. 11. Use service mode to check the installation.

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12.3. SIM card installation RECOMMENDATION To meet the performance, reliability and life span requirements of the metering environment, industrial grade SIM card in accordance to JEDEC, GSM and ETSI standards, should be used. RECOMMENDATION SIM card handling Do not touch the metal part of the SIM card (see Figure 88), neither the connector of the SIM-card holder (see Figure 87) with bare hands! They can be damp or wet. When you are going to touch a SIM card or the SIM-card holder (e.g. when inserting a SIM card into the holder), use gloves (ESD, fine cotton…) to protect the metal parts from contact with damp/liquid. In long term, this could cause a corrosion and, consequently, a malfunction of the SIM card. If GSM/GPRS, UMTS (3G) or LTE communication module (Figure 87) will be used in the meter, for establishing successful communication, a SIM card (Figure 88) should be installed into the module. For more information about modules, see chapter 6. METER MODULES. On the bottom side of the module, there is the SIM-card holder (see Figure 87). A SIM card (example in Figure 88) must be properly inserted that successful communication can be established.

Figure 87: Bottom side of the communication module with SIM-card colder (example of hinged type of the holder)

NOTE SIM-card holder type can be different (hinged type or push-push type). For more information, see the technical description of corresponding communication module.

Figure 88: Example of a SIM card

For properly inserting a SIM card into communication module, follow the instructions in corresponding technical description of the module.

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13. DISASSEMBLING OF A MODULE The meter possesses a module area, which allows exchange of WAN and HAN modules types. WARNING Only authorised personnel should open the module cover.

WARNING Because of the general safety issues, it is recommended that meter is unplugged from the electricity network before removal of module cover and communication modules. DANGER Only modules in original plastic housing can be inserted. It is life-hazardous to insert only module’s PCB. The following steps represent the procedure of removing communication modules for a review: 1. Unscrew the sealing screws of the module cover.

Figure 89: Removing communication module – step 1

2. Remove the module cover – slide it out from the base meter (Figure 90).

Figure 90: Removing communication module – step 2

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3. Remove the P1 port module – lift it up (over the pin on the communication module cover, see Figure 93) and slide it left from the module cover (Figure 91). For a detailed description of removing the P1 module out of the module cover, see chapter 13.1. Removing the P1 module out of the meter cover.

Figure 91: Removing communication module – step 3

4. Remove the communication module - slide it out from the base meter as it is shown in Figure 92.

Figure 92: Removing communication module – step 4

NOTE Please do not remove the module’s PCBs from the plastic PCB cover!

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13.1. Removing the P1 module out of the meter cover The P1 module is fitted in the inner side of the module cover with two snap fit elements.

Figure 93: P1 module – snap-fit elements in the inner side of the communication module cover

To remove the P1 module out of the module cover, follow the next procedure (see Figure 94): 1. With the slot type of a screwdriver (or some similar thin tool), lift up the left side of the module housing (step 1 in Figure 94) until the side detaches from the snap-fit element. 2. When the left side of the housing is lifted up, on the outside of module cover, push the closed rubber lid of the P1 port towards the inner side of the module cover (step 2 in Figure 94). Keep pushing. 3. With the slot type of a screwdriver, lift up the bottom side of the module housing (step 3 in Figure 94) until the side detaches from the snap-fit element. 4. Pull out the P1 module.

2 push from outside

1 4

3

Figure 94: P1 module removing procedure

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Figure 95: Removed P1 module

NOTE Please do not remove the module’s PCBs from the plastic PCB cover!

NOTE If the P1 communication module is removed, it should be replaced with a P1 “dummy” module (Figure 96) to cover the empty slot and fulfil IP-protection requirements (Figure 97). The P1 “dummy” module is an imitation of the P1 module, without the communication functionality.

Figure 96: P1 “dummy” module

Figure 97: P1 “dummy” module inserted in the module cover

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14. METER MAINTENANCE No maintenance is required during the meter’s lifetime. The implemented metering technique, built-in components, and manufacturing procedures ensure a high long-term stability of meters, so there is no need for their recalibration during their lifetime.

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15. METER DEINSTALLATION 1. 2. 3. 4. 5.

Disconnect the meter from the network. Remove the terminal cover. Unscrew all connected wires. Unscrew the fixing screws and remove the meter. After de-installation, protect all disconnected wires against electric shock.

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16. TECHNICAL CHARACTERISTICS 16.1. One-phase meter Model type Reference voltage Extended operating voltage range Reference frequency Reference current Maximum current Thermal current Start-up current Short circuit current Utilization category (EN 62052-31) Active energy (IEC 62053-21 / EN 50470) Reactive energy (IEC 62053-23) Meter shutdown voltage Meter restoration voltage Power consumption in voltage circuit (meter with all integrated components) Additional consumption Backlight Power consumption in current circuit (meter with all integrated components) Operating temperature of meter Operating temperature of LCD display Storage temperature Temperature coefficient

AM550-ED0 230 V

AM550-ED1 230 V

AM550-EB2 230 V

-20% +15%

-20% +15%

20% +15%

50 Hz 5A 60 A 120% Imax < 0.4% of reference current 30  Imax

50 Hz 5A 85 A 120% Imax < 0.4% of reference current 30  Imax

50 Hz 5A 100 A 120% Imax < 0.4% of reference current 30  Imax

UC1

UC2

UC2

Class 1/ Class B

Class 1/ Class B

Class 1 /Class B

Class 2

Class 2

Class 2

< 165 V 176 V

< 165 V 176 V

< 165 V 176 V

1.7 W and 9.9 VA

1.7 W and 9.9 VA

1.7 W and 9.9 VA

0.1 W / 0.1 VA

0.1 W / 0.1 VA

0.1 W / 0.1 VA

0.05 VA (Iref = 5 A) 3.9 VA (Imax = 60 A)

0.05 VA (Iref = 5 A)

0.03 VA (Iref = 5 A)

-40 °C to +70 °C

-40 °C to +70 °C

-40 °C to +70 °C

-25 °C to +70 °C

-25 °C to +70 °C

-25 °C to +70 °C

-40 °C to +80 °C -40 °C to +70 °C < ± 0.05% per K

-40 °C to +80 °C -40 °C to +70 °C < ± 0.05% per K

-40 °C to +80 °C -40 °C to +70 °C < ± 0.05% per K

IP54

IP54

IP54

contact 8 kV, air 15 kV

contact 8 kV, air 15 kV

contact 8 kV, air 15 kV

10 V/m active, 30 V/m passive Class B 4 kV into voltage circuit / 2 kV into other

10 V/m active, 30 V/m passive Class B 4 kV into voltage circuit / 2 kV into other

10 V/m active, 30 V/m passive Class B 4 kV into voltage circuit / 2 kV into other

OVC III

OVC III

OVC III

4 kV * into voltage circuit / 1 kV into other

4 kV * into voltage circuit / 1 kV into other

4 kV * into voltage circuit / 1 kV into other

10 V

10 V

10 V

4 kVrms, 50 Hz, 1 min 12 kV into voltage circuit, 6 kV into other

4 kVrms, 50 Hz, 1 min 12 kV into voltage circuit, 6 kV into other

4 kVrms, 50 Hz, 1 min 12 kV into voltage circuit, 6 kV into other

0.5 s/day

0.5 s/day

0.5 s/day

7 days Antistatic polycarbonate plastic  Shock test according to IEC 60068-2-27

7 days Antistatic polycarbonate plastic  Shock test according to IEC 60068-2-27

7 days Antistatic polycarbonate plastic  Shock test according to IEC 60068-2-27

Protective class Ingress protection (IEC 60529) Electrostatic discharges (IEC 61000-4-2) Electromagnetic RF fields (IEC 61000-4-3) Radio interference suppression Fast transient burst (IEC 61000-4-4) Overvoltage category (IEC 60664-1) Surge (IEC 61000-4-5) Immunity to conducted disturbances (IEC 61000-4-6) Insulation strength Impulse voltage 1.2/50µs (EN 50470-1) Internal clock accuracy; at +23 °C (IEC 62054-21) Backup with supercap Case Mechanical conditions

V3.00 – English

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16. TECHNICAL CHARACTERISTICS

AM550 User manual Model type

AM550-ED0  Vibration test according to IEC 60068-2-6

AM550-ED1  Vibration test according to IEC 60068-2-6

AM550-EB2  Vibration test according to IEC 60068-2-6

Humidity Altitude Pollution degree Type of meter Weight (without inserted FEM modules) Height/Width/Depth (in mm) Integrated switching device (Supply Control Switch) Insulation strength contact to contact Mechanical life of contacts (number of mechanical switching operations)