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A41/A42
1
User Manual
Page 2
2
Page 3
A41/A42
3
User Manual
Document ID: 2CMC484002M0201
Revision: C
2020-12-16
Page 4
Disclaimer
4
The information in this document is subject to change without notice and should
not be construed as a commitment by ABB Spa. ABB Spa assumes no
responsi-bility for any errors that may appear in this document.
In no event shall ABB Spa be liable for direct, indirect, special, incidental or
con-sequential damages of any nature or kind arising from the use of this
document, nor shall ABB Spa be liable for incidental or consequential damages
arising from use of any software or hardware described in this document.
Copyrights
Trademarks
Contact
This document and parts thereof must not be reproduced or copied without written
permission from ABB Spa, and the contents thereof must not be imparted to a
third party nor used for any unauthorized purpose.
The software or hardware described in this document is furnished under a license
and may be used, copied, or disclosed only in accordance with the terms of such
license.
© Copyright 2020 ABB Spa. All rights reserved.
ABB Spa is a registered trademark of the ABB Group. All other brand or
product
names mentioned in this document may be trademarks or registered
trademarks of their respective holders.
ABB Spa
via dell'Industria, 18
20009 - Vittuone - Milano
Italy
Tel: +39 02 2415 0000
Page 5
Table of Content
5
Table of Content
1 Product Overview ......................................................................................... 9
1.1 Meter Parts .................................................................................................................. 10
1.2 Meter Types .................................................................................................................12
2 Installation .................................................................................................. 15
2.1 Mounting the Meter ...................................................................................................... 16
2.2 Environmental Considerations ..................................................................................... 18
2.3 Installing the Meter ...................................................................................................... 19
2.3.1 Configuring the meter ........................................................................................ 20
2.4 Wiring Diagrams .......................................................................................................... 21
2.4.1 Direct connected meters .................................................................................... 21
2.4.2 Transformer connected meters without voltage transformer ............................. 21
2.4.3 Transformer connected meters with voltage transformer .................................. 22
2.4.4 Inputs/outputs .................................................................................................... 22
2.4.5 Communication .................................................................................................. 23
3 User Interface ............................................................................................. 25
3.1 Display ......................................................................................................................... 26
4 Meter Settings ............................................................................................ 31
4.1 Settings and Configurations ......................................................................................... 32
4.1.1 Setting Date ....................................................................................................... 32
4.1.2 Setting Time ....................................................................................................... 33
4.1.3 Setting Ratios .................................................................................................... 33
4.1.4 Setting Pulse Output .......................................................................................... 33
4.1.5 Setting I/O .......................................................................................................... 34
4.1.6 Setting Alarm ..................................................................................................... 35
4.1.7 Setting Currency/CO2 ........................................................................................ 36
4.1.8 Setting M-Bus .................................................................................................... 36
4.1.9 Setting RS-485 .................................................................................................. 37
4.1.10 Setting IR Side ................................................................................................. 37
4.1.11 Setting Upgrade Consent ................................................................................ 39
4.1.12 Setting Pulse LED ............................................................................................ 39
4.1.13 Setting Tariff .................................................................................................... 39
4.1.14 Setting Previous Values ................................................................................... 40
4.1.15 Setting Load Profile ......................................................................................... 40
4.1.16 Setting Demand ............................................................................................... 41
4.1.17 Resetting Resettable Registers ....................................................................... 41
5 Technical Description ................................................................................ 43
5.1 Energy Values ............................................................................................................. 44
5.2 Instrumentation ............................................................................................................ 46
5.3 Harmonics .................................................................................................................... 47
5.3.1 Measuring Harmonics ........................................................................................ 49
5.4 Alarm ........................................................................................................................... 51
5.5 Inputs and Outputs ...................................................................................................... 52
5.5.1 Tariff Inputs ........................................................................................................ 52
5.5.2 Pulse Outputs .................................................................................................... 53
5.5.2.1 Pulse Frequency and Pulse length ........................................................ 53
5.6 Internal Clock ............................................................................................................... 55
5.7 Logs ............................................................................................................................. 56
5.7.1 System Log ........................................................................................................ 56
5.7.2 Event Log ........................................................................................................... 57
5.7.3 Net Quality Log .................................................................................................. 57
5.7.4 Audit Log ............................................................................................................ 58
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Table of Content
6
5.7.5 Settings Log ....................................................................................................... 58
5.7.6 Event codes ....................................................................................................... 58
5.8 Demand ....................................................................................................................... 60
5.9 Previous Values ........................................................................................................... 62
5.10 Load Profile ................................................................................................................ 64
6 Technical data ............................................................................................ 67
6.1 Technical Specifications .............................................................................................. 68
6.2 Physical dimensions .................................................................................................... 72
7 Measurement Methods .............................................................................. 73
7.1 Measuring Energy ........................................................................................................ 74
7.1.1 Single Phase, 1-Element Metering .................................................................... 76
8 Service & Maintenance .............................................................................. 79
8.1 Service and Maintenance ............................................................................................ 80
9 Communication with Modbus ................................................................... 81
9.1 Bus Description ............................................................................................................ 82
9.2 About the Modbus Protocol ......................................................................................... 83
9.2.1 Function Code 3 (Read holding registers .......................................................... 83
9.2.2 Function Code 16 (Write multiple registers) ...................................................... 85
9.2.3 Function Code 6 (Write single register) ............................................................. 86
9.2.3.1 Exception Responses ............................................................................ 87
9.3 Reading and Writing to Registers ................................................................................ 88
9.4 Mapping Tables ........................................................................................................... 89
9.5 Historical Data ........................................................................................................... 100
9.5.1 Quantity identifiers ........................................................................................... 103
9.6 Previous Values ......................................................................................................... 108
9.6.1 Reading Previous Values ................................................................................ 110
9.7 Demand ..................................................................................................................... 112
9.7.1 Reading Demand ............................................................................................. 114
9.8 Event logs ..................................................................................................................116
9.8.1 Reading Event logs .......................................................................................... 118
9.9 Load profile ................................................................................................................119
9.9.1 Reading Load profile ........................................................................................ 121
9.10 Configuration ........................................................................................................... 122
9.10.1 Previous values ............................................................................................. 122
9.10.2 Demand ......................................................................................................... 123
9.10.3 Load profile .................................................................................................... 126
9.10.4 Alarms ............................................................................................................ 127
9.10.5 Inputs and outputs ......................................................................................... 131
9.10.6 Tariffs ............................................................................................................. 133
9.10.7 Daylight Savings Time ................................................................................... 140
10 Communication with M-Bus .................................................................. 143
10.1 Bus Description ........................................................................................................ 145
10.2 Protocol Description ................................................................................................. 146
10.2.1 Telegram Format ........................................................................................... 151
10.2.1.1 Field description ................................................................................ 151
10.2.2 Value Information Field codes ....................................................................... 157
10.2.2.1 Standard VIF codes ........................................................................... 157
10.2.2.2 Standard codes for VIFE used with extension indicator FDh ............ 157
10.2.2.3 Standard codes for VIFE ................................................................... 158
10.2.2.4 First manufacturer specific VIFE-codes ............................................. 158
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Table of Content
7
10.2.2.5 VIFE-Codes for reports of record errors (meter to master) ............... 160
10.2.2.6 VIFE-Codes for object actions (master to meter) .............................. 160
10.2.2.7 2:nd manufacturer specific VIFE followed after VIFE 1111 1000 (F8 hex): 160
10.2.2.8 2:nd manufacturer specific VIFE followed after VIFE 1111 1001 (F9 hex): 160
10.2.2.9 2:nd manufacturer specific VIFE followed after VIFE 1111 1110 (FE hex): 161
10.2.3 Communication process ................................................................................ 161
10.2.3.1 Selection and secondary addressing ................................................. 163
10.3 Standard Readout of Meter Data ............................................................................. 164
10.3.1 Example of the 1st telegram (all values are hexadecimal) ............................ 164
10.3.2 Example of 2nd telegram (all values are hexadecimal) ................................. 168
10.3.3 Example of 3rd telegram (all values are hexadecimal) .................................. 172
10.3.4 Example of the 4th telegram (all values are hexadecimal) ............................ 177
10.3.5 Example of the 5th telegram (all values are hexadecimal) ............................ 181
10.3.6 Example of the 6th telegram (all values are hexadecimal) ............................ 183
10.3.7 Example of the 7th telegram (all values are hexadecimal) ............................ 187
10.3.8 Example of the 8th telegram (all values are hexadecimal ............................. 190
10.3.9 Example of the 9th telegram (all values are hexadecimal ............................. 193
10.4 Special Readout of Meter Data ................................................................................ 196
10.4.1 Readout of Load Profile Data ........................................................................ 197
10.4.1.1 Examples of Readouts of Load Profile Data ...................................... 202
10.4.2 Readout of Demand Data .............................................................................. 205
10.4.2.1 Examples of Readouts of Demand Data ........................................... 206
10.4.3 Readout of Previous Values .......................................................................... 211
10.4.3.1 Examples of Readouts of Previous Values ....................................... 213
10.4.4 Readout of Event Log Data ........................................................................... 216
10.4.4.1 Example of readout of log data .......................................................... 218
10.4.5 Readout of Current Harmonics ...................................................................... 221
10.4.5.1 Examples of Readouts of Current Harmonics Data ........................... 222
10.4.6 Readout of Voltage Harmonics ...................................................................... 230
10.4.6.1 Examples of readout of voltage harmonics data ............................... 231
10.5 Sending Data to the Meter ....................................................................................... 239
10.5.1 Set tariff ......................................................................................................... 239
10.5.2 Set primary address ....................................................................................... 240
10.5.3 Change baud rate .......................................................................................... 240
10.5.4 Reset power fail counter ................................................................................ 241
10.5.5 Set Current transformer (CT) ratio - primary current ..................................... 241
10.5.6 Set voltage transformer (VT) ratio - primary voltage ...................................... 242
10.5.7 Set current transformer (CT) ratio - secondary current .................................. 242
10.5.8 Set voltage transformer (VT) ratio - secondary voltage ................................. 243
10.5.9 Select status information ............................................................................... 243
10.5.10 Reset of stored state for input 1 ................................................................... 244
10.5.11 Reset of stored state for input 2 ................................................................... 244
10.5.12 Reset of stored state for input 3 ................................................................... 245
10.5.13 Reset of stored state for input 4 ................................................................... 245
10.5.14 Reset of input counter 1 ............................................................................... 246
10.5.15 Reset of input counter 2 ............................................................................... 246
10.5.16 Reset of input counter 3 ............................................................................... 247
10.5.17 Reset of input counter 4 ............................................................................... 247
10.5.18 Set output 1 ................................................................................................. 248
10.5.19 Set output 2 ................................................................................................. 248
10.5.20 Set output 3 ................................................................................................. 249
10.5.21 Set output 4 ................................................................................................. 249
10.5.22 Reset power outage time ............................................................................. 250
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Table of Content
8
10.5.23 Send password ............................................................................................ 250
10.5.24 Set password ............................................................................................... 250
10.5.25 Set date and time ......................................................................................... 251
10.5.26 Set date ....................................................................................................... 252
10.5.27 Reset demand, previous values, load profile and logs ................................ 252
10.5.28 Reset resettable active energy import ......................................................... 253
10.5.29 Reset resettable active energy export ......................................................... 253
10.5.30 Reset resettable reactive energy import ...................................................... 254
10.5.31 Reset resettable reactive energy export ...................................................... 254
10.5.32 Freeze demand ............................................................................................ 255
10.5.33 Set write access level .................................................................................. 255
10.5.34 Set tariff source ............................................................................................ 256
10.5.35 Set CO2 conversion factor ........................................................................... 256
10.5.36 Set currency conversion factor .................................................................... 257
11 Troubleshooting ..................................................................................... 259
11.1 Error, warnings and information codes .................................................................... 260
Page 9
Chapter 1: Product Overview
9
Product Overview
Overview
In this chapter
This chapter describes the parts of the meter and the different meter types.
The following topics are covered in this chapter:
1.1 Meter Parts ........................................................................................... 10
1.2 Meter Types ......................................................................................... 12
Page 10
Product Overview
OK
SET
3
3
3
3
3
3
4
5
6
7,8
9,10
11
12
13
14
15
16
17
2
1
10
1.1 Meter Parts
Illustration
The parts of the meter are shown in the illustration below:
Parts description
The following table describes the parts of the meter:
Item Description Comments
1 Terminal for communication connection
2 Terminal for input/output connection
3 Sealing point. Seal thread can be used to seal the
cover.
4 Sealable terminal cover Protective cover with printed wiring
5 LED Flashes in proportion to the energy
6 Set button Enter configuration mode
7 Sealable terminal cover Protective cover with printed wiring
8 Terminal block Terminal for all voltages and cur-
9 Sealable cover To protect the LCD and seal the set
diagram on the inside.
measured.
diagram on the inside
rents
button
Page 11
Product Overview
11
Item Description Comments
10 Product data Contains data about the meter type
11 OK button Perform an action or choose a menu
12 Down button Toggle down (toggle right in the
main menu)
13 Up button Toggle up (toggle left in the main
menu)
14 Exit button Exit to the previous menu or toggle
between default and main menu.
15 Display LCD for meter reading
16 Optical communication interface For IR communication
17 Sealing
Page 12
Product Overview
12
1.2 Meter Types
Main groups
Subgroups
The A41/A42 meters are divided into two main groups:
• Direct connected meters for currents 80A.
• Transformer connected meters for currents > 80A using external current
transformer with secondary current 6A and optional voltage transformer.
The main meter groups are further divided into subgroups depending on the functionality of the respective meter:
Subgroup Functionality
Platinum Active energy, Reactive energy, Apparent energy, Import/export of energy,
Resettable energy registers, Harmonics, Configurable I/O (except the
690V meter which has fixed I/O), Advanced clock functions (load profiles),
Basic clock functions (Tariff control, Previous values, Max/min demand,
Event log), Class 0.5 or Class 1, Tariffs, Fixed I/O, Pulse output/alarm
Gold Active energy, Reactive energy, Apparent energy, Import/export of energy,
Resettable energy registers, Basic clock functions (Tariff control, Previous
values, Max/min. demand, Event log), Class 0.5 or Class 1, Tariffs, Fixed
I/O, Pulse output/alarm
Silver Active energy, Reactive energy, Apparent energy, Import/export of energy,
Resettable energy registers, Class 0.5 or Class 1, Tariffs, Fixed I/O, Active
energy, Pulse output/alarm
Bronze Active energy, Reactive energy, Apparent energy, Import/export of energy,
Class 1, Pulse output/alarm
Steel Active energy import, Class 1, Pulse output/alarm
Page 13
Product Overview
2CMA170508R1000
12345678
A43 513-100
3x57,7/100...3x288,7/500
0,25-5(80) A
50 or 60 Hz
1000 imp/kWh
Prog imp kWh
-40°C to 85°C
2010-52
Active energy cl. 1 and B
Reactive energy cl. 2
M11
0122
12345678
1
2
3
4
5
6
7
8
20
9
10
11
12
13
14
15
16
17
18
19
21
22
A43 513-100
9
13
Product label
The meter type information that is reflected on the labels on the meter is shown
in the picture below:
23
10
Product label
information
The information on the product label is explained in the table below:
Item Description
1 Import/export of energy
2 3-element metering
3 2-element metering
4 1-element metering
5LED
6 Pulse output
7 Protection class II
8 Declaration of product safety
9 Type designation
10 Serial number
11 Accuracy active energy
Page 14
Product Overview
14
Item Description
12 Accuracy reactive energy
13 Voltage
14 Current
15 Frequency
16 LED pulse frequency
17 Pulse frequency
18 Temperature range
19 Date of manufacture (year and week)
20 ABB ID
21 Notified body
22 MID and year of verification
23 Caution, refer to accompanying document
Page 15
Chapter 2: Installation
15
Installation
Overview
In this chapter
This chapter describes how to mount the A41/A42 meters and how to connect
them to an electricity network. The chapter also contains information about how
to perform a basic configuration of the meter.
Information about how to connect I/O and communication options is also included in this chapter.
The following topics are covered in this chapter:
2.1 Mounting the Meter .............................................................................. 16
2.2 Environmental Considerations ............................................................. 18
2.3 Installing the Meter .............................................................................. 19
2.3.1 Configuring the meter ................................................................ 20
2.4 Wiring Diagrams .................................................................................. 21
2.4.1 Direct connected meters ............................................................ 21
2.4.2 Transformer connected meters without voltage transformer ..... 21
2.4.3 Transformer connected meters with voltage transformer .......... 22
2.4.4 Inputs/outputs ............................................................................ 22
2.4.5 Communication .......................................................................... 23
Page 16
Installation
16
2.1 Mounting the Meter
General
DIN-rail mounted
DIN-rail
This section describes different ways to mount the A41/A42 meters. For some
methods of mounting additional accessories are needed. For further information
about accessories, refer to the Main Catalog (2CMC480001C0201).
The A41/A42 meters are intended to be mounted on a DIN-rail (DIN 50022). If
this method of mounting is used no extra accessories are needed and the meter is
fastened by snapping the DIN-rail lock onto the rail.
The following picture shows a DIN-rail.
Wall mounted
The recommended way to mount the meter on a wall is to mount a separate DINrail on the wall and then mount the meter on the rail.
Page 17
Installation
17
Flush mounted
Flush-mount kit
To flush-mount the meter a flush-mount kit should be used.
The following picture shows a flush-mount kit.
Page 18
Installation
18
2.2 Environmental Considerations
Ingress protection
To comply with the protection requirements the product must be mounted in protection class IP 51 enclosures, or better, according to IEC 60259.
Mechanical environment
In accordance with the Measuring Directive (2014/32/UE), the product complies
with M2, which means that it can be operated in “...locations with significant or
high levels of vibration and shock, e.g. transmitted from machines and passing
vehicles in the vicinity or adjacent to heavy machines, conveyor belts, etc.”
Electromagnetic environment
Climatic environment
In accordance with the Measuring Directive (2014/32/UE), the product complies
with E2, which means that it can be operated “...in locations with electromagnetic
disturbances corresponding to those likely to be found in other industrial buildings.”
In order to work properly the product should not be operated outside the specified
temperature range of -40°C - +70°C.
In order to work properly the product should not exposed to humidity exceeding
the specified 75% yearly average, 95% on 30 days/year.
Page 19
2.3 Installing the Meter
19
Warning – Electrical equipment should only be installed, accessed, serviced and
E
E
E
maintained by qualified electrical personnel.
Working with high voltage is potentially lethal. Persons subjected to high voltage may
suffer cardiac arrest, burn injuries, or other severe injuries. To avoid such injuries,
make sure to disconnect the power supply before you start the installation.
Warning – For safety reasons it is recommended that the equipment is installed in a
way that makes it impossible to reach or touch the terminal blocks by accident.
The best way to make a safe installation is to install the unit in an enclosure. Further,
access to the equipment should be limited through use of lock and key, controlled by
qualified electrical personnel.
Warning – The meters must always be protected by fuses on the incoming side.
In order to allow for maintenance of transformer rated meters, it is recommended that
there should be a short circuiting device installed near the meter. Alternatively a CT
with short circuiting terminals is used to short circuit the secondary current during
maintenance. The reason for short circuiting the secondary current during maintenance is that a very high voltage will be induced across the terminals if current is
flowing through the CT primary and any secondary terminal is disconnected. This high
voltage can be potentially lethal and can damage the CT or other equipment.
Installation
Utilization category
IEC 62052-31
Installation
requirements
Install the meter
A41: Utilization Category UC2
A42: Utilization Category UC1
Meters with wireless communication should not be installed closer than 20 cm
from people.
Follow the steps in the table below to install and verify the installation of the
meter:
Step Action
1 Switch off the mains power.
2 Place the meter on the DIN rail and make sure it snaps onto it.
3 Strip the cable insulation to the length that is indicated on the meter.
4 Connect the cables according to the wiring diagram that is printed on the meter
and tighten the screws (3.0 Nm for direct connected meters and 1.5 Nm for
transformer connected meters).
5 Install the circuit protection. See table 2:1 below for the correct fuse.
6 If inputs/outputs are used, connect the cables according to the wiring diagram
that is printed on the meter and tighten the screws (0.25 Nm). Then connect to
an external power supply (max 240V).
7 If communication is used, connect the cables according to the wiring diagram
that is printed on the meter and tighten the screws (0.25 Nm).
Verify the installation
Page 20
Installation
20
Step Action
8 Check that the meter is connected to the specified voltage and that voltage
phase connections and the neutral (if used) are connected to the correct terminals.
9 For a transformer connected meter, check that the current direction of the pri-
mary and secondary current of the external transformer is correct. Also check
that the transformer are connected to the correct meter terminals.
10 Switch on the power. If a warning symbol is displayed, refer to the error codes
in Troubleshooting.
11 Under the menu item "Instantaneous Values" on the meter, check that the volt-
age, current, power and power factor are reasonable and that the power direction is what to be expected (the total power should be positive for a load that
consumes energy). When doing the check the meter should be connected to
the intended load, with a current above zero to make the check as complete as
possible.
Circuit protection
Use the information in this table to select the correct fuse for the circuit protection.
Tabelle : 2 : 1
Meter type Max circuit protection
Direct connected 80 A MCB, C characteristic or 80 A fuse type gL-gG
Transformer connected 10 A MCB, B characteristic or Diazed, fast.
2.3.1 Configuring the meter
Default settings
Default settings
For information about how to change the default settings of the meter, refer to the
chapter called Meter Settings.
The following table lists the default settings of the meter that normally need to be
changed. Check the settings of the meter to see if they need to be reconfigured.
Parameter Direct connected meters Transformer connected meters
Clock --- ---
Ratios VT --- 1
Ratios CT --- 1
Pulse frequency 100 impulses / kWh (kvarh) 10 impulses / kWh (kvarh)
Pulse length 100 ms 100 ms
Page 21
2.4 Wiring Diagrams
1
3
L
N
6
4
S1 S2
P1
P2
12
3
5
L
N
P1
21
Installation
General
This section describes how to connect the different types of meters to an electricity network. The terminal numbers in the wiring diagrams listed below correspond to the marking on the terminal block of the meter.
2.4.1 Direct connected meters
2-wire connection
The following diagram shows a 2-wire connection of a direct connected 1-phase
meter:
2.4.2 Transformer connected meters without voltage transformer
2-wire connection
The following diagram shows a 2-wire connection of a transformer connected 3phase meter:
Page 22
Installation
S1 S2
P1
P2
12
3
5
L
N
P1
C
Inp1 Inp2
Out1
Out2
13 15 16
17
18
C
I/O1 I/O2 I/O3 I/O4
13 15 16
17
18
22
2.4.3 Transformer connected meters with voltage transformer
2-wire connection
The following diagram shows a 2-wire connection of a transformer connected 3phase meter with voltage transformers:
2.4.4 Inputs/outputs
2 outputs, 2
inputs
4 configurable
inputs/outputs
Page 23
1 output
C
Out1
13
15
NC
NC
NC
RS485
3637
35
A
BC
M-Bus
3637
23
2.4.5 Communication
RS-485
Installation
M-Bus
Page 24
Installation
24
Page 25
Chapter 3: User Interface
25
User Interface
Overview
In this chapter
This chapter describes the different display views and the menu structure.
The following topics are covered in this chapter:
3.1 Display ................................................................................................. 26
Page 26
User Interface
ACT. NRG. IMP. TOT 1/20
1
26
3.1 Display
General
Default menu
Energy values
The display contains two main views, the Default menu and the Main menu. Use
the Exit button
E to toggle between the views. In both views a number status
icons are displayed in the upper part of the display. These icons are explained in
table 3:1 below. In the same manner the bottom part of the display has an explanatory text to describe what is shown or highlighted at the moment.
The following image shows an example of the layout of the Default menu:
The following table explains the content of the 25 available pages in the Default
menu:
Page Unit Text on display Explaining text
1/25 kWh ACT.NRG.IMP.TOT Measures the total
imported active energy.
2/25 kWh ACT.NRG.EXP.TOT Measures the total
exported active energy.
3/25 kWh ACT.NRG.NET.TOT Measures the total
net active energy.
4/25 kvarh REACT.NRG.IMP.TOT Measures the total
imported reactive energy.
5/25 kvarh REACT.NRG.EXP.TOT Measures the total
exported reactive energy
6/25 kvarh REACT.NRG.NET.TOT Measures the total
net reactive energy
7/25 kVAh APP.NRG.IMP.TOT Measures the total
imported apparent
energy
8/25 kVAh APP.NRG.EXP.TOT Measures the total
exported apparent
energy
Page 27
User Interface
27
Page Unit Text on display Explaining text
9/20 kVAh APP.NRG.NET.TOT Measures the total
net apparent energy
10/25 kWh ACT.NRG.IMP.TAR1 Measures the im-
ported active energy
for tariff 1
11/25 kWh ACT.NRG.IMP.TAR2 Measures the im-
ported active energy
for tariff 2
12/25 kWh ACT.NRG.IMP.TAR3 Measures the im-
ported active energy
for tariff 3
13/25 kWh ACT.NRG.IMP.TAR4 Measures the im-
ported active energy
for tariff 4
14/25 kWh ACT.NRG.EXP.TAR1 Measures the ex-
ported active energy
for tariff 1
15/25 kWh ACT.NRG.EXP.TAR2 Measures the ex-
ported active energy
for tariff 2
16/25 kWh ACT.NRG.EXP.TAR3 Measures the ex-
ported active energy
for tariff 3
17/25 kWh ACT.NRG.EXP.TAR4 Measures the ex-
ported active energy
for tariff 4
18/25 kvarh REACT.NRG.IMP.TAR1 Measures the im-
ported reactive energy for tariff 1
19/25 kvarh REACT.NRG.IMP.TAR2 Measures the im-
ported reactive energy for tariff 2
20/25 kvarh REACT.NRG.IMP.TAR3 Measures the im-
ported reactive energy for tariff 3
21/25 kvarh REACT.NRG.IMP.TAR4 Measures the im-
ported reactive energy for tariff 4
22/25 kvarh REACT.NRG.EXP.TAR1 Measures the ex-
ported reactive energy for tariff 1
23/25 kvarh REACT.NRG.EXP.TAR2 Measures the ex-
ported reactive energy for tariff 2
24/25 kvarh REACT.NRG.EXP.TAR3 Measures the ex-
ported reactive energy for tariff 3
25/25 kvarh REACT.NRG.EXP.TAR4 Measures the ex-
ported reactive energy for tariff 4
Page 28
User Interface
ENERGY REGISTERS
1
28
Status Icons
Main menu
The status icons that can be seen the display are explained in the following table.
Table: 3:1
Icon Indication
Active quadrant
Communication is in progress. The meter is either sending
or receiving information
Rotates when metering in progress, that is when the phase
current is above the starting current
Arrows indicate direction of current. Arrow left = export, arrow right = import. A digit without arrow indicates that the
current is below the starting current
Active tariff
Error, warning, note
Transformer ratio (only on transformer rated meters)
The following image shows an example of the layout of the main menu:
Main menu icons
Depending on the meter type all or a subset of the following icons may be available in the display:
Icon Explanation
Energy registers
Instantaneous values
Stored values
Harmonics
I/O
Page 29
Icon Explanation
29
Status
Settings
User Interface
Main menu
structure
Active Energy Import Active Power Previous Values THD Voltage I/O 1 System Log Clock
Active Energy Export Reactive Power Load Profiles Harmonics Volt-
Active Energy Net Apparent Power Demand THD Current I/O 3 Net Quality
Reactive Energy Import
Reactive Energy Export
Reactive Energy Net Current Settings Log Alarm
Apparent Energy Import
Apparent Energy Export
Apparent Energy Net Phase Angle
Active Energy Import
Tariff
Active Energy Export
Tariff
Reactive Energy Import Tariff
Reactive Energy Export Tariff
Resettable Active Energy Import Total
Resettable Active Energy Export Total
Resettable Reactive
Energy Import Total
Resettable Reactive
Energy Export Total
The following table describes the main menu structure and its content. Depending
on meter type, all or a subset of the items can be present.
I/O 2 Event Log Ratios
age
Wires
Log
Phase Voltage Harmonics Cur-
rent
Main Voltage Audit Log I/O
frequency About Currency/CO
Power Factor RS-485
Power
Phase Angle Voltage
Phase Angle Current
Current Quadrant Pulse LED
I/O 4 System Sta-
tus
Pulse Output
IR Side
Wireless
Upgrade Consent
Tariff
Previous Values
Load profiles
Demand
Resettable registers
2
Page 30
User Interface
30
Currency
CO
2
Page 31
Chapter 4: Meter Settings
31
Meter Settings
Overview
In this chapter
This chapter gives an overview of the meter settings and configuration options.
The following topics are covered in this chapter:
4.1 Settings and Configurations ................................................................ 32
4.1.1 Setting Date ............................................................................... 32
4.1.2 Setting Time ............................................................................... 33
4.1.3 Setting Ratios ............................................................................. 33
4.1.4 Setting Pulse Output .................................................................. 33
4.1.5 Setting I/O .................................................................................. 34
4.1.6 Setting Alarm ............................................................................. 35
4.1.7 Setting Currency/CO2 ................................................................ 36
4.1.8 Setting M-Bus ............................................................................ 36
4.1.9 Setting RS-485 ........................................................................... 37
4.1.10 Setting IR Side .......................................................................... 37
4.1.11 Setting Upgrade Consent ......................................................... 39
4.1.12 Setting Pulse LED .................................................................... 39
4.1.13 Setting Tariff ............................................................................. 39
4.1.14 Setting Previous Values ........................................................... 40
4.1.15 Setting Load Profile .................................................................. 40
4.1.16 Setting Demand ........................................................................ 41
4.1.17 Resetting Resettable Registers ................................................ 41
Page 32
Meter Settings
32
4.1 Settings and Configurations
Configurable
functions
Depending on the meter type, all or a subset of the following functions can be
configured:
•Clock
• Ratios
•Wires
• Pulse output (Pul.Out.) on display
•I/O
•Alarm
• Currency/CO
•M-Bus
•RS-485
•IR Side
• Wireless (W-less on display)
• Upgrade Consent (Upgr.Cons) on display
• Pulse LED (Puls.LED) on display
•Tariff
• Previous Values (Prev. Val. on display)
• Load profile (Load Pro on display)
• Demand
• Resettable registers (Rst.Rg on display)
(Curr/CO2) on display
2
Setting a value
When setting a value, the
U buttons are used to change the options that can be set, such as on or off. If the
set-option involves setting a number, for example a alarm limit, the
used to increase a digit, and the D button is used to decrease a digit. The O
button is used to toggle between digits.The option/digit that is active for setting is
marked with a underscore. When the underscore on the last option has dissapeared, the setting has been performed.
4.1.1 Setting Date
To set the date, perform the following steps:
S button is used to activate the set-option. The D and
1. Choose the Settings icon in the main menu, press
2. Choose “Clock”, press
3. The display will now show the date.
4. Set the date.
O.
U button is
O.
Page 33
4.1.2 Setting Time
33
To set the time, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “Clock”, press
3. The display will now show the date. Press
4. Set the time.
4.1.3 Setting Ratios
To set the ratios, perform the following steps:
1. Choose the Settings icon in the main menu, press O.
2. Choose “Ratios”, press
3. The display will show the quantity Current (CT on the display) and the
4. Press
Table: 4:1
Option Interval
Transformer Current (CT) 1-9999/1-9
Transformer Voltage (VT) 1-999999/1-999
Meter Settings
O.
O.
D to get to the time-menu.
O.
ratio. To change the ratio, press S. See table 4:1 for interval.
D. The display will show the quantity Voltage (VT on the display)
and the ratio. To change the ratio, press
S. See table 4:1 for interval.
4.1.4 Setting Pulse Output
To set the pulse output, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “Pulse out” (Pul.out on the display), press
The display will show what type of energy is measured on pulse output 1.
Depending on meter type, the available choices are:
Act.Nrg.Imp on the display Active energy imported
Act.Nrg.Exp on the display Active energy exported
React.Nrg.Imp on the display Reactive energy imported
React.Nrg.Exp on the display Reactive energy exported
Inactive on the display Inactive
3. Set the energy type.
4. Press
5. Press D once to get to the next menu. The display will show the pulse
6. Press D once to get to the next menu. The display will show the setting for
D once to get to the next menu. The display will show the frequency.
The intervall that can be set is 0-999999 imp/kWh or 0-999999 imp/MWh.
Set the frequency and quantity.
length in milliseconds. The intervall for the pulse length is from 10 to
990ms. Set the pulse length.
pulse output 1. Depending on the meter type, the available choices are:
O.
O.
Page 34
Meter Settings
34
N
4.1.5 Setting I/O
4 configurable I/Os 4 static I/Os 1 static I/O
No output No output No output
Out 1 Out 1 Out 1
Out 2 Out 2 -
Out 3 - -
Out 4 - -
Note – If choosing an I/O that is not pulse output configured, the option is set to “no
output” when pressing the
O button.
7. The first pulse output is now fully configured. Depending on the meter
type, up to four pulse outputs can be set. If your meter supports multiple
pulse outputs, use D to toggle down to the remaining pulse outputs and set
them the same way as pulse output 1.
To set the I/O, perform the following steps:
1. Choose the Settings icon in the main menu, press O.
2. Choose “I/O”, press
3. The display will now show I/O 1. To change I/O, use
O, press the
S button. Depending on the meter type, different choices can
O.
U or D. To set an I/
be made for the I/O, see table 4:2.
Table: 4:2
I/O Available choices
4 configurable I/Os
• Input
•Alarm out
• Communication out (Comm.out on
display)
• Pulse out (Pul.out on display)
• Tariff out
• Always on
• Always off
4 static I/Os
1 static I/O
1. This choice makes it possible to control outputs by time.
2
•Alarm out
• Communication out (Comm.out on display)
• Pulse out (Pul.out on display)
• Tariff out
• Always on
• Always off
•Alarm out
• Communication out (Comm.out on display)
• Pulse out Pul.out on display)
• Always on
• Always off
1
3
Page 35
2. I/O 1 and I/O 2 are set to static output by default.I/O 3 and 4 are set to static output by
35
default and cannot be configured. I/O 3 and I/O 4 are not shown in the display.
3. This choice makes it possible to control fixed I/O outputs by time and thus only
available in gold meters.
4.1.6 Setting Alarm
To set the alarm, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “Alarm”, press
3. The display will show what quantity shall be measured. Depending on the
4. Press
5. Press
6. Press
7. Press
8. Press
9. Press
Meter Settings
O.
O.
meter type, different quantities are available. See table 4:3 and table for
available quantities and interval/units for the different quantities. Set the
desired quantity.
D once to get to the next menu. The display will show what level the
alarm will trigger on. Set the alarm level.
D once to get to the next menu. The display will show the time that
the measured value has to be higher than the limit set in the previous step
in order for the alarm to trigger. Set the time limit.
D once to get to the next menu.The display will show what level the
alarm will cease on.Set the alarm level.
D once to get to the next menu. The display will show the time that
the measured value has to be lower than the limit set in the previous step in
order for the alarm to cease. Set the time limit.
D once to get to the next menu.The display will show if the alarm
will be logged or not. The available values are “on” and “off”. Set logging
to on or off.
D once to get to the next menu. The display will show what output
the alarm is set on (or if no output is set). The available choices are
dependent on meter type, see table 4:4.
N
Note – If choosing an I/O that is not alarm configured, the option will be set to “no
output” when pressing the
10.The first alarm is now fully configured. Depending on the meter type, up
to four alarms can be set. If your meter supports multiple alarms, use
S button.
D and
U to set the remaining alarms the same way as the first alarm was
configured.
Table: 4:3
Alarm alternatives Interval/Unit
Inactive -
Current L1 0.01-99.99 A/kA
Voltage L1 0.1-999.9 V/kV
Harmonic voltage L1 0 - 999 %
Harmonic current L1 0 - 999 %
Active power total 0-9999 W/kW/MW
Page 36
Meter Settings
36
Alarm alternatives Interval/Unit
Reactive power total 0-9999 var/kvar/Mvar
Apparent power total 0-9999 VA/kVA/MVA
Power factor total 0.000-0.999
Table: 4:4
4 configurable I/Os 4 static I/Os 1 static I/O
No output No output No output
Out 1 Out 1 Out 1
Out 2 Out 2
Out 3
Out 4
4.1.7 Setting Currency/CO2
By setting a conversion factor for Currency/CO2, kWh is converted to currency
and/or kg CO2.
To set currency/CO2, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “Currency/CO2” (Curr/CO2 on the display), press
3. The display will show price in currency per unit.
4. Press S to set the the conversion factor and the quantity.
5. Use
6. Press S to set the conversion factor for CO2.
4.1.8 Setting M-Bus
To set the wired M-Bus interface, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “MBus”, press
3. Press
4. Press D once to get to the next menu. The display will show the address.
5. Press
6. Press D once to get to the next menu. The display will show the Send status
7. Press
O.
O.
D to get to the next page. The page will display the CO
kg per kWh.
emissions in
2
O.
O.
D once to get to the next menu. The display will show the baudrate.
See Ta bl e 4: 5 for baudrate options. Set baudrate.
See Ta bl e 4: 5 for address range. Set address.
D once to get to the next menu. The display will show the access
level. See Ta bl e 4: 5 for options. Set the access level.
info. See Tab le 4: 5 for options. Set the send info status.
D once to get to the next menu. The display will show if the
password is to be reset. See Tab le 4: 5 for options. Set the option.
Page 37
4.1.9 Setting RS-485
37
The RS-485 uses the EQ-Bus and the Modbus protocol to communicate. To set
the RS-485 communication depending on protocol, perform the following steps:
Step EQ-Bus Modbus
1
2
3
4 Press
5 Press
6 Press
7 Press
Meter Settings
Choose the Settings icon in the
main menu, press
O.
Choose communication interface. Choose communication inter-
Choose EQ-Bus. Choose Modbus.
D once to get to the next
menu. The display will show the
baudrate. See table Table 4:5 for
baudrate options. Set baudrate.
D once to get to the next
menu. The display will show the
address. See Tab l e 4 :5 for address
range. Set address.
D once to get to the next
menu. The display will show the
Oct. TO. See Table 4:5 for options.
Set Oct. TO
D once to get to the next
menu. The display will show the
Inac. TO. See Table 4:5 for options.
Set Inac. TO
Press D once to get to the next
menu. The display will show if the
password is to be reset. See
Tabl e 4: 5 for options. Set the option.
Choose the Settings icon in the
main menu, press O.
face.
D once to get to the next
Press
menu. The display will show
the baudrate. See Tab l e 4: 5 for
baudrate options. Set baudrate.
D once to get to the next
Press
menu. The display will show
the address. See Table 4:5 for
address range. Set address.
D once to get to the next
Press
menu. The display will show
the Parity. See Tab l e 4 : 5 for options. Set Parity.
4.1.10 Setting IR Side
The IR Side uses the M-Bus and the EQ-Busi protocol to communicate. To set the
IR Side communication depending on protocol, perform the following steps:
Step M-Bus EQ-Bus
1
2
3
4 Press
i. EQ-Bus is a communication protocol designed for internal communication with ABB meters.
The protocol is based on the following IEC standards; 62056-42, 62056-46, 62056-53, 6205661, 62056-62.
Choose the Settings icon in the
main menu, press
Choose IR Side, press
S and choose M-Bus. Press S and choose EQ-Bus.
Press
O.
O. Choose IR Side, press O.
D once to get to the next
menu. The display will show the
baudrate. See Tab le 4: 5 for baudrate options. Set baudrate.
Choose the Settings icon in the
main menu, press O.
D once to get to the next
Press
menu. The display will show the
baudrate. See Tab l e 4 :5 for baudrate
options. Set baudrate.
Page 38
Meter Settings
38
Step M-Bus EQ-Bus
5 Press
menu. The display will show the
address. See Table 4:5 for address
range. Set address.
6 Press
menu. The display will show the
access level. See Tab l e 4 : 5 for options. Set the access level.
7 Press
menu. The display will show the
Send status info. See Table 4:5 for
options. Set the send info status.
Press
menu. The display will show if the
password is to be reset. See
Table 4:5 for options. Set the op-
tion.
Press
menu. The display will show the
upgrade mode. See Tab le 4: 5 for
options. Set the upgrade mode.
D once to get to the next
D once to get to the next
D once to get to the next
D once to get to the next
D once to get to the next
D once to get to the next
Press
menu. The display will show the
address. See Tab l e 4 : 5 for address
range. Set address.
D once to get to the next
Press
menu. The display will show the
Oct. TO. See Table 4:5 for options.
Set Oct. TO.
D once to get to the next
Press
menu. The display will show the
Inac. TO. See Tab l e 4 : 5 for options.
Set Inac. TO.
D once to get to the next
Press
menu. The display will show password reset option. Set if the password shall be reset or not.
Protocol details
Protocol Access
level
EQ-Bus
(when
used
through
RS-485)
Modbus
(when
used
through
RS-485
- - - Yes, No - 1200,
---- None,
The following table shows the intervals and options for the different protocols:
Table: 4:5
Upgrade
mode
Send
Status
Info
Reset
password
Parity Baudrate Address Inter
octet
timeout
(ms)
16-16381 20-6000 0-2000
2400,
4800,
9600,
19200,
38400,
57600,
115200,
125000,
230400,
250000,
460800
Odd,
Even
1200,
2400,
4800,
9600,
19200,
38400,
57600,
115200
1-247 - -
Inactivity
timeout
(ms)
Page 39
Meter Settings
39
Protocol Access
level
M-Bus
(when
used
through IRSide
EQ-Bus
(when
used
through IRSide)
Open,
Password,
Closed
- - - Yes, No - 1200,
Upgrade
mode
Active,
Not Active
Send
Status
Info
Always,
Never,
When
not OK
Reset
password
Yes, No - 2400,
4.1.11 Setting Upgrade Consent
Upgrade Consent can be set to Allowed or Not Allowed. Setting it to Allowed
means you agree to updates of the meter. Setting it to Not Allowed means no
upgrades will take place.
Parity Baudrate Address Inter
octet
timeout
(ms)
1-250 - 4800,
9600,
19200,
38400
2400,
4800,
9600,
19200,
38400,
57600,
115200,
125000,
230400
Inactivity
timeout
(ms)
To set Upgrade Consent, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “Upgrade Consent” (Upgr.Cons on the display), press
3. Press
4.1.12 Setting Pulse LED
To set pulse LED, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “Pulse LED” (Puls.LED on the display), press
3. Press
indicate on.
4.1.13 Setting Tariff
The tariff source can be set to input, clock or communication. To set the tariffs,
perform the following steps:
Step Input Clock Communication
1 Choose the Settings icon in
the main menu, press
2 Choose “Tariff”, press O. Choose “Tariff”, press O. Choose “Tariff”,
O.
O.
S to set Upgrade Consent.
O.
O.
S to set the type of energy, active or reactive, that the LED shall
Choose the Settings icon in
O.
the main menu, press O.
Choose the Settings icon in the
main menu, press
O.
press
O.
Page 40
Meter Settings
40
Step Input Clock Communication
3 Press
4 Use D to toggle to the first
5 - Set the desired tariffs with
S and choose Input. Press S and choose Clock.
configuration. Four configurations are available. Set
the tariff that shall be active
for each configuration.
4.1.14 Setting Previous Values
To set set the previous values, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “Previous Values” (Prev.Val. on the display), press
3. Perform the setting. The options are day, week and month.
4. If setting week, use
5. Set what week-day the snapshot of the values will be taken.
4.1.15 Setting Load Profile
If the display says
“Config found
No reset”
then reset the configuration
by pressing
“Reset”
Press
page.
start-time and if the tariff is to
be used or not. Up to eight
tariff switch times can be set,
four for weekdays and four
for weekends. Set at least
one tariff for weekdays
(Mon-Fri) and one for weekends (Sat-Sun) even if the
values are the same
S and choosing
D to get to the next
D to go to the next step.
Press
choose Comm.
The tariff source is
now set for communication.
-
O.
O.
S and
To set the load profile, perform the following steps:
1. Choose the Settings icon in the main menu, press O.
2. Choose “Load Profiles” (Load Pro on the display), press
O.
3. The first page will show the interval for the quantity active energy imported
(Act.Imp.Tot on the display). Up to eight channels (pages) are available to
configure, see table below.
Page Quantity On display Predefined
value
1/8 Active Energy Imported total Act.Imp.Tot 1 hours
2/8 Active Energy Exported Total Act.Exp.Tot 1 hours
3/8 Reactive Energy Imported Total React.Imp.Tot 1 hours
4/8 Reactive Energy Exported Total React.Exp.Tot 1 hours
5/8 Input Counter 1 Inp.Ctr 1 1 hours
6/8 Input Counter 2 Inp.Ctr 2 1 hours
Page 41
Page Quantity On display Predefined
41
7/8 Input Counter 3 Inp.Ctr 3 1 hours
8/8 Input Counter 4 Inp.Ctr 4 1 hours
4. Configure the desired channels.
When a configuration has been made, a reset may be required in order to perform
a new configuration. To reset the intervals, toggle down to the reset page and
perform a reset the same way as performing a setting.
4.1.16 Setting Demand
The demand function enables measuring of up to 50 values (channels). Step 1-6
are general for the function and step 7-9 are specific for each channel.
To set the demand, perform the following steps:
1. Choose the Settings icon in the main menu, press
2. Choose “Demand” (Demand on the display), press
3. Set the period. The available choices are day, week and month. If choosing
day, the starting point will be now and the ending point will be 00:00. If
choosing month, the starting point will be now and the ending point will be
the first of next month at 00:00. If choosing week, the starting point will be
now and the ending point will be the set day at 00:00. If choosing week,
press
4. Set the interval that shall be measured. Press
5. Set the subinterval that shall be measured. Press
6. Set if the previous settings shall be reset. Press
7. Set the quantity that shall be measured. Press
8. Set the demand type. Press
9. The demand level will be set automatically.
Meter Settings
value
O.
O.
D to get to the page where the day is set. Press D.
D to continue.
D to continue.
D to continue.
D to continue.
D to continue.
The first channel is now set. To set the next channel, repeat step 3-9. Up to 50
channels can be set.
4.1.17 Resetting Resettable Registers
To reset registers, perform the following steps:
1. Choose the Settings icon in the main menu, press O.
2. Choose “Resettable registers” (Rst.Reg on the display), press
3. The display will show the different registers to reset. Depending on the
meter type, the available choices are:
Register On the display
Active Energy Imported Total Act.Imp
Active Energy Exported Total Act.Exp
Reactive Energy Imported Total Rea.Imp
Reactive Energy Exported Total Rea.Exp
O.
Page 42
Meter Settings
42
Register On the display
Reset all All
4. Toggle through the pages and reset the desired registers.
Page 43
Chapter 5: Technical Description
43
Technical Description
Overview
In this chapter
This chapter contains technical descriptions of the meter functions. Depending of
the meter type, the meter may contain all or a subset of the functions described in
this chapter.
The following topics are covered in this chapter:
5.1 Energy Values ..................................................................................... 44
5.2 Instrumentation .................................................................................... 46
5.3 Harmonics ........................................................................................... 48
5.3.1 Measuring Harmonics ................................................................ 50
5.4 Alarm ................................................................................................... 52
5.5 Inputs and Outputs .............................................................................. 53
5.5.1 Tariff Inputs ................................................................................ 53
5.5.2 Pulse Outputs ............................................................................ 54
5.6 Internal Clock ....................................................................................... 56
5.7 Logs ..................................................................................................... 57
5.7.1 System Log ................................................................................ 57
5.7.2 Event Log ................................................................................... 58
5.7.3 Net Quality Log .......................................................................... 59
5.7.4 Audit Log .................................................................................... 59
5.7.5 Settings Log ............................................................................... 60
5.7.6 Event codes ............................................................................... 60
5.8 Demand ............................................................................................... 62
5.9 Previous Values ................................................................................... 64
5.10 Load Profile ......................................................................................... 66
Page 44
Technical Description
44
5.1 Energy Values
General
The energy values are stored in energy registers. The different energy registers
can be divided into:
• Registers containing active, reactive or apparent energy
• Registers containing different tariffs or total sum of all tariffs
• Registers containing energy per phase or total sum of all phases
• Resettable registers (possible to set to zero via buttons or communication
command)
• Registers containing momentary or historical value
The energy values can be read via communication or directly in the display with
the help of the buttons.
Primary value
In transformer connected meters with external current transformers, and sometimes also external voltage transformers, the total transformer ratio is taken into
account for all energy registers, that is all energy registers store primary values.
Presentation of register values
In direct connected meters the energy is usually displayed with 7 digits in kWh/
kvarh/KVAh with two decimals and displays one decimal less at overflow, that is
it changes to one decimal at 100000.0 kWh and to no decimals at 1000000 kWh.
In transformer connected meters where primary values are displayed, the energy
values can be rather big when the total transformer ratio is big. Normally the
meter automatically adapts the unit and number of decimals displayed to the
value.
In case the energy is displayed with fixed units and number of decimals the energy
will "roll over" to zeros when the energy is incremented if all nines are displayed.
The meter can however contain more digits internally, which can be read out via
communication if the meter is equipped with a communication interface. See the
example below where the value 2483756 is displayed, while the internal register
contains 192483756.6.
Page 45
Technical Description
ACT. NRG. IMP. TOT 1/20
1
2483756
.6
19
45
Image
The following picture shows a display with fixed unit and numbers of decimals:
Page 46
Technical Description
46
5.2 Instrumentation
Instrumentation
functions
The following table shows the complete instrumentation functions of the A41/
A42 meters. Depending on the meter type all or a subset of the following functions are available.
Instrumentation A41 A42
Active power X X
Reactive power X X
Apparent power X X
Voltage X X
Current X X
Frequency X X
Power factor X X
Phase angle power X X
Phase angle voltage X X
Phase angle current X X
Current quadrant X X
THD voltage X X
Harmonics voltage (number 2-16) X X
THD current X X
Harmonics current (number 2-16) X X
Accuracy
All instrumentation data accuracy is defined within the voltage range 20 % of the
stated nominal voltage and within the current range 5 % of the base current to the
maximum current.
The accuracy of all instrumentation data except the frequency and voltage and
current phase-angles is the same as the stated energy metering accuracy. The accuracy for the voltage and current phase-angles is 2 degrees and 0.5 % for the
frequency.
Page 47
5.3 Harmonics
47
Technical Description
General
The presence of harmonics in voltages and currents may cause a number of unwanted problems. This chapter describes the origin of harmonics, how the negative effects of harmonics can be eliminated and how harmonics is measured.
The harmonics data can be read via communication or directly in the display with
the help of the buttons.
Generation of harmonics
Generators in the power system produce a nearly pure sinusoidal voltage with a
frequency near the stated system frequency, normally 50 or 60 Hz. Linear loads,
consisting of pure resistors, capacitors and inductors, draw a pure sinusoidal current if the voltage over the load is pure sinusoidal.
A non-linear load, however, draws non-sinusoidal current resulting in a current
consisting of several frequencies. One example of a common non-linear load are
power supplies in electronic equipment which normally contains rectifier diodes
which rectifies the incoming voltage and charges a capacitor. The power supply
only draws current at the top of the sine wave when the rectified voltage exceeds
the voltage over the capacitor. Another example of a non linear load is a thyristor
controlled load, where the current normally is turned on at the voltage zero crossing and turned off sometimes during the sine wave.
These currents are all non-sinusoidal and can be divided into a fundamental part,
which is the same as the mains frequency, and high frequency parts, that is harmonics, which have frequency that are integral multiples of the mains frequency.
Harmonics in the current will in turn cause harmonics in the voltage since the
mains wires and the generator have an impedance causing a voltage drop that is
proportional to the current. It should also be pointed out that if there is harmonics
in the voltage, also a linear load will cause harmonics in the current, that have the
same magnitude as the voltage harmonics. However, the origin of harmonics in
the voltage are non-linear loads.
Page 48
Technical Description
48
Negative effects of harmonics
The presence of harmonics in voltages and currents can cause a number of problems:
• Increased cable losses. At higher frequencies skin and proximity effects
increases, resulting in increased losses.
• High current in the neutral wire.
• Motor efficiency and product lifetime will decrease if the voltage contain
harmonics.
• In transformers, harmonics will cause higher wire, hysteresis and eddy
losses, which could result in efficiency losses up to 50%.
• Voltage harmonic can give higher peak voltages (higher crest factor),
causing overvoltage protection devices to trip and in worst case destruction
of devices.
• Voltage harmonic can result in decreased product lifetime and in worst case
destruction of capacitor banks (used for power factor correction).
• Voltage harmonic can cause malfunction of devices controlled by the
voltage, often zero crossings (voltage harmonics can give extra zero
crossings).
• Voltage harmonics can produce disturbances within devices having its
power supply connected to the mains causing problems.
Eliminating negative effects of harmonics
Because of the negative effects of harmonics it may be necessary to take actions
to decrease the problems. This can be either done by decreasing the harmonics,
and/or taking actions that decrease the negative effects of the harmonics.
Suggested actions
• Increase the size of the neutral conductor if the current is abnormally high
due to harmonics.
• Install appropriate filters to isolate loads with high current harmonics.
• Install filters to protect to protect loads that are sensitive to voltage
harmonics.
• Oversize generators, motors and transformers to better cope with
harmonics.
• Substitute equipment for equipment that generates less current harmonics
and is less sensitive to voltage harmonics.
Page 49
5.3.1 Measuring Harmonics
49
Technical Description
General
Measuring
To detect and eliminate the problems related to presence of harmonics, it’s generally necessary to measure the harmonics. Meters that have harmonic measurement enabled measure harmonics on all voltages and currents up to the 16th harmonic and calculates the total harmonic distortion (THD).
Measurement of the harmonics is done sequentially, one at a time, and approximately two harmonic numbers are measured every second.
Each harmonic is calculated according to:
and the total current harmonic distortion for the harmonics measured is calculated
according to:
where I
is the fundamental current and In is the current for harmonics with num-
f
ber n.
At each measurement the harmonic is set to 0 if the rms value of the current is
below a certain lower limit (normally 5% of the basic current).
Folding distortion
Frequency
measurement
Since the meter have limited sampling frequency, presence of harmonics over the
20:th harmonic (1 kHz at 50 Hz line frequency) will result in folding distortion
and can affect the harmonic measurement accuracy negatively.
Due to the possible presence of folding distortion and the fact that harmonics is
measured sequentially, one at a time, it is recommended that the harmonic measurement results of the meter is used as a tool to detect presence of harmonics and
not as an exact instrument to get exact results.
Measuring harmonics require a valid frequency measurement. If the frequency
measurement is uncertain, the harmonic measurement will not be performed. To
get a valid measurement the meter uses a retry scheme. If the retry scheme does
not give a valid measurement the harmonic will be marked as "not available".
Page 50
Technical Description
50
Accuracy
The accuracy of the current harmonics varies with the harmonic amplitude and is
valid only provided there is no harmonics above the 16th harmonic.
Harmonic
Number
2 ± 0.5%* ± 1.0 ± 2% ± 4% ± 6%
3 ± 0.7%* ± 1.5% ± 3% ± 6% ± 9%
4 ± 1.0% ± 2.0% ± 4% ± 8% ± 12%
5 ± 1.2% ± 2.5% ± 5% ± 10% ± 15%
6 ± 1.5% ± 3.0% ± 6% ± 12% ± 18%
7 ±1.7% ± 3.5% ± 7% ± 14% ± 21%
8 ± 2.0% ± 4.0% ± 8% ± 16% ± 24%
9 ± 2.5% ± 5.0% ± 10% ± 20% ± 30%
10 ± 2.5% ± 5.0% ± 10% ± 20% ± 30%
11 ± 2.5% ± 5.0% ± 10% ± 20% ± 30%
12 ± 2.5% ± 5.0% ± 10% ± 20% ± 30%
13 ± 2.5% ± 5.0% ± 10% ± 20% ± 30%
14 ± 2.5% ± 5.0% ± 10% ± 20% ± 30%
15 ± 2.5% ± 5.0% ± 10% ± 20% ± 30%
16 ± 2.5% ± 5.0% ± 10% ± 20% ± 30%
1% <
Distortion ≤
5%
5% <
Distortion ≤
10%
10% <
Distortion ≤
20%
20% <
Distortion ≤
50%
50% <
Distortion ≤
100%
* For distortion levels below 1% the absolute uncertainty is ± 0.5%.
Page 51
5.4 Alarm
51
Technical Description
General
Quantities
Functional
description
The purpose of the alarm function is to enable monitoring of quantities in the
meter. Monitoring can be set to high or low level detection. High level detection
gives an alarm when the level of a quantity goes above the set level. Low level
detection gives an alarm when the value goes below the set level.
It is possible to configure 25 alarms. Configuration can be done via communication or with the buttons directly on the meter.
Depending on the meter type all or a subset of the following quantities can be
monitored:
Voltage Apparent power
Current Power factor
Active power Harmonic voltage
Reactive power Harmonic current
When the value of the monitored quantity passes the activation level, and remains
there for a period of time equal or longer than the specified time delay, the alarm
is activated. In the same way, the alarm is deactivated when the value passes the
deactivation level and remains there for a time equal or longer than the specified
time delay.
If the activation level is higher than the deactivation level, the alarm is activated
when the value of the monitored quantity is higher than the activation level.
If the activation level is lower than the deactivation level, the alarm is activated
when the vale of the monitored quantity is lower than the activation level.
Page 52
Technical Description
52
5.5 Inputs and Outputs
General
Inputs/outputs are built with optocouplers and are galvanically isolated from
other meter electronics. They are polarity independent and handle both DC and
AC voltage.
An input that is not connected equals having its voltage off.
The equivalent circuitry of the outputs is an ideal relay in series with a resistor.
Functionality of
inputs
The inputs count pulses, register activity and current status and the data can be
read directly on the meter display or via communication
Register activity can be reset via communication or via the buttons directly on the
meter.
Functionality of
outputs
The outputs can be controlled by communication, alarm or by the internal clock.
5.5.1 Tariff Inputs
Tariff control
On meters with tariff functionality, the tariffs are controlled either via communication, the internal clock or by 1 or 2 tariff inputs.
Tariff control via inputs is done by applying a proper combination of "voltage" or
"no voltage" to the input(s). Each combination of "voltage"/"no voltage" will result in that the meter will register the energy in a particular tariff register.
In combined meters with both active and reactive metering, both quantities are
controlled by the same inputs and the active tariff for active and reactive energy
will always be the same.
Indication of
active tariff
Input coding, meters with 4 tariffs
The active tariff is displayed on the LCD by the text "Tx" in the status field, where
x is the tariff number. The active tariff can also be read via communication.
The coding of the inputs is binary. The following table describes the default coding.
Input 4 Input 3 Tariff
OFF OFF = T1
OFF ON = T2
ON OFF = T3
ON ON = T4
Page 53
Input coding, meters with 2 tariffs
53
The coding of the inputs is binary. The following table describes the default coding.
Input 3 Tariff
OFF = T1
ON = T2
5.5.2 Pulse Outputs
Technical Description
About pulse
outputs
Meters equipped with pulse outputs may have up to 4 outputs.
On the pulse outputs the meter sends out a specified number of pulses (pulse
frequency) per kWh (kvarh for reactive pulse outputs).
The pulse outputs are primary, which means that the pulses are sent out in proportion to the true primary energy, taking current and voltage transformer ratios (CT
and VT ratio) programmed on the meter into account.
For direct connected meters no external transformers are used and the amount of
pulses sent out are in proportion to the energy flowed through the meter.
5.5.2.1 Pulse Frequency and Pulse length
General
Pulse frequency and pulse length can be set via the buttons on the meter or via
communication. If the meter have more than 1 pulse output, all outputs will have
the same pulse frequency and pulse length.
Pulse frequency
The pulse frequency is configurable and can be set to a value between 1-9999
impulses. The value must be an integer. The unit is selectable and may be set to
imp/kWh, imp/Wh or imp/MWh.
Pulse length
Deciding pulse frequency/length
The pulse length can be set to a value between 10-990 ms.
If the power is too high for a certain pulse length and pulse frequency, there is a
risk that the pulses may go into one another. If this happens the meter will emit a
new pulse (relay closed) before the previous one has terminated (relay open) and
the pulse will be missed. In worst case the relay may be closed at all times.
To avoid this problem a calculation should be made to work out the maximum
pulse frequency allowed at a particular site based upon an estimated maximum
power and the meter’s pulse output data.
Page 54
Technical Description
54
Formula
Example 1
Example 2
N
The formula to use for this calculation is:
Max pulse frequency = 1000*3600 / U / I /n / (Ppause + Plength)
where U and I is the estimated maximum element voltage (in volts) and current
(in amperes), n the number of elements (1 - 3). Plength and Ppause are the pulse
length and the required pulse pause (in seconds). A reasonable minimum pulse
length and pulse pause is 30 ms which conforms to the S0 and IEC standard.
Note – U and I have to be the primary values in a transformer connected meter if the
CT and VT for the external transformers are programmed into the meter.
In a direct connected 3-element meter with estimated maximum voltage and current of 250 V and 65 A and pulse length 100 ms and required pulse pause 30 ms,
the maximum allowed pulse frequency will be:
1000 * 3600 / 250 / 65 / 3 / (0.030 + 0.100)) = 568 impulses / kWh (kvarh)
In a transformer connected 3-element meter with estimated maximum voltage and
current of 63 * 100 V = 6300 V (VT ratio 100) and 6 * 50 A = 300 A (CT ratio
50) and pulse width 100 ms and required pulse pause 30 ms the maximum allowed
pulse frequency will be:
1000 * 3600 / 6300 / 300 / 3 / (0.030 + 0.100) = 6.16 impulses / kWh (kvarh)
Page 55
5.6 Internal Clock
55
Technical Description
General
Time and date
Time dependant
functions
Backup of clock
Meter with a built-in clock automatically keeps track of leap year and daylight
savings time (DST). The use of DST is optional.Time is controlled by a quartz
crystal real time clock.
Time and date can be set via communication, or with the buttons directly on the
meter.
• Load profile
• Maximum demand
• Minimum demand
• Previous values
• Event log
• Outputs controlled by time
• Tariff control
In case of power failure a super capacitor backs up the clock for at least 48 hours.
Page 56
Technical Description
56
5.7 Logs
General
The meter contains a total of five different logs:
•System Log
• Event Log
• Net Quality Log
• Audit log
• Settings Log
Log events can be read via communication or directly in the display of the meter.
A maximum of 500 log events can be stored in the System Log, the Event Log
and the Net Quality Log. When the maximum number of events for a log is
reached, the oldest events will be overwritten.
A maximum of 40 log events can be stored in the Audit Log. When the maximum
number of events for this log is reached, no more events can be stored. A new
firmware upgrade attempt will be unsuccessful because no more log events can
be stored.
A maximum of 80 log events can be stored in the Settings Log. When the maximum number of events for this log is reached, no more events can be stored. A
new setting for either CT/VT or number of elements will not be accepted because
no more log events can be stored.
It is possible to delete all entries in the System Log, The Event Log and the Net
Quality Log via communication.
5.7.1 System Log
This log stores events that relate to errors in the meter.
Contents
The following information is stored in an event:
The following events are stored in this log:
• Date and time
• Event Code
• Duration
• Program CRC Error - Error when checking firmware consistency.
• Persistent Storage Error - Data stored in long-term memory is corrupt.
• RTC Circuit Error - Error when trying to read date and time from real-time
clock.
Page 57
5.7.2 Event Log
57
Technical Description
This log stores events that relate to alarms and configuration warnings.
Contents
The following information is stored in an event:
• Date and Time
• Event Code
• Duration
The following events are stored in this log:
• Date Not Set Warning - Date has not been configured for RTC.
• Time Not Set Warning - Time has not been configured for RTC.
• Negative Total Power - Power is measured as negative.
• Alarm Current
• Alarm Active Power
• Alarm Reactive Power
• Alarm Apparent power
• Alarm Power Factor
5.7.3 Net Quality Log
This log stores alarms and information that relates to net quality.
Contents
The following events are stored in this log
• Voltage Missing Warning - Voltage is missing
• Frequency Warning - Net frequency is not stable
• Alarm Voltage
• Alarm Harmonic Voltage
Page 58
Technical Description
58
5.7.4 Audit Log
The Audit Log stores an event after an attempt has been made to upgrade the
firmware.
Contents
The following information is stored in an event:
5.7.5 Settings Log
This log stores an event when the transformer ratio is reconfigured.
Contents
The following information is stored in an event:
• Date and Time
• Firmware version
• Active Energy import
• Active Energy import Tariff 1
• Active Energy import Tariff 2
• Active Energy import Tariff 3
• Active Energy import Tariff 4
• Active Energy Export
• Firmware Upgrade status
• Date and Time
• Firmware version
• Active Energy import
• Active Energy import Tariff 1
• Active Energy import Tariff 2
• Active Energy import Tariff 3
• Active Energy import Tariff 4
• Active Energy Export
•CT-Value
•VT-Value
5.7.6 Event codes
Description
The following table describes the event codes that may ocurr in the System log,
the Event log and the Net quality log:
Event code Event
41 Program CRC error
42 Persistent storage error
53 RTC circuit error
Page 59
Event code Event
59
1000 Voltage Missing Warning
1004 Negative Power Element 1 Warning
1007 Negative Total power Warning
1008 Frequency Warning
1010 Date Not Set Warning
1011 Time Not Set Warning
2013 Alarm 1 active
2014 Alarm 2 active
2015 Alarm 3 active
2016 Alarm 4 active
2017 Alarm 5 active
2018 Alarm 6 active
2019 Alarm 7 active
2020 Alarm 8 active
2021 Alarm 9 active
2022 Alarm 10 active
2023 Alarm 11 active
2024 Alarm 12 active
2025 Alarm 13 active
2026 Alarm 14 active
2027 Alarm 15 active
2028 Alarm 16 active
2029 Alarm 17 active
2030 Alarm 18 active
2031 Alarm 19 active
2032 Alarm 20 active
2033 Alarm 21 active
2034 Alarm 22 active
2035 Alarm 23 active
2036 Alarm 24 active
2037 Alarm 25 active
Technical Description
Page 60
Technical Description
60
5.8 Demand
General
N
Interval length
Storing periods
The demand functionality is used to measure and store the maximum and minimum demands of different quantities in the meter. Time is divided into intervals
of a certain length in which the mean values of a set of selected quantities are
measured.
Demand can be configured via Modbus and EQ-bus communication or via the
buttons on the meter.
Note – Before any demand values can be stored, time/date must be set.
Changing time/ date will store the current period and start a new one.
If a power fail occurs that lasts over the end of an ongoing period, the period will
be stored when the meter powers up again and a new period will start. If date/time
is not set when the meter powers up again, demand will enter a waiting state until
time/date is set.
The interval lengths for demand can be one of the following: 1, 2, 5, 10, 15, 20,
30, 60 minutes.
When the last interval of an ongoing period has finished, the maximum- and/or
minimum values are stored and a new period starts.
The length of a demand period can be a day, a week or a month.
Demand has 50 channels which can be configured individually. Each channel can
store up to 200 periods. A stored period contains the demand value, the date/time
of the period and the date/time of the interval when the demand value was measured. All channels use the same interval, subinterval and period length. Individual channel parameters are type of demand which have the four choices maximum, minimum, maximum sliding or minimum sliding and the number of the
demand with the three choices first, second or third (max/min).
The period/interval date and time is stored as end of period/interval. For instance,
if a period starts 2010.01.01 00:00.00 and ends 2010.01.02 00:00.00, then the
stored period will be 2010.01.02 00:00.00.
If there is no free memory space available, the oldest period will be erased to
make room for the most recent one.
Stored periods can be read via communication or directly on the display.
An ongoing period can be ended and a new one started by sending a “freeze demand” via communication.
It is also possible to erase all stored periods by sending a “Reset Demand” command via communication.
If the time is set backward within an interval the calculation of demand for that
interval is restarted if the channel is configured to store a maximum value (as the
Page 61
Technical Description
61
actual time for that interval will be longer than the interval time which could result
in a too big demand value). For the same reason the calculation of demand for an
interval is restarted if the channel is configured to store a minimum value and the
time is set forward within the interval or into another interval.
Demand values
Sliding demand
Selectable
quantities
Each demand quantity is individually configurable to store up to the three highest
or lowest demand values, where each value use one demand channel configured
to use first, second and third maximum/minimum. If demand is configured to
store only one maximum interval, then only the interval with the maximum peak
will be recorded. If a demand quantity is configured to store three maximum intervals the intervals with the three highest peaks are recorded.
A demand channel can also be configured as maximum sliding demand or minimum sliding demand. A sub-interval time is set which divides the interval into a
circular array with a new mean value calculated at the end of every sub-interval.
The selectable sub-interval times for demand is a subset of the interval times and
evenly divisible with the selected interval time.
Depending on the meter type all or a subset of the following quantities can be
selected.
ACTIVE POWER IMPORT TOTAL REACTIVE POWER IMPORT TARIFF2
REACTIVE POWER IMPORT TOTAL REACTIVE POWER IMPORT TARIFF3
APPARENT POWER IMPORT TOTAL REACTIVE POWER IMPORT TARIFF4
ACTIVE POWER IMPORT TARIFF1 VOLTAGE L1
ACTIVE POWER IMPORT TARIFF2 HARMONIC VOLTAGE L1
ACTIVE POWER IMPORT TARIFF3 CURRENT L1
ACTIVE POWER IMPORT TARIFF4 HARMONIC CURRENT L1
REACTIVE POWER IMPORT TARIFF1 PULSE INPUT COUNTERS
The value is the mean value of the interval. The unit for the pulse input counters
are pulses per hour (for example if 2 pulses were registered in a 15 minute interval
the value for the interval will be 8 pulses per hour).
Page 62
Technical Description
62
5.9 Previous Values
General
N
Storing periods
At the end of a defined period, up to 50 configurable channels, which can contain
energy register values, input counter values and currency/CO2 values, are stored
together with the time/date for the end of the period.
Previous values can be configured via Modbus and EQ-bus communication or via
the buttons on the meter.
Note – Before any previous values can be stored, time/date must be set.
Changing time/date into another period than the pending period will store the
current period and start a new one.
If a power fail occurs that lasts over the end of an ongoing period, the period will
be stored when the meter powers up again and a new period will start. If the meter
have lost time and date/time is not set when the meter powers up again, previous
values will enter a waiting state until time/date is set.
Previous values has 50 channels which can be configured individually via communication. Each channel can store up to 200 periods.
The period length can be a day, a week or a month and can be configured via
Modbus and EQ-bus communication or via the buttons on the meter.
The period date and time is stored as end of period. For instance, if a period starts
2010.01.01 00:00.00 and ends 2010.01.02 00:00.00, then the stored period will be
2010.01.02 00:00.00.
Selectable
quantities
Stored periods can be read via communication or directly on the display.
If there is no free memory space available, the oldest period will be erased to
make room for the most recent one.
It is possible to erase all stored periods by sending a “Reset Previous Values”
command via communication.
Depending on the meter type all or a subset of the following quantities can be
selected.
ACTIV ENERGY IMPORT TOTAL ACTIVE ENERGY EXPORT TARIFF1
ACTIVE ENERGY EXPORT TOTAL ACTIVE ENERGY EXPORT TARIFF2
REACTIVE ENERGY IMPORT TOTAL ACTIVE ENERGY EXPORT TARIFF3
REACTIVE ENERGY EXPORT TOTAL ACTIVE ENERGY EXPORT TARIFF4
APPARENT ENERGY IMPORT TOTAL REACTIVE ENERGY EXPORT TARIFF1
APPARENT ENERGY EXPORT TOTAL REACTIVE ENERGY EXPORT TARIFF2
RESETTABLE ACTIVE ENERGY IMPORT
TOTAL
RESETTABLE ACTIVE ENERGY EXPORT TOTAL
REACTIVE ENERGY EXPORT TARIFF3
REACTIVE ENERGY EXPORT TARIFF4
Page 63
Technical Description
63
RESETTABLE REACTIVE ENERGY IMPORT TOTAL
RESETTABLE REACTIVE ENERGY EXPORT TOTAL
ACTIVE ENERGY IMPORT TARIFF1 APPARENT ENERGY NET TOTAL
ACTIVE ENERGY IMPORT TARIFF2 ACTIVE ENERGY CURRENCY CONVER-
ACTIVE ENERGY IMPORT TARIFF3 ACTIVE ENERGY CO2 CONVERSION
ACTIVE ENERGY IMPORT TARIFF4 PULSE INPUT COUNTERS
REACTIVE ENERGY IMPORT TARIFF1
REACTIVE ENERGY IMPORT TARIFF2
REACTIVE ENERGY IMPORT TARIFF3
REACTIVE ENERGY IMPORT TARIFF4
ACTIVE ENERGY NET TOTAL
REACTIVE ENERGY NET TOTAL
SION
Page 64
Technical Description
64
5.10 Load Profile
General
Intervals
Load profile is a collection of 8 channels that can store register values for register
quantities or interval averages for instrumentation quantities. Through Modbus
and EQ-bus communication each channel can be assigned one register or instrumentation quantity, a time interval and a maximum amount of snapshots to be
stored in the channel.
Interval length per channel can also be configured via the buttons on the meter.
The load profiles can be read via communication or directly on the display.
The stored register values in a channel are read as a list of register snapshots and
for instrumentation values as a list of interval averages.
Note – Before any load profiles can be stored, time/date must be set.
N
If a power failure occurs that lasts over the end of an interval, the value will be
stored when the meter powers up again only if time/date are still correct.
The interval lengths for Load Profiles can be one of the following: 1, 2, 5, 10, 15,
20, 30, 60, 120, 180, 240, 360, 480, 720 or 1440 minutes.
If the interval is evenly divisible with an hour, the start of each hour will mark the
start of a new interval. If the interval is evenly divisible with a day, the start of a
day will mark the start of a new interval.
Example 1
Example 2
Channels and
snapshots
The interval date and time is stored as end of interval. For instance, if an interval
starts 2010.01.01 00:00.00 and ends 2010.01.01 00:15.00, then the stored period
will be 2010.01.01 00:15.00.
Interval is set to 120 minutes, current time 12:13. Evenly divisible with a day. The
next interval end/start times will be: 14:00, 16:00, 18:00, 20:00, 22:00, 00:00,
etc,...
Interval is set to 15 minutes, current time 12:13. Evenly divisible with an hour.
The next interval end/start times will be: 12:15, 12:30, 12:45, 13:00, 13.15, 13.30
etc,...
Each channel has its own interval configuration. That means that snapshots in one
channel can be stored with a different interval than snapshots in another channel.
Each channel can be assigned a number of snapshots. A total of 40 000 snapshots
can be stored in a load profile. All channels in a load profile share the same memory area, which means that one channel can store 40 000 snapshots if no other
Page 65
Technical Description
65
channel is used. By default the meter has all 8 channels activated with 5000 snapshots assigned to each.
If there is no free memory space available, the oldest snapshot will be erased to
make room for the most recent one.
It is possible to erase all snapshots in all channels by sending a “Reset Load profile” command via communication. Via Modbus and EQ-bus communication it is
also possible to erase all snapshots in a particular channel.
Load profile data
Selectable
quantities
Each load profile data value is associated with a status value. The status value
gives information such as:
• Interval is longer or shorter than defined length
• Power outage occurred during interval
• Overflow in data
• Time was changed during interval
• Data not available
• Error in data
Depending on the meter type all or a subset of the following quantities can be
selected:
ACTIVE ENERGY IMPORT TOTAL ACTIVE ENERGY CURRENCY CONVER-
SION
ACTIVE ENERGY EXPORT TOTAL ACTIVE ENERGY CO2 CONVERSION
REACTIVE ENERGY IMPORT TOTAL
REACTIVE ENERGY EXPORT TOTAL CURRENT L1*
APPARENT ENERGY IMPORT TOTAL POWER FACTOR TOTAL*
APPARENT ENERGY EXPORT TOTAL PULSE INPUT COUNTERS
VOLTAGE L1*
*The values are mean values of the intervals.
Page 66
Technical Description
66
Page 67
Chapter 6: Technical data
67
Technical data
Overview
In this chapter
This chapter contains technical data and product drawings.
The following topics are covered in this chapter:
6.1 Technical Specifications ...................................................................... 68
6.2 Physical dimensions ............................................................................ 72
Page 68
Technical data
68
6.1 Technical Specifications
Specifications for A41 direct connected meters
Voltage/current inputs
Nominal voltage 230 V AC
Voltage range 57.7 - 288 V AC (-20%-+15%)
Power dissipation voltage circuits 0.8 VA (0.8 W) at 230 V AC
Power dissipation current circuits 0.007 VA (0.007 W) at I
Base current I
Reference current I
Transitional current I
Maximum current I
Minimum current I
Starting current I
b
ref
tr
max
min
st
Terminal wire area 1-25 mm
Recommended tightening torque 3.0 Nm
General data
Frequency 50 or 60 Hz ± 5%
Accuracy 1%, 2%
Accuracy of internal clock 5 ppm at reference temperature 25°C
Display 96x64 pixels, view area 39x26 mm
Mechanical
Material Polycarbonate in transparent front glass, bottom case, upper
Weight 0.23 kg
Environmental
Operating temperature -40°C - +70°C
Storage temperature -40°C - +85°C
Humidity 75% yearly average, 95% on 30 days/year
Resistance to fire and heat Terminal 960°C, cover 650°C (IEC 60695-2-1)
Resistance to water and dust IP 20 on terminal block without protective enclosure and IP 51
Mechanical environment Class M2 in accordance with the Measuring Instrument Direc-
Electromagnetic environment Class E2 in accordance with the Measuring Instrument Direc-
Outputs
Current 2 - 100 mA
Voltage 5 - 240 V AC/DC. For meters with only 1 output, 5 - 40 V DC.
Pulse output frequency Prog. 1 - 9999 imp/MWh, 1 - 9999 imp/kWh, 1 - 9999 imp/Wh
Pulse length 10 - 990 ms
5 A
5 A
0.5 A
80 A
0.25 A
< 20 mA
case and terminal cover. Glass reinforced polycarbonate in
terminal block.
in protective enclosure, according to IEC 60529.
tive (MID), (2014/32/UE).
tive (MID), (2014/32/UE).
ref
2
Page 69
Technical data
69
Terminal wire area 0.5 - 1 mm²
Recommended tightening torque 0.25 Nm
Inputs
Voltage 0-240 V AC/DC
Off 0-5 V AC/DC
ON 57-240 V AC, 24-240 V DC
Min. pulse length and pulse pause 30 ms
Terminal wire area 0.5 - 1 mm²
Recommended tightening torque 0.25 Nm
Communication
Terminal wire area 0.5 - 1 mm²
Recommended tightening torque 0.25 Nm
M-Bus EN 13757-2, EN 13757-3
Modbus Modbus Application Protocol Specification V1.1b
EQ-Bus IEC 62056-42, 62056-46, 62056-53, 62056-61, 62056-62
Pulse indicator (LED)
Pulse Frequency 1000 imp/kWh
Pulse length 40 ms
EMC compatibility
Impulse voltage test 6 kV 1.2/50µs (IEC 60060-1)
Surge voltage test 4 kV 1.2/50µs (IEC 61000-4-5)
Fast transient burst test 4 kV ( IEC 61000-4-4 )
Immunity to electromagnetic HF-fields 80 MHz - 2 GHz at 10 V/m (IEC 61000-4-3)
Immunity to conducted disturbance 150kHz – 80MHz, ( IEC 61000-4-6 )
Immunity to electromagnetic disturbances
Radio frequency emission EN 55022, class B (CISPR22)
Electrostatic discharge 15 kV ( IEC 61000-4-2 )
Standards IEC 62052-11, IEC 62053-21 class 1 & 2, IEC 62053-23 class
2-150 kHz for kWh-meters
2, IEC 62054-21, GB/T 17215.211-2006, GBT 17215.3212008 class 1 & 2, GB 4208-2008, EN 50470-1, EN 50470-3
category A & B
Specifications for A42 transformer connected meters
Voltage inputs
Nominal voltage 230 V AC
Voltage range 57.7 - 288 V AC (-20% - + 15%)
Power dissipation voltage circuits 0.8 VA (0.8 W) at 230 V AC
Power dissipation current circuits 0.001 VA (0.001 W) at I
Terminal wire area 0.5 - 10 mm²
Recommended tightening torque 1.5 Nm
Current inputs
ref
Page 70
Technical data
70
Rated current I
Reference current I
Maximum current I
Transitional current I
Minimum current I
Starting current I
n
ref
max
tr
min
st
Terminal wire area 0.5 - 10mm
1 A
1 A
6 A
0.05 A
0.01 A
< 1 mA
2
Recommended tightening torque 1.5 Nm
General data
Frequency 50 or 60 Hz ± 5%
Accuracy 0.5%, 1%
Accuracy of internal clock 5 ppm at reference temperature 25°C
Display 96x64 pixels, view area 39x26 mm
Mechanical
Material Polycarbonate in transparent front glass, bottom case, upper
case and terminal cover. Glass reinforced polycarbonate in
terminal block.
Weight 0.20 kg
Environmental
Operating temperature -40°C - +70°C
Storage temperature -40°C - +85°C
Humidity 75% yearly average, 95% on 30 days/year
Resistance to fire and heat Terminal 960°C, cover 650°C (IEC 60695-2-1)
Resistance to water and dust IP 20 on terminal block without protective enclosure and IP 51
in protective enclosure, according to IEC 60529.
Mechanical environment Class M2 in accordance with the Measuring Instrument Direc-
tive (MID), (2014/32/UE).
Electromagnetic environment Class E2 in accordance with the Measuring Instrument Direc-
tive (MID), (2014/32/UE).
Outputs
Current 2 - 100 mA
Voltage 5-240 V AC/DC. For meters with only 1 output, 5 - 40 V DC.
Pulse output frequency Prog. 1 - 9999 imp/MWh, 1 - 9999 imp/kWh, 1 - 9999 imp/Wh
Pulse length 10 - 990 ms
Terminal wire area 0.5 - 1 mm²
Recommended tightening torque 0.25 Nm
Inputs
Voltage 0-240 V AC/DC
Off 0-5 V AC/DC
ON 57-240 V AC, 24-240 V DC
Min. pulse length and pulse pause 30 ms
Terminal wire area 0.5 - 1 mm²
Recommended tightening torque 0.25 Nm
Page 71
Technical data
71
Communication
Terminal wire area 0.5 - 1 mm
Recommended tightening torque 0.25 Nm
M-Bus EN 13757-2, EN 13757-3
Modbus Modbus Application Protocol Specification V1.1b
EQ-Bus IEC 62056-42, 62056-46, 62056-53, 62056-61, 62056-62
Transformer ratios
Configurable voltage ratio (VT) 1 - 9999
Configurable current ratio (CT) 1 - 9999
Max total transformer ratio (VT*CT) 999999
Pulse indicator (LED)
Pulse Frequency 5000 imp/kWh
Pulse length 40 ms
EMC compatibility
Impulse voltage test 6 kV 1.2/50µs (IEC 60060-1)
Surge voltage test 4 kV 1.2/50µs (IEC 61000-4-5)
Fast transient burst test 4 kV (IEC 61000-4-4)
Immunity to electromagnetic HF-fields 80 MHz - 2 GHz at 10 V/m (IEC61000-4-3)
Immunity to conducted disturbance 150kHz – 80MHz, ( IEC 61000-4-6 )
Immunity to electromagnetic disturbances
Radio frequency emission EN 55022, class B (CISPR22)
Electrostatic discharge 15 kV (IEC 61000-4-2)
Standards IEC 62052-11, IEC 62053-21 class 1 & 2, IEC 62053-23 class
2-150 kHz for kWh-meters
2, IEC 62054-21, GB/T 17215.211-2006, GBT 17215.3212008 class 1 & 2, GB 4208-2008, EN 50470-1, EN 50470-3
category A & B
Page 72
Technical data
70
89
93
45
97
43
58
65
72
6.2 Physical dimensions
A41/A42
The following drawing shows the physical dimensions of the A41 and the A42
meters.
Page 73
Chapter 7: Measurement Methods
73
Measurement Methods
Overview
In this chapter
This chapter contains information about measurement theory and the most commonly used measurement methods. The information can be used to better understand the meter behavior and/or to pick the correct measurement method.
The following topics are covered in this chapter:
7.1 Measuring Energy ............................................................................... 74
7.1.1 Single Phase, 1-Element Metering ............................................ 76
Page 74
Measurement Methods
74
7.1 Measuring Energy
Active energy
Reactive energy
It is easy to understand the need for a utility to measure active energy, since the
information is necessary to bill the customer correctly. Usually the more energy
the customer consumes the higher the accuracy of the meter needs to be. Normally
4 accuracy classes are used: 2%- (small consumers, e.g. households), 1%-, 0.5%and 0.2%-meters with defined power levels for each class.
Also from a customer point of view it is easy to understand the need to measure
the active energy as it can give him information about where and when energy is
consumed. This information can then be used to take measures to decrease the
consumption.
In many cases it is desired to simplify the measurement. In such cases simplified
methods can be used of which the most common are described in this chapter.
These methods most often require a balanced load, which means that the impedance is the same in all phases giving the same current amplitude and power factor
in all phases.
Sometimes there is also a need to measure the reactive energy. Consumer equipment often introduces a phase shift between current and voltage due to the fact
that the load has a more or less reactive component, e.g. motors that have an
inductive component, etc. A reactive load will increase the current which means
that the power source generator and the size of the power lines have to increase
which in turn means higher cost for the utility. A higher current also means that
the line losses increase.
Because of that, the maximum permissible phase shift is sometimes governed in
the terms of the contract that the consumer have with the power supplier. If the
consumer exceeds a specified maximum reactive load, he will be liable for an
extra charge. This type of contract will require a utility meter that measures reactive energy and/or power.
Also, from the customer’s point of view, it may be of some interest to measure
reactive energy/power since it gives him knowledge about the nature of the load.
That is, how big the different loads are and how they vary over time. This knowledge can be used in the planning how to decrease the reactive power/energy to
decrease the electricity bill.
Resistive, inductive and capacitive loads
Resistive loads don't give rise to any phase shifts. Inductive loads have phase shift
in one direction with the current lagging the voltage, while capacitive loads produces a phase shift in the opposite direction with the current leading the voltage.
As a result, inductive and capacitive loads can be used to compensate each other
Page 75
Measurement Methods
Resistive load
I
U
UU
II
Capacitive load
Inductive load
Clockwise rotation
Clockwise rotation
M
Reactive power
Active
power
Apparent
power
75
Illustration
Phase
displacement
The following illustration shows a vector diagram for resistive, inductive and capacitive loads:
A load that consumes both reactive and active energy can be divided into active
and reactive components. The angle between the apparent power (U*I) vector and
the active power component is described as phase displacement angle or power
factor angle, often referred to as . Cos is referred to as the power factor.
Illustration
The 4 power
quadrants
The following illustration shows a vector diagram for a load with an active and a
reactive component:
Active power = P = U x I x cos (unit W)
Reactive power = Q = U x I x sin (unit var)
Apparent power = S = U x I (unit VA)
The type of load can be represented geometrically by for quadrants. In the first
quadrant the load is inductive and active and energy is imported (energy is delivered from the utility to the customer). In the second quadrant the load is capacitive
and active energy is exported and reactive energy is imported. In the third quadrant the load is inductive and active and reactive energy is exported. In the last
quadrant the load is capacitive and active energy is imported and reactive energy
exported.
Page 76
Measurement Methods
M
Export of
reactive
power
Export of
active power
S
Q
P
1
43
2
Import of
reactive
power
-
+
+
-
Import of
active power
76
Illustration
7.1.1 Single Phase, 1-Element Metering
The following illustration shows the loads
1- element metering in a 2-wire system
In a 2-wire installation a single phase meter is used. Normally the 2 wires are a
phase voltage and the neutral.
The active energy consumed by the load is the product of momentary voltage and
current integrated over the desired measuring time period.
Calculating active
power
In the case where no harmonics is present and the rms value of the voltage and
current is constant, the active power can be expressed as:
P = U
rms*Irms
where is the phase angle between the voltage and the current.
*cos
Page 77
Measurement Methods
I
N
Load
L
U
Meter
I3
N
Load
L3
U3
Meter
L2
L1
77
Illustration
1-element metering in a 4-wire system
The following illustration shows a direct connected single phase meter measuring
the active energy (E) consumed by a load.
In 4-wire system the single element metering method only gives correct results in
a balanced system (same voltage, current and power factor in all phases). This
method should not be used for accurate measurement, but can be used when high
accuracy is not needed.
Illustration
The following illustration shows single phase metering in a 3-phase system.
Page 78
Measurement Methods
L
2351
S1
S2
P1
P2
N
S1
S2
P1
P2
To load 1
To l o a d 2
78
Summation
metering
Illustration
The currents from several different transformers can be summed into one single
meter.
The following illustration shows summation metering in a single phase meter:
Page 79
Chapter 8: Service & Maintenance
79
Service & Maintenance
Overview
In this chapter
This chapter contains information about service and maintenance of the product.
The following topics are covered in this chapter:
8.1 Service and Maintenance .................................................................... 80
Page 80
Service & Maintenance
80
8.1 Service and Maintenance
Service
Cleaning
This product contains no parts that can be repaired or exchanged. A broken meter
must be replaced.
If the meter needs to be cleaned, use a lightly moistened cloth with a mild detergent to wipe it.
Caution – Be careful that no liquid gets into the meter since it can ruin the equipment.
C
Page 81
Communication with Modbus
81
Chapter 9: Communication with Modbus
Overview
In this chapter
This chapter describes the mapping from meter data to Modbus and how to read
and write to registers. The chapter contains information for all functionality and
data for the complete A series family. For single phase meters some data does not
exist, for example data for phase 2 and 3.
The following topics are covered in this chapter:
9.1 Bus Description ................................................................................... 82
9.2 About the Modbus Protocol ................................................................. 83
9.2.1 Function Code 3 (Read holding registers .................................. 83
9.2.2 Function Code 16 (Write multiple registers) ............................... 85
9.2.3 Function Code 6 (Write single register) ..................................... 86
9.3 Reading and Writing to Registers ........................................................ 88
9.4 Mapping Tables ................................................................................... 89
9.5 Historical Data ................................................................................... 100
9.5.1 Quantity identifiers ................................................................... 103
9.6 Previous Values ................................................................................. 108
9.6.1 Reading Previous Values ......................................................... 110
9.7 Demand ............................................................................................. 112
9.7.1 Reading Demand ..................................................................... 114
9.8 Event logs .......................................................................................... 116
9.8.1 Reading Event logs .................................................................. 118
9.9 Load profile ........................................................................................ 119
9.9.1 Reading Load profile ................................................................ 121
9.10 Configuration ..................................................................................... 122
9.10.1Previous values ....................................................................... 122
Page 82
Communication with Modbus
82
9.1 Bus Description
General Modbus communication in the A series meters is done on a 3-wire (A, B and
Common) polarity dependent bus according to the RS-485 standard. Maximum
number of meters connected to one physical bus is 247 (which is the same as the
individual device address range in Modbus).
Topology The RS-485 bus uses line topology, see figure below. Stubs at the meter connec-
tions are allowed but should be kept as short as possible and no longer than 1 m.
Bus termination in both ends of the line should be used. The resistors should have
the same values as the characteristic impedance of the cable which normally is
120 ohm.
Cable Cable used is non shielded or shielded twisted pair cable with wire area of 0.35-
1.5 mm2. If shielded cable is used the shield should be connected to ground in one
end. Maximum length of the bus is 700 m.
Page 83
9.2 About the Modbus Protocol
83
Communication with Modbus
General
Supported
function codes
Modbus request
frame
Modbus is a master-slave communication protocol that can support up to 247
slaves organized as a multidrop bus. The communication is half duplex. Services
on Modbus are specified by function codes.
The function codes are used to read or write 16 bit registers. All metering data,
such as active energy, voltage or firmware version, is represented by one or more
such registers. For further information about the relation between register number
and metering data, refer to “Mapping Tables” on page - 89.
The Modbus protocol is specified in its entirety in Modbus Application Protocol
Specification V1.1b. The document is available at http://www.modbus.org
The following function codes are supported:
• Function code 3 (Read holding registers
• Function code 6 (Write single register)
• Function code 16 (Write multiple registers)
A Modbus request frame generally has the following structure:
Slave Address Function Code Data Error Check
Slave address Modbus slave address, 1 byte.
Function code Decides the service to be performed.
Data Dependent on the function code. The length varies.
Error check CRC, 2 bytes
Message types
The network messages can be query-response or broadcast type. The queryresponse command sends a query from the master to an individual slave and is
generally followed by a response.
The broadcast command sends a message to all slaves and is never followed by a
response. Broadcast is supported by function code 6 and 16.
9.2.1 Function Code 3 (Read holding registers
General
Function code 3 is used to read measurement values or other information from the
electricity meter. It is possible to read up to 125 consecutive registers at a time.
This means that multiple values can be read in one request.
Page 84
Communication with Modbus
84
Request frame
Example of a
request
Response frame
A request frame has the following structure:
Slave Address Function Code Address No. of Registers Error Check
The following is an example of a request. (read total energy import, etc...)
Slave address 0x01
Function code 0x03
Start address, high byte 0x50
Start address, low byte 0x00
No. of registers, high byte 0x00
No. of registers, low byte 0x18
Error check (CRC), high byte 0x54
Error check (CRC), low byte 0xC0
A response frame has the following structure:
Slave Address Function Code Byte Count Register Values Error Check
Example of a
response
The following is an example of a response:
Slave address 0x01
Function code 0x03
Byte count 0x30
Value of register 0x5000, high byte 0x00
Value of register 0x5000, low byte 0x15
...
Value of register 0x5017, high byte 0xFF
Value of register 0x5017, low byte 0xFF
Error check (CRC), high byte 0xXX
Error check (CRC), low byte 0xXX
In this example, the slave with the Modbus address 1 responds to a read request.
The number of data bytes is 0x30. The first register (0x5000) has the value
0x0015 and the last (0x5017) has the value 0xFFFF
Page 85
9.2.2 Function Code 16 (Write multiple registers)
85
Communication with Modbus
General
Request frame
Example of a
request
Function code 16 is used to modify settings in the meter, such as date/time, to
control output and to reset values, such as power fail counter. It is possible to write
up to 123 consecutive registers in a single request. This means that several
settings can be modified and/or several reset operations can be performed in a
single request.
A request frame has the following structure:
Slave
Address
Function
Code
Start
Address
No. of
Registers
Byte
Count
Register
Values
Error
Check
The following is an example of a request (set Date/Time to November 11, 2010,
12:13:14):
Slave address 0x01
Function code 0x10
Start address, high byte 0x8A
Start address, low byte 0x00
No. of registers, high byte 0x00
No. of registers, low byte 0x03
Byte count 0x06
Value of register 0x8A00, high byte 0x0A
Value of register 0x8A00, low byte 0x0B
Value of register 0x8A01, high byte 0x0B
Value of register 0x8A01, low byte 0x0C
Value of register 0x8A02, high byte 0x0D
Value of register 0x8A02, low byte 0x0E
Error check (CRC), high byte 0x8C
Error check (CRC), low byte 0x82
In this example the master sends a write request to the slave that has the Modbus
address 1. The first register to write is 0x8A00 and the number of registers to write
is 0x03. This means that the registers 0x8A00 to 0x8A02 are written. Register
0x8A00 is set to the value 0x0A0B, and so on.
Page 86
Communication with Modbus
86
Response frame
Example of a
response
A response frame has the following structure:
Slave Address Function Code Start Address No. of Registers Error Check
The following is an example of a response:
Slave address 0x01
Function code 0x10
Register address, high byte 0x8A
Register address, low byte 0x00
No. of registers, high byte 0x00
No. of registers, low byte 0x03
Error check (CRC), high byte 0xAA
Error check (CRC), low byte 0x10
In the example above the slave with the Modbus address 1 responds to a write
request. The first register is 0x8A00 and 0x03 registers have been successfully
written to.
9.2.3 Function Code 6 (Write single register)
General
Request frame
Example of a
request
Function code 6 can be used as an alternative to function code 16 if there is only
one register to be written. It can, for example be used to reset the power fail
counter.
A request frame has the following structure:
Slave Address Function Code Register Address Register Value Error Check
The following is an example of a request (reset power fail counter):
Slave address 0x01
Function code 0x06
Register address, high byte 0x8F
Register address, low byte 0x00
No. of registers, high byte 0x00
No. of registers, low byte 0x01
Page 87
Communication with Modbus
87
Error check (CRC), high byte 0x62
Error check (CRC), low byte 0xDE
Response frame
Using function code 6, the response frame is an echo of the request frame.
9.2.3.1 Exception Responses
General
If an error should occur while processing a request, the meter gives an exception
response that contains an exception code.
Exception frame
An exception frame has the following structure:
Slave Address Function Code Exception Code Error Check
In the exception response the function code is set to the function code of the
request plus 0x80.
Exception codes
The exception codes that are used are listed in the following table:
Exception code Exception Definition
01 Illegal function A function code that is not supported has
02 Illegal data address The requested register is outside the
been used.
allowed range.
03 Illegal data value The structure of a received message is
incorrect.
04 Slave device failure Processing the request fail due to an
internal error in the meter.
Page 88
Communication with Modbus
88
9.3 Reading and Writing to Registers
Readable
registers
Multi-register
values
Unused registers
The readable range in the modbus mapping are registers 1000-8EFF
(hexadecimal). Reading any registers within this range will result in a normal
Modbus response. It is possible to read any number of registers between 1 and
125, i.e., it is not necessary to read all registers of a quantity listed on one line in
the mapping tables. Any attempt to read outside this range will result in an illegal
data address exception (Modbus exception code 2).
For quantities that are represented as more than 1 register, the most significant
byte is found in the high byte of the first (lowest) register. The least significant
byte is found in the low byte of the last (highest) register.
Unused registers within the mapping range, for example missing quantities in the
connected meter, will result in a normal Modbus response but the value of the
register will be set to “invalid”.
For quantities with data type “unsigned”, the value will be FFFF in all registers.
For quantities with data type “signed”, the value is the highest value possible to
express. That means that a quantity that is represented by only one register will
have the value 7FFF. A quantity that is represented by 2 registers will have the
value 7FFFFFFF, and so on.
Writing to
registers
Confirm set
values
N
Writing to registers is only permitted to the registers listed as writable in the
mapping tables. Attempting to write to a register that is listed as writable but that
is not supported by the meter will not result in an error indication.
Note – It is not possible to modify parts of a setting, e.g. to set only the year and month
of the Date/time setting.
After you set a value in the meter, it is recommended that you read the value to
confirm the result, since it is not possible to confirm if a write was successful from
the Modbus response.
Page 89
9.4 Mapping Tables
89
Communication with Modbus
Introduction
Contents of the
mapping tables
Tota l en er gy
accumulators
The purpose of this section is to explain the relation between register number and
metering data.
The following table explains the content of the mapping tables:
Quantity Name of the meter quantity or other information available in the
meter.
Details Refinement of the Quantity column.
Start Reg (Hex) Hexadecimal number for the first (lowest) Modbus Register for
this quantity. *
Size Number of Modbus registers for the meter Quantity. A Modbus
Register is 16 bits long.
Res. Resolution of the value for this Quantity (if applicable).
Unit Unit for the Quantity (if applicable).
Data type Data type for this Quantity, i.e. how the value in the Modbus
registers should be interpreted.
*It is expressed exactly as it is sent on the bus. That is, it should not be subtracted
by 40 000 or decremented by 1, as is common for Modbus products.
All registers in the following table are read only:
Quantity Details Start reg
(Hex)
Size Res. Unit Data type
Active import kWh 5000 4 0,01 kWh Unsigned
Active export kWh 5004 4 0,01 kWh Unsigned
Active net kWh 5008 4 0,01 kWh Signed
Reactive import kvarh 500C 4 0,01 kvarh Unsigned
Reactive export kvarh 5010 4 0,01 kvarh Unsigned
Reactive net kvarh 5014 4 0,01 kvarh Signed
Apparent import kVAh 5018 4 0,01 kVAh Unsigned
Apparent export kVAh 501C 4 0,01 kVAh Unsigned
Apparent net kVAh 5020 4 0,01 kVAh Signed
Active import
CO2
Active import
Currency
kVAh 5024 4 0,001 kg Unsigned
kVAh 5034 4 0,001 currency Unsigned
Page 90
Communication with Modbus
90
Energy accumulators divided into tariffs
All registers in the following table are read only:
Quantity Details Start reg (Hex) Size Res. Unit Data type
Active import Tariff 1 5170 4 0,01 kWh Unsigned
Active import Tariff 2 5174 4 0,01 kWh Unsigned
Active import Tariff 3 5178 4 0,01 kWh Unsigned
Active import Tariff 4 517C 4 0,01 kWh Unsigned
Active export Tariff 1 5190 4 0,01 kWh Unsigned
Active export Tariff 2 5194 4 0,01 kWh Unsigned
Active export Tariff 3 5198 4 0,01 kWh Unsigned
Active export Tariff 4 519C 4 0,01 kWh Unsigned
Reactive import Tariff 1 51B0 4 0,01 kvarh Unsigned
Reactive import Tariff 2 51B4 4 0,01 kvarh Unsigned
Reactive import Tariff 3 51B8 4 0,01 kvarh Unsigned
Reactive import Tariff 4 51BC 4 0,01 kvarh Unsigned
Reactive export Tariff 1 51D0 4 0,01 kvarh Unsigned
Reactive export Tariff 2 51D4 4 0,01 kvarh Unsigned
Reactive export Tariff 3 51D8 4 0,01 kvarh Unsigned
Reactive export Tariff 4 51DC 4 0,01 kvarh Unsigned
Energy accumulators per phase
All registers in the following table are read only:
Quantity Details Start reg (Hex) Size Res. Unit Data type
Active import L1 5460 4 0,01 kWh Unsigned
Active import L2 5464 4 0,01 kWh Unsigned
Active import L3 5468 4 0,01 kWh Unsigned
Active export L1 546C 4 0,01 kWh Unsigned
Active export L2 5470 4 0,01 kWh Unsigned
Active export L3 5474 4 0,01 kWh Unsigned
Active net L1 5478 4 0,01 kWh Signed
Active net L2 547C 4 0,01 kWh Signed
Active net L3 5480 4 0,01 kWh Signed
Page 91
Communication with Modbus
91
Quantity Details Start reg (Hex) Size Res. Unit Data type
Reactive import L1 5484 4 0,01 kvarh Unsigned
Reactive import L2 5488 4 0,01 kvarh Unsigned
Reactive import L3 548C 4 0,01 kvarh Unsigned
Reactive export L1 5490 4 0,01 kvarh Unsigned
Reactive export L2 5494 4 0,01 kvarh Unsigned
Reactive export L3 5498 4 0,01 kvarh Unsigned
Reactive net L1 549C 4 0,01 kvarh Signed
Reactive net L2 54A0 4 0,01 kvarh Signed
Reactive net L3 54A4 4 0,01 kvarh Signed
Apparent import L1 54A8 4 0,01 kVAh Unsigned
Apparent import L2 54AC 4 0,01 kVAh Unsigned
Apparent import L3 54B0 4 0,01 kVAh Unsigned
Apparent export L1 54B4 4 0,01 kVAh Unsigned
Apparent export L2 54B8 4 0,01 kVAh Unsigned
Apparent export L3 54BC 4 0,01 kVAh Unsigned
Apparent net L1 54C0 4 0,01 kVAh Signed
Apparent net L2 54C4 4 0,01 kVAh Signed
Apparent net L3 54C8 4 0,01 kVAh Signed
Resettable energy accumulators
All registers in the following table are read only:
Quantity Start reg
Resettable active
import
Resettable active
export
Size Res. Unit Data type
(Hex)
552C 4 0,01 kWh Unsigned
5530 4 0,01 kWh Unsigned
Resettable
reactive import
Resettable
reactive export
5534 4 0,01 kWh Unsigned
5538 4 0,01 kWh Unsigned
Page 92
Communication with Modbus
92
Instantaneous values
All registers in the following table are read only:
Quantity Details Start
reg
(Hex)
Voltage L1-N 5B00 2 0,1 V Unsigned
Voltage L2-N 5B02 2 0,1 V Unsigned
Voltage L3-N 5B04 2 0,1 V Unsigned
Voltage L1-L2 5B06 2 0,1 V Unsigned
Voltage L3-L2 5B08 2 0,1 V Unsigned
Voltage L1-L3 5B0A 2 0,1 V Unsigned
Current L1 5B0C 2 0,01 A Unsigned
Current L2 5B0E 2 0,01 A Unsigned
Current L3 5B10 2 0,01 A Unsigned
Current N 5B12 2 0,01 A Unsigned
Active power Total 5B14 2 0,01 W Signed
Active power L1 5B16 2 0,01 W Signed
Active power L2 5B18 2 0,01 W Signed
Active power L3 5B1A 2 0,01 W Signed
Reactive power Total 5B1C 2 0,01 var Signed
Reactive power L1 5B1E 2 0,01 var Signed
Reactive power L2 5B20 2 0,01 var Signed
Reactive power L3 5B22 2 0,01 var Signed
Apparent power Total 5B24 2 0,01 VA Signed
Apparent power L1 5B26 2 0,01 VA Signed
Apparent power L2 5B28 2 0,01 VA Signed
Apparent power L3 5B2A 2 0,01 VA Signed
Frequency 5B2C 1 0,01 Hz Unsigned
Phase angle power Total 5B2D 1 0,1 ° -180°-+180° Signed
Phase angle power L1 5B2E 1 0,1 ° -180°-+180° Signed
Phase angle power L2 5B2F 1 0,1 ° -180°-+180° Signed
Phase angle power L3 5B30 1 0,1 ° -180°-+180° Signed
Phase angle voltage L1 5B31 1 0,1 ° -180°-+180° Signed
Phase angle voltage L2 5B32 1 0,1 ° -180°-+180° Signed
Phase angle voltage L3 5B33 1 0,1 ° -180°-+180° Signed
Phase angle current L1 5B37 1 0,1 ° -180°-+180° Signed
Phase angle current L2 5B38 1 0,1 ° -180°-+180° Signed
Phase angle current L3 5B39 1 0,1 ° -180°-+180° Signed
Power factor Total 5B3A 1 0,001 - -1,000-+1,000 Signed
Power factor L1 5B3B 1 0,001 - -1,000-+1,000 Signed
Power factor L2 5B3C 1 0,001 - -1,000-+1,000 Signed
Size Res. Unit Value range Data
type
Page 93
Communication with Modbus
93
Harmonics
N
Quantity Details Start
reg
(Hex)
Power factor L3 5B3D 1 0,001 - -1,000-+1,000 Signed
Current quadrant Total 5B3E 1 - 1-4 Unsigned
Current quadrant L1 5B3F 1 - 1-4 Unsigned
Current quadrant L2 5B40 1 - 1-4 Unsigned
Current quadrant L3 5B41 1 - 1-4 Unsigned
Note – Powers are sent out as 32 bit signed integers, expressed in W (or var/VA)
Size Res. Unit Value range Data
type
with 2 decimals. This means that the maximum power possible to express is
approximately ±21 MW. If the power is higher than that the user is adviced to read
power from the DMTME mapping instead, where the scaling is in W without
decimals.
Harmonics are mapped in one register each, starting with THD and then followed
by 2nd, 3rd, 4th harmonic and so on.
Inputs and
outputs
All registers in the following table are read only:
Quantity Details Start
reg
(Hex)
Voltage harmonics L1-N 5D00 1 16 0,1 % Unsigned
Voltage harmonics L2-N 5D80 1 16 0,1 % Unsigned
Voltage harmonics L3-N 5E00 1 16 0,1 % Unsigned
Voltage harmonics L1-L2 5E80 1 16 0,1 % Unsigned
Voltage harmonics L3-L2 5F00 1 16 0,1 % Unsigned
Voltage harmonics L1-L3 5F80 1 16 0,1 % Unsigned
Current harmonics L1 6000 1 16 0,1 % Unsigned
Current harmonics L2 6080 1 16 0,1 % Unsigned
Current harmonics L3 6100 1 16 0,1 % Unsigned
Current harmonics N 6180 1 16 0,1 % Unsigned
Size/
harmonic
Nr of
harmonics
Res. Unit Data type
The following table contains both writable and read only registers:
Quantity Details Start
Reg
(Hex)
Size Possible values Data type Read/
Write
Output 1 6300 1 ON=1, OFF=0 Unsigned R/W
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Communication with Modbus
94
Quantity Details Start
Reg
(Hex)
Output 2 6301 1 ON=1, OFF=0 Unsigned R/W
Output 3 6302 1 ON=1, OFF=0 Unsigned R/W
Output 4 6303 1 ON=1, OFF=0 Unsigned R/W
Input 1 Current state 6308 1 ON=1, OFF=0 Unsigned R
Input 2 Current state 6309 1 ON=1, OFF=0 Unsigned R
Input 3 Current state 630A 1 ON=1, OFF=0 Unsigned R
Input 4 Current state 630B 1 ON=1, OFF=0 Unsigned R
Input 1 Stored state 6310 1 ON=1, OFF=0 Unsigned R
Input 2 Stored state 6311 1 ON=1, OFF=0 Unsigned R
Input 3 Stored state 6312 1 ON=1, OFF=0 Unsigned R
Input 4 Stored state 6313 1 ON=1, OFF=0 Unsigned R
Input 1 Counter 6318 4 Unsigned R
Input 2 Counter 631C 4 Unsigned R
Input 3 Counter 6320 4 Unsigned R
Size Possible values Data type Read/
Write
Production data
and identification
Input 4 Counter 6324 4 Unsigned R
All registers in the following table are read only:
Quantity Start Reg (Hex) Size Data type
Serial number 8900 2 Unsigned
Meter firmware version 8908 8 ASCII string (up to 16
characters)
Modbus mapping version 8910 1 2 bytes
Type designation 8960 6 ASCII string (12 characters,
including null termination)
Meter firmware version is expressed as a string of 3 digits separated by periods,
e.g. 1.0.0. Unused bytes at the end are set to binary 0.
In the Modbus mapping version register the high byte corresponds to the Major
version (1-255), and the low byte corresponds to the Minor version (0-255).
Page 95
Communication with Modbus
95
Miscellaneous
In the following table Date/time and current tariff are writable. All other registers
are read only:
Quantity Start
Reg
(Hex)
Date/time 8A00 Byte 0: year*
Day of week 8A03 Weekdays (1-7,
DST active 8A04 1=DST active
Day type 8A05 Value 0-15
Season 8A06 Value 0-3
Description Size Data type Read/
Write
3 Date/Time R/W
Byte 1: month
Byte 2: day
Byte 3: hour
Byte 4: minute
Byte 5: second
1 Unsigned R
Mo=1)
1 Unsigned R
0=DST inactive
1 Unsigned R
correspond to
day type 1-16
1 Unsigned R
correspond to
season 1-4
Current tariff 8A07 Tariff 1-4 1 Unsigned R/W
Error flags 8A13 64 flags 4 Bit string R
Information flags 8A19 64 flags 4 Bit string R
Warning flags 8A1F 64 flags 4 Bit string R
Alarm flags 8A25 64 flags 4 Bit string R
Power fail counter 8A2F 1 Unsigned R
Power outage time 8A39 Byte 0-2: days*
Byte 3: hours
Byte 4: minutes
Byte 5: seconds
Reset counter for
active energy import
Reset counter for
active energy export
Reset counter for
reactive energy import
Reset counter for
reactive energy export
8A48 4 Unsigned R
8A4C 4 Unsigned R
8A50 4 Unsigned R
8A54 4 Unsigned R
3 Days/Time R
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Communication with Modbus
96
* Byte 0 is the highest byte of the lowest register
The Reset counter registers show the number of times the resettable energy
accumulators have been reset.
Settings
All registers in the following table have read and write access except number of
elements which is read only:
Quantity Start
Reg
(hex)
Current transformer ratio
primary current
Voltage transformer ratio
primary voltage
Current transformer ratio
secondary current
Voltage transformer ratio
secondary voltage
CO2 conversion factor 8CE0 2 0.001 kg/kWh Unsigned
Currency conversion factor 8CE2 2 0.01 Currency/
LED source (0 = active
energy, 1 = reactive energy)
Number of elements (values
1-3)
8C04 2 - Unsigned
8C06 2 - Unsigned
8C08 2 - Unsigned
8C0A 2 - Unsigned
8CE4 1 - Unsigned
8CE5 1 - Unsigned
Size Res. Unit Data type
Unsigned
kWh
DST start (month in 8CE6
high byte, day of month in
8CE6 low byte, day of week
in 8CE7 high byte, hour in
8CE7 low byte)
DST end (month in 8CE6
high byte, day of month in
8CE6 low byte, day of week
in 8CE7 high byte, hour in
8CE7 low byte)
DST enabled (0 = disabled,
1 = enabled)
8CE6 2 - Unsigned
8CE8 2 - Unsigned
8CEA 1 - Unsigned
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Communication with Modbus
97
Operations
All registers in the following table are write only:
Quantity Details Start
Reg
(hex)
Reset power fail
counter
Reset power outage
time
Reset input counter Input 1 8F0B 1 Write the value 1 to
Reset input counter Input 2 8F0C 1 Write the value 1 to
Reset input counter Input 3 8F0D 1 Write the value 1 to
Reset input counter Input 4 8F0E 1 Write the value 1 to
Reset stored state input 1 8F13 1 Write the value 1 to
Reset stored state Input 2 8F14 1 Write the value 1 to
8F00 1 Write the value 1 to
8F05 1 Write the value 1 to
Size Action Data type
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Reset stored state input 3 8F15 1 Write the value 1 to
perform a reset
Reset stored state Input 4 8F16 1 Write the value 1 to
perform a reset
Reset resettable active
energy import
Reset resettable active
energy export
Reset resettable
reactive energy import
Reset resettable
reactive energy export
Reset Previous values 8F1F 1 Write the value 1 to
Reset Demand 8F20 1 Write the value 1 to
Reset Load profile
channel 1
Reset Load profile
channel 2
8F1B 1 Write the value 1 to
perform a reset
8F1C 1 Write the value 1 to
perform a reset
8F1D 1 Write the value 1 to
perform a reset
8F1E 1 Write the value 1 to
perform a reset
perform a reset
perform a reset
8F21 1 Write the value 1 to
perform a reset
8F22 1 Write the value 1 to
perform a reset
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
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Communication with Modbus
98
Quantity Details Start
Reg
(hex)
Reset Load profile
channel 3
Reset Load profile
channel 4
Reset Load profile
channel 5
Reset Load profile
channel 6
Reset Load profile
channel 7
Reset Load profile
channel 8
Reset System log 8F31 1 Write the value 1 to
Reset Event log 8F32 1 Write the value 1 to
Reset Net quality log 8F33 1 Write the value 1 to
8F23 1 Write the value 1 to
8F24 1 Write the value 1 to
8F25 1 Write the value 1 to
8F26 1 Write the value 1 to
8F27 1 Write the value 1 to
8F28 1 Write the value 1 to
Size Action Data type
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
perform a reset
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
Unsigned
DMTME
multimeters
Freeze demand 8F70 1 Write the value 1 to
freeze the demand
values
Unsigned
Parts of the Modbus mapping is compatible with the ABB DMTME multimeters.
All registers in the following table are read only:
Quantity Start Reg (Hex) Size Unit Data type
Phase Voltage L1-N 1002 2 Volt Unsigned
Phase Voltage L2-N 1004 2 Volt Unsigned
Phase Voltage L3-N 1006 2 Volt Unsigned
Line Voltage L1-L2 1008 2 Volt Unsigned
Line Voltage L2-L3 100A 2 Volt Unsigned
Line Voltage L1-L3 100C 2 Volt Unsigned
Line Current L1 1010 2 mA Unsigned
Line Current L2 1012 2 mA Unsigned
Line Current L3 1014 2 mA Unsigned
Page 99
Communication with Modbus
99
Quantity Start Reg (Hex) Size Unit Data type
3-Phase Sys. Power Factor 1016 2 *1000 Signed
Power Factor L1 1018 2 *1000 Signed
Power Factor L2 101A 2 *1000 Signed
Power Factor L3 101C 2 *1000 Signed
3-Phase Sys. Apparent Power 1026 2 VA Unsigned
Apparent Power L1 1028 2 VA Unsigned
Apparent Power L2 102A 2 VA Unsigned
Apparent Power L3 102C 2 VA Unsigned
3-Phase Sys. Active Power 102E 2 Watt Unsigned
Active Power L1 1030 2 Watt Unsigned
Active Power L2 1032 2 Watt Unsigned
Active Power L3 1034 2 Watt Unsigned
3-Phase Reactive power 1036 2 VAr Unsigned
Reactive Power L1 1038 2 VAr Unsigned
Reactive power L2 103A 2 VAr Unsigned
Reactive Power L3 103C 2 VAr Unsigned
3-Phase Sys. Active energy 103E 2 Wh*100 Unsigned
3-Phase Sys. Reactive energy 1040 2 VArh*100 Unsigned
Frequency 1046 2 mHz Unsigned
Current transformer ratio (current
transformer ratio secondary
current must be set to 1)
Voltage transformer ratio
(voltage transformer ratio
secondary voltage must be set to
1)
11A0 2 1-999999 Unsigned
11A2 2 1-9999 Unsigned
Page 100
Communication with Modbus
100
9.5 Historical Data
General
Header registers
In the Modbus mapping all historical data is organized as entries. This concerns
Previous values, Demand, Load profile and Event logs.
Entry number 1 is the most recent entry, entry number 2 is the second most recent,
and so on. Entry number 0 is not used.
Readout of all types of historical values is made by writing to a group of registers
called Header and reading from one or more groups of registers called Data
blocks.
The Header is used for controlling readout with respect to date/time or entry
numbers, and for loading new entries into the Data blocks. The data blocks
contain the actual data, for example event log entries or energy values.
When there are no more entries to read all registers in the Data blocks are set to
0xFFFF.
There are a number of standard commands that are used in the same way when
reading out any type of historical data. These are represented by registers in the
Header, separately mapped for each functionality, but with the same names.
The following table describes the common header registers:
Function Size Description Data type Read/
write
Get next entry
register
Get next entry 1 Write the value 1 to this register to load
new values in the Data block(s)
Entry number 1 Write to this register to choose an entry
number to start reading from
Date/Time 3 Write to this register to choose a date/
time to start reading from
Direction 1 Write to this register to choose the
direction of reading
Unsigned R/W
Unsigned R/W
Date/Time
(see below)
Unsigned R/W
R/W
The Get next entry register is used to continue an ongoing readout, which was
started by writing to any of the Entry number, Date/Time or Direction registers.
If the direction in Direction register is set to backward the Data block is loaded
with older data. And correspondingly, if the direction is set to forward the Data
block is loaded with more recent data.
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