Electricity Meters IEC/MID
Industrial and Commercial
ZMD400AT/CT, ZFD400AT/CT
E650 Series 3
User Manual
Date: 26.09.2012
File name: D000030110 E650 ZxD400xT Series 3 User Manual en.docx
© Landis+Gyr D000030110 en g
2/96 Revision history
Revision history
Version Date Comments
a 01.07.2009 First edition
b 15.10.2009 Fig. 4.16 replaced
Referenced documents corrected in section 1.8
Error code F.F 00 00 2x 00 added in section 6.2.2 Error Groups
Various grammatical and language errors corrected throughout the document
c 12.11.2009 Minor formatting and typing errors corrected
d 27.05.2010 Update for firmware version B31
e 27.01.2011 Test mode section and document template updated
Optional red LED added to outputs in section 1.4
Phase angles removed from the ZFD400 column in section 1.5.3
Footnote added after table in section 1.5.3
Reactive energy section modified in section 1.5.4
Summation channels section modified in section 1.5.4
Footnote added in section 1.7.2
Section 3.1 retitled "Housing"
f 05.10.2011 Updated document template. Comment regarding grounding inserted in section
4.1.2. Section 5.3.3 "Index System" simplified and new section 11 "Appendix OBIS
Code" inserted.
g 26.09.2012 Update for firmware version B32. New extension board 326x. New measured
quantities. New events. New integrated terminal cover switch. Updated document
template. Section "Safety" becomes first section. OBIS explanation expanded. New
representation of value change procedure in set mode. Minor text improvements
and corrections of formatting and typing errors.
Nothing in this document shall be construed as a representation or guarantee in respect of the performance, quality or durability of the
specified product. Landis+Gyr accepts no liability whatsoever in respect of the specified product under or in relation to this document.
Subject to change without notice.
© Landis+Gyr D000030110 en g – E650 Series 3 – ZMD400AT/CT, ZFD400AT/CT – User Manual
Table of contents 3/96
Table of contents
Revision history...................................................................................................................................... 2
Table of contents ................................................................................................................................... 3
About this document .............................................................................................................................. 5
1 Safety ............................................................................................................................................. 6
1.1 Safety information ..................................................................................................................... 6
1.2 Responsibilities ......................................................................................................................... 6
1.3 Safety regulations ..................................................................................................................... 7
1.4 Radio Interference .................................................................................................................... 7
2 Device description........................................................................................................................ 8
2.1 Field of application .................................................................................................................... 8
2.2 Characteristics .......................................................................................................................... 8
2.3 Type designation..................................................................................................................... 10
2.4 Block schematic diagram ........................................................................................................ 11
2.5 Measuring system ................................................................................................................... 14
2.5.1 Input signals ...................................................................................................................... 14
2.5.2 Signal processor ................................................................................................................ 15
2.5.3 Measured quantities .......................................................................................................... 17
2.5.4 Formation of measured quantities ..................................................................................... 19
2.5.5 Summation channels ......................................................................................................... 24
2.6 Data profile.............................................................................................................................. 24
2.6.1 Stored value profile ........................................................................................................... 24
2.6.2 Load profile 1 and load profile 2 (option) ........................................................................... 25
2.6.3 Event log ........................................................................................................................... 25
2.7 Communication ....................................................................................................................... 28
2.7.1 Optical interface ................................................................................................................ 28
2.7.2 Communication units ......................................................................................................... 28
2.8 MAP software tools ................................................................................................................. 30
2.9 Anti-tampering features ........................................................................................................... 31
2.9.1 DC magnet detection ......................................................................................................... 31
2.9.2 Terminal cover detection ................................................................................................... 31
3 Mechanical construction ........................................................................................................... 32
3.1 Housing ................................................................................................................................... 32
3.2 Face plates ............................................................................................................................. 35
3.3 Connections ............................................................................................................................ 36
3.4 Connection diagrams (examples) ........................................................................................... 38
3.5 Dimensions ............................................................................................................................. 42
4 Installation and de-installation .................................................................................................. 43
4.1 Basic information for connecting meter ................................................................................... 43
4.1.1 Connection to low voltage with current transformers......................................................... 43
4.1.2 Connection to medium and high voltage (Aron circuit) ...................................................... 44
4.1.3 Connection to medium and high voltage (three-phase four-wire circuit) ........................... 45
4.2 Mounting the meter ................................................................................................................. 46
4.3 Connecting meter .................................................................................................................... 48
4.3.1 Connecting the R-S485 interface ...................................................................................... 51
4.4 Check of connections .............................................................................................................. 52
4.5 Commissioning, functional check and sealing ........................................................................ 52
4.6 Installation of terminal cover detection .................................................................................... 54
4.7 De-installation ......................................................................................................................... 55
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5 Operation .....................................................................................................................................57
5.1 Operation with auxiliary power supply .....................................................................................57
5.2 Control elements .....................................................................................................................58
5.2.1 Display keys .......................................................................................................................58
5.2.2 Control of display via optical interface................................................................................58
5.2.3 Reset key ...........................................................................................................................59
5.3 Display .....................................................................................................................................60
5.3.1 Introduction ........................................................................................................................60
5.3.2 Basic layout ........................................................................................................................60
5.3.3 Index system ......................................................................................................................61
5.4 Types of display .......................................................................................................................62
5.4.1 Operating display ...............................................................................................................62
5.4.2 Display menu .....................................................................................................................63
5.4.3 Service menu .....................................................................................................................66
5.5 Alert LED .................................................................................................................................67
5.6 Optical test output ....................................................................................................................68
5.7 Data readout ............................................................................................................................69
5.7.1 Readout to IEC 62056-21 ..................................................................................................70
5.7.2 Readout to dlms .................................................................................................................72
5.8 Input of formatted commands ..................................................................................................73
5.9 Set time and date, ID numbers, battery time ...........................................................................74
6 Service .........................................................................................................................................75
6.1 Operating faults .......................................................................................................................75
6.2 Error messages .......................................................................................................................75
6.2.1 Structure of an error message ...........................................................................................76
6.2.2 Error groups .......................................................................................................................77
6.3 Repairing meters .....................................................................................................................82
7 Maintenance ................................................................................................................................83
7.1 Meter testing ............................................................................................................................83
7.1.1 Test mode ..........................................................................................................................83
7.1.2 Measuring times .................................................................................................................84
7.1.3 Optical test output ..............................................................................................................84
7.1.4 Creep test ..........................................................................................................................86
7.1.5 Starting test active part ......................................................................................................86
7.1.6 Starting test reactive part ...................................................................................................86
7.2 Changing the battery ...............................................................................................................87
8 Disposal .......................................................................................................................................89
9 Index .............................................................................................................................................90
Appendix 1 OBIS code ..................................................................................................................93
© Landis+Gyr D000030110 en g – E650 Series 3 – ZMD400AT/CT, ZFD400AT/CT – User Manual
About this document 5/96
About this document
Range of validity The present user manual applies to the meters specified on the title page.
Purpose The user manual contains all the information required for metering applica-
tions for the intended purpose. This includes:
Provision of knowledge concerning the characteristics, construction
and function of the meters
Information about potential dangers, their consequences and meas-
ures to prevent any danger
Details about the performance of all activities throughout the service
life of the meters (parameterisation, installation, commissioning, opera-
tion, maintenance, decommissioning and disposal)
Target group The content of this user manual is intended for technically qualified person-
nel of utilities (energy supply companies), responsible for system planning,
installation and commissioning, operation, maintenance, decommissioning
and disposal of meters.
Reference documents The following documents provide further information related to the subject
of this document:
D000030106 "E650 ZxD400xT Series 3 Technical Data"
D000030112 "E650 ZxD Series 3 Functional Description"
Conventions The structure and significance of meter type designations are described in
section 2.3 "Type designation". The following conventions are employed in
this user manual for representing type designations:
The lower case letter "x" can be used as an unknown to indicate dif-
ferent versions (e.g. ZxD400 for the ZMD400 and ZFD400 meters or
ZMD410xT for the ZMD410AT and ZMD410CT meters).
The digit pair "00" can be used to indicate accuracy data (e.g. ZxD400
for the ZxD405 and ZxD410 meters).
The abbreviated type designation ZMD or ZFD meters can be used
when all three-phase four-wire meters or three-phase three-wire
meters are meant.
The following collective terms are also sometimes used instead of the
type designation:
– "Active energy meters" for the ZxD400AT meters
– "Combi-meters" for the ZxD400CT meters
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1 Safety
This section describes the safety information used in this manual, outlines
the responsibilities and lists the safety regulations to be observed.
1.1 Safety information
The following symbols are used to draw your attention to the relevant
danger level, i.e. the severity and probability of any danger, in the individual
sections of this document.
Warning
Used to indicate a dangerous situation that could cause bodily injury or
death.
Caution
Used to indicate a situation/ action that could result in material damage or
loss of data.
Note
Used to indicate general guidelines and other useful information.
In addition to the danger level, safety information also describes the type
and source of the danger, its possible consequences and measures for
avoiding the danger.
1.2 Responsibilities
The owner of the meters – usually the utility company – is responsible for
ensuring that all persons working with meters:
Have read and understood the relevant sections of the user manual.
Are appropriately qualified for the work to be performed.
Strictly observe the safety regulations (laid down in section 1.3) and
the operating instructions as specified in the individual sections.
In particular, the owner of the meters bears responsibility for the protection
of persons, prevention of material damage and the training of personnel.
For this purpose, Landis+Gyr provides training on a variety of products and
solutions. Please contact your local Landis+Gyr representative if interested.
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1.3 Safety regulations
The following safety regulations must be observed at all times:
The meter connections must be disconnected from all voltage sources
during installation or when opening.
Contact with live parts can be fatal. The relevant supply fuses should,
therefore, be removed and kept in a safe place until the work is com-
pleted so that other persons cannot replace them unnoticed.
Local safety regulations must be observed. Only technically qualified
and appropriately trained personnel are authorised to install the
meters.
Only appropriate tools shall be used for the job. This means, e.g. that
the screwdriver must be of the correct size for the screws, and the
handle of the screwdriver must be insulated.
Secondary circuits of current transformers must be short-circuited (at
the test terminal block) without fail before opening. The high voltage
produced by an interrupted current transformer circuit is dangerous to
life and destroys the transformer.
Transformers in medium or high voltage systems must be earthed on
one side or at the neutral point on the secondary side. Otherwise they
can be statically charged to a voltage which exceeds the insulation
strength of the meter and is also dangerous to life.
The meters must be held securely during installation. They can cause
injuries if dropped.
Meters that have been dropped must not be installed, even if no dam-
age is apparent, but must be returned to the service and repair depart-
ment (or the manufacturer) for testing. Internal damage may result in
malfunctions or short-circuits.
The meters must never be cleaned under running water or with com-
pressed air. Water ingress can cause short-circuits.
1.4 Radio Interference
Possible radio interference in residential environments
This meter is normally a class B product. In combination with some commu-
nication modules it can become a Class A product. In a domestic environ-
ment, this may then cause radio interference, in which case the user may
be required to take adequate measures.
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2 Device description
This section provides you with a brief overview of the design and function of
the ZxD400xT meters.
2.1 Field of application
ZxD400xT meters can be used for transformer connection at all three volt-
age levels, namely on low, medium and high voltage. They are primarily
used by medium and large consumers and in the field of energy generation
and exchange.
The ZMD400xT meter is especially suitable for applications at the low volt-
age level, while the ZFD400xT meter is generally used more at the medium
and high voltage levels.
ZxD400xT meters have a comprehensive tariff structure. This extends from
seasonal tariffs to multiple energy and demand tariff rates.
The ZMD400xT and ZFD400xT meters are designed for connection to cur-
rent transformers with 5 A or 1 A rated current or as a special version for
both applications (5//1).
The ZMD400CT and ZFD400CT combi-meters record active and reactive
energy consumption, the ZMD400AT and ZFD400AT active energy meters
only the active energy in three-phase four-wire or three-phase three-wire
networks (low, medium and high voltage) and from this determine the re-
quired electrical measured quantities. For this purpose they are connected
to the measuring point via current transformers and possibly also voltage
transformers:
Low voltage: ZMD400xT with current transformers
Medium voltage: ZFD400xT (sometimes also ZMD400xT) with current
and voltage transformers
High voltage: ZMD400xT (sometimes also ZFD400xT) with current
and voltage transformers
The data determined are displayed (LCD) and are also available at the op-
tical interface for data acquisition, with an appropriate communication unit
also as required via CS, RS232, RS485, modem, etc.
When equipped with transmitting contacts, the meters can also be used as
transmitting meters for telemetering. The tariff rates can be controlled inter-
nally or externally.
With a communication unit, the meters can also be used for recording
counter pulses for other physical media (e.g. water or gas volumes).
2.2 Characteristics
ZxD400xT meters have the following basic characteristics:
Recording of active, reactive and apparent energy in all four quadrants
(ZxD400CT) or recording of imported and exported active energy
(ZxD 400AT)
Tariff system with energy and demand tariff rates, stored values, load
profiles etc.
Extended functions such as monitoring functions, sliding maximum
demand, etc. (for ZxD400CT additionally power factor cosφ)
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Tariff control
– External
- via control inputs (ZxD400xT21 and ZxD400xT41)
- via communication interfaces using formatted commands
– Internal
- by integral time switch (ZxD400xT24 and ZxD400xT44)
- by event signals based on monitored values, such as voltage,
current, demand etc.
Display of data on a liquid crystal display (LCD)
Active and reactive power per phase and true RMS values of voltages
and currents by means of digital signal processing (DSP) chips
Accuracy: Compliance with IEC class 1 or 0.5 S and with MID accu-
racy class B or C for active energy consumption (ZxD400xT) and IEC
class 1 for reactive energy (ZxD400CT).
Exception: ZxD402CT – IEC class 0.2S for active energy and IEC
class 0.5 for reactive energy.
Flexible measuring system through parameterisation (definition of
different variables by software)
Correct measurement even with failure of individual phases or when
used in two- or single-phase networks
Wide range of measurement from starting current to maximum current
Optical interface according to IEC 62056-21 and dlms
– for direct readout of meter data
– for service functions of the meter, extension board and communica-
tion unit (e.g. parameterisation)
Inputs for recording fixed valency pulses (communication unit)
Output contacts (solid-state relays) for fixed valency pulses, control
signals and status messages
Output contacts (relays) for control and status messages
Input contact for alarm monitoring and sending SMS messages, if
suitable optional communication unit selected
Installation aids
– Indication of phase voltages, phase angles, rotating field and
direction of energy
Storage of event information, e.g. voltage failures, exceeding of thres-
holds or error messages. Event information can be read out via the
available interfaces. Important events can be communicated to the
energy supply company as operational messages (sending of SMS
messages, control of an arrow in the display, drive for an output con-
tact, etc.).
Interfaces such as CS, RS232, RS485, modem, etc. for remote trans-
mission of data (communication unit)
Auxiliary power supply for communication with the meter if no measur-
ing voltage is present
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2.3 Type designation
ZMD 4 10 C T 44 4207 S3
Network type
ZFD 3-phase 3 wire network (F-circuit)
ZMD 3-phase 4 wire network (M-circuit)
Connection type
4 Transformer operated
Accuracy class
10 Active energy class 1 (IEC), B (MID)
05 Active energy class 0.5 (IEC), C (MID)
02 Active energy class 0.2 (IEC)
Measured quantities
C Active and reactive energy
A Active energy
Construction
T With exchangeable communication units
Tariffication
21 Energy rates, external rate control via control inputs
24 Energy rates, internal rate control via time switch
(additionally possible via control inputs)
41 Energy and demand rates, external rate control via control inputs
44 Energy and demand rates, internal rate control via time switch
(additionally possible via control inputs)
All versions with 3 control inputs and 2 output contacts
Additional functions
000x No extension board
060x 6 outputs
240x 2 control inputs, 4 outputs
326x 3 control inputs. 2 relays outputs, auxiliary power supply 12–24 VDC
420x 4 control inputs, 2 outputs
045x 4 outputs, auxiliary power supply 100–240 VAC/VDC
046x 4 outputs, auxiliary power supply 12–24 VDC
xxx0 No additional functions
xxx2 DC-magnet-detection
xxx7 Load profile
xxx9 DC-magnet-detection and load profile (integrated terminal cover switch option only available
in this configuration)
Series 3
As the communication unit is a device on its own, it is not part of the meter’s
type designation. The customer can exchange it at any time without opening
the certification seal. Each communication unit has its own user manual.
Series designation The hardware version is defined with a series designation. The first hard-
ware generation (Series 1) does not have a series designation.
The type designation on the nameplate ends with the series designation S2
for the 2nd hardware generation (Series 2). An attached suffix points out
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that the meter is equipped with certain non-standard features, e.g. S2s
represents a Series 2 meter with symmetrical terminal layout.
S3 represents the newest hardware generation.
Firmware version The meter’s firmware version, which determines certain meter characteris-
tics, can be displayed on the LCD e.g. as part of the rolling display (depen-
ding on parameterisation) and can be read out in the following two ways:
meter data readout (depending on parameterisation)
meter identification readout (see section 5.7 "Data readout")
Class 0.2 Some executions of ZMD400CT/CR meters are available with accuracy
class 0.2S. These meters fulfill the IEC accuracy class 0.2S for active ener-
gy and class 0.5 for reactive energy. For details see the corresponding
datasheet.
2.4 Block schematic diagram
This section provides an overview of the function of ZxD400xT meters
based on a block schematic diagram.
Figure 1 Block schematic diagram ZMD400xT
The ZxD400AT active energy meters record the imported and exported
active energy consumption, while the ZxD400CT combi-meters record the
active and reactive energy consumption in all four quadrants.
The ZxD400xT meters can be fitted with modular communication interfaces
in a communication unit, which can be exchanged or used in the field as
required.
Inputs The main meter inputs are:
Connections of phase voltages (U1, U2, U3), phase currents (I1, I2, I3)
and neutral conductor N
– for processing in the measuring system
– for the three-phase power supply to the meter and voltage monitor
Control inputs Ut (3 fixed, plus up to 4 others on extension board) for:
– Changeover of energy and demand tariff rates
– Resetting
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– Demand inhibition
– Synchronizing
Opto-couplers protect the internal circuitry from interference, which
could otherwise enter via the control inputs.
Keys
– for display control (display keys, optical interface)
– for resetting or service functions (reset key)
Pulse inputs for connection of external pulse transmitters (only for
meters equipped with a communication unit)
Outputs The meter has the following outputs:
LCD display with display keys for local reading of billing data (single 8-
digit display with additional information, such as energy direction, type
of energy, presence of phase voltages and identification number)
Optical test outputs (red, 1 in active energy meters, 2 in combi-meters)
Optional alert LED (red) to indicate alerts on the front face of the meter
Static relay with freely parameterised signal assignment (2 fixed, plus
up to 6 others on the extension board)
Relay outputs with limited parameterised signal assignment due to
limited life expectancy (up to 2 on the extension board)
Optical interface for automatic local data acquisition by a suitable
acquisition unit (handheld terminal)
Communication interfaces of various kinds in the communication unit
(see also section 2.7 "Communication")
Measuring system The input circuits (voltage dividers and current transformers) record voltage
and current in the individual phases. Analogue-digital converters digitise
these values and feed them as instantaneous digital values via calibration
stages to a signal processor.
Signal processing The signal processor determines the following measured quantities from
the instantaneous digital values of voltage and current for each phase and
forms their mean value over one second:
Active power per phase
Reactive power per phase (combi-meters ZxD400CT only)
Phase voltages
Phase currents
Network (mains) frequency
Phase angles
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Signal utilisation For signal utilisation in the various registers, the microprocessor scans the
measured quantities every second to determine the following values:
Active energy (sum and individual phases, separated according to en-
ergy direction, if required in the combi-meters ZxD400CT also
assigned to the 4 quadrants)
Reactive energy (only for combi-meters ZxD400CT, sum and individual
phases, separated according to energy direction, assigned to the 4
quadrants)
Apparent energy (only for combi-meters ZxD400CT, sum and
individual phases, separated according to energy direction)
Power factor cosφ (only for combi-meters ZxD400CT, individual
phases and mean value)
Phase voltages
Phase currents and neutral current
Active and reactive power
Direction of rotating field
Total harmonic distortions of active energy, voltage and current
Energy losses (line losses and transformer losses)
Tariff control Tariff control is performed:
Externally via control inputs (3 fixed, plus up to 4 others on the exten-
sion board)
Externally via communication interfaces using formatted commands
Internally by time switch and calendar clock
By event signals based on threshold values of the monitoring functions
Data preparation for The following registers are available for evaluation of the individual
billing measured values:
32 for energy rates
27 for total energy
10 for running mean demand values
24 for demand rates
2 for power factors cosφ (combi-meters ZxD400CT only)
up to 41 diagnostic registers
others for values of voltage and current, network frequency and phase
angles
Memory A non-volatile flash memory serves to record data profiles and also con-
tains the configuration and parameterisation data of the meter and secures
the billing data against loss due to voltage failures.
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Power supply The supply voltages for the meter electronics are obtained from the three-
phase network, whereby the phase voltage can vary over the entire voltage
range without the supply voltage having to be adjusted. A voltage monitor
ensures correct operation and reliable data recovery in the event of a
power failure and correct restarting when the voltage is restored.
Auxiliary power For medium or high-voltage applications in particular, the measuring volt-
supply age can be switched off. Since the meter normally obtains its supply from
the measuring voltage, it is also switched off and cannot be read. The aux-
iliary power supply connected in parallel with the normal power supply en-
sures operation of the meter free from interruption, so that it can be read at
any time. The auxiliary power supply is situated on an extension board.
Extension board The extension board is fitted inside the meter and is secured by the certifi-
cation seals. It cannot be exchanged. It can have the following components:
up to 4 control inputs in combination with
up to 6 output contacts (solid-state relays)
up to 2 relays outputs
an auxiliary power supply
Communication unit The communication unit for fitting only in the ZxD400xT meters is a com-
plete unit in its own case. If present, it is situated behind the front door, and
is therefore secured by a utility seal and can be exchanged or inserted in
the field if necessary. It contains:
Communication interfaces as required for remote readout of the meter
(e.g. CS, RS232, RS485, modem)
2 signal inputs (S0 interfaces) for processing external pulse transmit-
ters
2.5 Measuring system
Figure 2 Block schematic diagram of measuring system
2.5.1 Input signals
The meter has the analogue current values I1, I2 and I3 and analogue volt-
age values U1, U2 and U3 available as input signals.
ZMD400xT
Figure 3 Type of measurement ZMD400xT
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Since the ZMD400xT measures the individual phases mutually independ-
ently with one measuring element each, it can record the sum of the three
phases, the individual phases themselves, the phase angle between volt-
age and current as well as the angle between voltages U1–U2 and U1–U3.
ZFD400xT
Figure 4 Type of measurement ZFD400xT
The ZFD400xT with Aron circuit records with its two measuring elements
the phase currents I1 or I3, together with the corresponding voltage U12 or
U32. It cannot therefore construct any actual single-phase values. In addi-
tion, the phase angles between voltage and current always have an addi-
tional angle of 30° and are therefore not representative.
Voltage input High resistance voltage dividers reduce the voltages U1, U2 and U3 (58 to
240 V) applied to the meter to a proportionate amount of a few mV (UU) for
further processing.
Current input Internal current transformers reduce the input currents I1, I2 and I3 to the
meter (0 to 10 A) for further processing. The secondary currents of these
current transformers develop voltages proportional to the input currents
across resistors, also of a few mV (UI).
2.5.2 Signal processor
Figure 5 Principle of signal processor
ZxD400AT active energy meters do not measure reactive energy.
Digitizing The analogue signals Ux and Ix are digitised in Sigma-Delta converters
(analogue-digital converters with highest resolution) with a sample rate of
1.6 kHz and then filtered. A following calibration stage compensates for the
natural errors of the voltage divider or current transformer, so that no fur-
ther adjustment is necessary in the subsequent processing.
Calibrated digital instantaneous values of voltage (u) and current (i) for all
three phases are then available as intermediate values for the formation of
the required values in the signal processor.
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Calculation of active The instantaneous value of active power p is produced by multiplying the
power instantaneous values of voltage u and current i (the active component cor-
responds to the product of voltage component with the current component
parallel to the voltage). Thereby the harmonics up to 1 kHz are measured
correctly.
IQ I
Calculation per phase of
P = U . I . cos
IP U
Figure 6 Active power calculation
Instantaneous power If the meter is parameterised to calculate instantaneous power as signed
with sign values, the following values of power are available:
Active P: + in QI and QIV, - in QII and QIII
Reactive P: + in QI and QII, - in QIII and QIV
Calculation of reactive There are two possibilities to calculate the instantaneous value of reactive
power power (ZxD400Cx combi-meters only):
Measured:
For the instantaneous value of reactive power q the instantaneous value of
voltage u must be rotated by 90° before multiplication (the reactive
component is the product of the voltage component with the current
component vertical to the voltage). Thereby no harmonics are measured
since only the fundamental wave is rotated through 90°.
IQ I
Calculation per phase of
Q = U . I . sin
IP U
Figure 7 Reactive power calculation (method: measured)
Calculated vectorial (not recommended):
The instantaneous value of reactive power is calculated using the values of
active power and apparent power.
The reactive power is the square root of the square value of apparent
power minus the square value of active power. This method includes the
harmonics.
URMS, IRMS calculation The square values of voltage and current are obtained by multiplying the
instantaneous values of voltage and current by themselves. From these
values the signal processor forms the corresponding single-phase RMS
values URMS and IRMS.
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Time measurement The network frequency can be calculated from the time measured between
two zero passages (change from negative to positive value of voltage U1).
The times between zero passage of the phase voltage U1 and those of the
other phase voltages U2 and U3 serves to determine the phase angle be-
tween the voltages and of the rotating field.
U1 U2 U3 Time measurement
for rotating field,
frequency, phase angle
1 : T U1-U2
2 : T U1-U3
1
2
3 : TU1-U1 (fn)
3
Figure 8 Time measurement
The phase angle between voltage and current is determined by the times
between zero passage of the phase voltage U1 and those of the phase cur-
rents I1, I2 and I3.
Mean value formation For further processing of the individual signal the signal processor gener-
ates mean values over one second, which the following microprocessor
scans at intervals of one second.
2.5.3 Measured quantities
Measured quantity ZMD400 ZFD400
Active energy in quadrant I A (QI) Sum / Phases Sum
Active energy in quadrant II A (QII) Sum / Phases Sum
Active energy in quadrant III A (QIII) Sum / Phases Sum
Active energy in quadrant IV A (QIV) Sum / Phases Sum
Active energy import +A (QI+QIV) Sum / Phases Sum
Active energy export –A (QII+QIII) Sum / Phases Sum
Active energy, absolute value +A+-A Sum / Phases Sum
Active energy, absolute value +A--A Sum / Phases Sum
Active energy import summation Σ +A Sum Sum
Acitve energy export summation Σ -A Sum Sum
Active energy by single quantity Σ ALx Sum Sum
Reactive energy in quadrant I R (QI) Sum / Phases Sum
Reactive energy in quadrant II R (QII) Sum / Phases Sum
Reactive energy in quadrant III R (QIII) Sum / Phases Sum
Reactive energy in quadrant IV R (QIV) Sum / Phases Sum
Reactive energy import +R (QI+QII) Sum / Phases Sum
Reactive energy export –R (QIII+QIV) Sum / Phases Sum
Reactive energy import +R (QI+QIV) Sum / Phases Sum
Reactive energy export –R (QII+QIII) Sum / Phases Sum
Reactive energy, combined R (QI+QIII) Sum / Phases Sum
Reactive energy, combined R (QII+QIV) Sum / Phases Sum
Reactive energy, absolute value +R+-R Sum / Phases Sum
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Measured quantity ZMD400 ZFD400
Reactive energy, absolute value +R--R Sum / Phases Sum
Reactive energy import summation Σ +R Sum Sum
Reacitve energy export summation Σ -R Sum Sum
Apparent energy import +S (QI+QIV) Sum / Phases Sum
Apparent energy export -S (QII+QIII) Sum / Phases Sum
Phase voltages (RMS) U1, U2, U3 U12, U32
Phase currents (RMS) I1, I2, I3 I1, I3
Neutral current I0 yes no
Network frequency fn yes yes
Active power ±P Sum / Phases Sum
Reactive power ±Q Sum / Phases Sum
Phase angle between voltages U U1-U2 / U1-U3* no
Phase angle between voltage and U-I U1-I1, U1-I2, no
current U1-I3 *
or
U1-I1, U2-I2,
U3-I3
Power factor PF Sum / Phases Sum
Direction of rotating field yes yes
THD of active energy import +THDA Sum Sum
THD of active energy export -THDA Sum Sum
THD of active energy (percent) THDA [%] Sum Sum
THD of phase voltages (absolute) THDU Phase 1, 2, 3 Phase 1, 3
THD of voltage (percent) THDU [%] Sum Sum
THD of phase currents (absolute) THDI Phase 1, 2, 3 Phase 1, 3
THD of current (percent) THDI [%] Sum Sum
Line (copper) losses of active OLA Sum Sum
energy
Transformer (iron) losses of active NLA Sum Sum
energy
Voltage square hours U2h Sum Sum
2
Ampere square hours Ih Sum Sum
* Only if U1 is present.
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2.5.4 Formation of measured quantities
By scanning the mean values of active power P, and in combi-meters also
reactive power Q every second, energy components are produced (Ws or
vars) at fixed intervals (every second) and with varying energy magnitudes
or demand. These energy components are scaled by the microprocessor
corresponding to the meter constant and are then available as measured
quantities for selection of the measured values. The measured values are
fed directly to the following registers to record the energy and the maximum
demand (in combi-meters also of minimum power factor).
Active energy The active energy in the individual phases ±A1, ±A2 and ±A3 are formed
directly from the mean values of active power P1, P2 and P3.
By summating the mean values of active energy A1, A2 and A3 the micro-
processor calculates the total active energy import +A or the total active
energy export -A.
Mean values
per second Measured quantities
± A1
+A (Import)
±A 2 -A (Export)
±A3
Figure 9 Total active energy
Reactive energy The reactive energy values of the individual phases ±R1, ±R2 and ±R3 are
obtained in the combi-meters directly from the mean values of reactive
power Q1, Q2 and Q3. The reactive energy can therefore also be
calculated vectorially (see 1.5.2).By summating the mean values of reactive
energy R1, R2 and R3, the microprocessor calculates the total positive
reactive energy +R or the total negative reactive energy -R.
Mean values
per second Measured quantities
± R1
+R
±R2 -R
±R3
Figure 10 Total reactive energy
The microprocessor can allocate the reactive energy to the 4 quadrants in
the combi-meters from the signs of R and A:
Reactive energy in 1st quadrant: +Ri
Reactive energy in 2nd quadrant: +Rc
Reactive energy in 3rd quadrant: –Ri
Reactive energy in 4th quadrant: –Rc
In the same way it can allocate the reactive energy of the individual phases
to the 4 quadrants.
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+R
+ kvarh + kvarh
+Rc +Ri
Quadrant II Quadrant I
Export -A +A Import
- kWh Quadrant III Quadrant IV + kWh
- kvarh
-Ri -Rc - kvarh
-R
Figure 11 4-quadrant measurement
The quadrants are numbered from top right as 1st quadrant (+A/+Ri) anti-
clockwise to the 4th quadrant (+A/–Rc) at bottom right.
Apparent energy The apparent energy is calculated in the combi-meters in two ways:
by vectorial addition of the active and reactive energy of the individual
phases
by multiplying the rms values of voltage and current of the individual
phases
The method of calculation can be parameterised (only one possible in each
case).
Calculation method 1 From the mean values A1, A2 and A3 and R1, R2 and R3 the microproc-
(vectorial addition) essor calculates the apparent energy of the individual phases ±S1, ±S2 and
±S3 as well as the total apparent energy ±S.
Mean values
per second
±A1
Measured quantities
±A2
±A3
2 2 +S (Import)
(A1 + A2 + A3) + (R1 + R2 + R3)
±R1 -S (Export)
±R2
±R3
Figure 12 Total apparent energy according to calculation method 1
Only fundamental wave considered for reactive energy
Only the fundamental wave is considered for the calculation of the reactive
energy share; possible harmonics are not taken into account.
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Calculation method 2 From the mean values U1rms, U2rms, U3rms and I1rms, I2rms, I3rms the micro-
(from rms values) processor calculates by multiplication the apparent power of the individual
phases ±VA1, ±VA2 and ±VA3 and summates these for the total apparent
power ±VA.
Mean values
per second
I1rm s
U1rm s
I1rm s U1 rm s
å Measured quantities
I2rm s +S (Import)
U2rm s
I2rm s U2 rm s
å -S (Export)
I3rm s
U3rm s
I3rm s U3 rm s
å
Figure 13 Total apparent power according to calculation method 2 (ZxD400Cx
combi-meters only)
Harmonics considered for reactive energy
As RMS values are used for the calculation of the apparent energy with cal-
culation method 2, not only the fundamental wave but also the harmonics
are taken into account. Therefore, if harmonics are present, the measured
values are greater than those of calculation method 1.
Summation channels The values of two measurement quantities (incl. pulse inputs EX1 and EX2)
can be added.
Power factor cosφ The power factor cosφ is calculated in combi-meters as follows:
The meter uses the method of calculation employed for calculating the
apparent power.
Phase voltages The rms values of the voltages U1rms, U2rms and U3rms are obtained from
the mean values of the squares of the voltages by extracting the root and
directly from these the phase voltages U1, U2 and U3.
Phase currents The rms values of the currents I1rms, I2rms and I3rms are obtained from the
mean values of the squares of the currents by extracting the root and di-
rectly from these the phase currents I1, I2 and I3.
Neutral current The signal processor calculates the instantaneous neutral current i0 by
adding the instantaneous phase currents i1, i2 and i3.
i2
i0 = i1 + i2 + i3
i1 (vectorial addition)
i3
i0
Figure 14 Neutral current I0
Network frequency The signal processor calculates the network frequency fn by forming the
reciprocal from the time tU1-U1 between two zero passages of voltage U1.
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Phase angles The signal processor calculates the phase angles between voltages U1-U2
and U1-U3 from the times tU1-U1, tU1-U2 and tU1-U3 between zero passages of
the various voltages.
The signal processor calculates the phase angle between voltage U1 and
current per phase from the times tU1-I1, tU1-I2 and tU1-I3 between zero pas-
sages of the voltage U1 and the phase currents.
2 forms of representation are available for displaying the phase angle.
These can be selected by parameterisation.
Case 1: All voltage and current angles are displayed clockwise with refer-
ence to the voltage in phase 1. The values of the angles are always posi-
tive and can be from 0 to 360°.
Figure 15 Phase angle case 1
Case 2: The voltage angles are displayed as in case 1. The angles of the
currents are displayed, however, with reference to the associated phase
voltage and can have values between -180° and +180°.
Figure 16 Phase angle case 2
Direction of rotating The direction of the rotating field is calculated by the microprocessor based
field on the phase angle of the 3 voltages. If the direction of rotation corres-
ponds to that specified by the parameterisation, the phase voltage indica-
tions L1, L2 and L3 are continuously lit. Otherwise they flash every second.
Total harmonic The measuring system produces information about the total harmonic dis-
distortion tortion of the active energy.
For that purpose, the voltages are fed through notch filters, which remove
the fundamental wave.
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+A +THDA
+THDA = +A - (+A fundamental)
-A -THD A = -A - (-A fundamental ) -THDA
Figure 17 Calculation of total harmonic distortion
In addition, the following absolute and relative THD values available:
THD of active energy (relative to the nominal active energy)
THD of phase voltages (absolute)
THD of voltage (relative to the nominal voltage)
THD of phase currents (absolute)
THD of phase current (relative to the nominal current)
Losses Depending on the metering point in the network, the meter does not only
measure the net energy that is transferred from the power station to the
user but also the line losses (caused by the copper resistance RCu) and the
transformer losses (caused by the iron resistance RFe).
Metering point A Metering point B Metering point C
RFe
RCu
Generator Load
Transmission
Production Meter A Meter B Customer
Figure 18 Calculation of Losses
Line losses are caused by the copper resistance RCu of the transmitting
line. The copper resistance is only effective if there is a load and therefore
current is actually flowing.
On Load Active OLA for line losses of active energy
The transformer losses represent all losses of the transformer. They are
mainly caused by the iron core of the transformer. Transformer losses
(equivalent resistance RFe) are present whenever the transformer is con-
nected to the network.
No Load Active NLA for transformer losses of active energy
Based on the IRMS and URMS values, the microprocessor generates the
following measured quantities:
OLA On load active. Line (copper) losses of active energy.
OLA = I2h x RCu. The value of RCu can be set by parameterisation.
NLA No load active. Transformer (iron) losses of active energy.
NLA = U2h / RFe. The value of RFe can be set by parameterisation.
I2h (Cu) Ampere square hours (with RCu = 1)
2
U h (Fe) Voltage square hours (with RFe 1 M)
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2.5.5 Summation channels
The values of two measurement quantities (incl. pulse inputs EX1 and EX2)
can be added.
Energy registers which contain the summation of two measured quantities
(summation channels) cannot be used for tariffication.
ME1
EX1
EX2
MExx
+ Total energy register
Figure 19 Summation channels
2.6 Data profile
A non-volatile memory (FLASH memory) contains the data of:
the stored value profile
the load profile 1
the load profile 2 (optional)
the event log
the three groups of dedicated event logs
The flash memory stores data without data loss in case of voltage failures.
No battery is required for this purpose.
The total size of the available memory for the stored billing value profile, the
load profile(s), the event log and the dedicated event logs is 1.8 MB.
2.6.1 Stored value profile
At the end of the billing period, the meter stores the current value of the
registers to the stored value profile. Which energy registers and/or demand
registers are stored to the stored billing value profile can be selected by
parameterisation.
Memory organisation The stored value profile is organised as a circular buffer, i.e. the oldest
entry will be overwritten by the most recent entry. The memory capacity
which is available for the stored value profile depends on parameterisation.
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2.6.2 Load profile 1 and load profile 2 (option)
The load profiles are used to save the values of various registers at regular
intervals. The measured values that are captured in the load profile can be
selected by parameterisation.
Load profile 2 is optional
The second load profile is optional.
Please consult your sales representative for further details.
Profile 1 The first load profile is generally used for billing purposes. Its capture
period has a range of 1...60 min. This load profile may also contain instan-
taneous values and detailed status information for data processing in cen-
tral stations.
Profile 2 The second load profile can be used to store instantaneous values over a
period which differs from the period of the first load profile. Apart from the
differing capture period, the second load profile is identical with the first
load profile.
Memory organisation The load profile is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry. The memory capacity which is availa-
ble for the load profile(s) depends on parameterisation. If both load profiles
are activated, they share the memory capacity which is allocated to the
load profile(s).
2.6.3 Event log
Events that occur sporadically are stored in the event log. The user may
select which events trigger an entry in the event log. The event log is used
to analyse the behaviour of the network as well as to supervise the correct
function of the meter.
Memory organisation In the event log, a maximum of 500 event entries can be stored. The indi-
vidual entries consist of the time stamp and the event number. Additional
information such as the error register or energy total registers can also be
stored with every event.
The event log is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry.
Dedicated event log Network quality events, can be stored in the dedicated event log. The
dedicated event log consists of three groups of logs.
Over-voltage events
Under-voltage events
Missing voltage events
In the dedicated event logs, important information can be stored per entry
such as:
duration of the events
extreme values of the events (not for missing voltage).
instantaneous values
maximum three energy registers
Additional information can be read from the header of the event logs, such
as the longest entry, the shortest entry, the total number of occurrence and
the total duration of the event.
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Memory organisation The dedicated event logs are organised as circular buffers, i.e. the oldest
entry will be overwritten by the most recent entry.
List of events The table below lists all events which can be captured in the event log.
Depending on the parameterisation, some events may never occur.
Events which can be stored in the dedicated event log are marked in the
corresponding column.
Number Event Entry in dedicated
event log possible
2 All energy registers cleared
3 Stored values and/or load profile cleared
4 Event log profile cleared
5 Battery voltage low
7 Battery ok
8 Billing period reset
9 Daylight saving time enabled or disabled
10 Clock adjusted (old time/date)
11 Clock adjusted (new time/date)
17 Under-voltage L1 x
18 Under-voltage L2 x
19 Under-voltage L3 x
20 Over-voltage L1 x
21 Over-voltage L2 x
22 Over-voltage L3 x
23 Power down
24 Power up
25 Over-current L1
26 Over-current L2
27 Over-current L3
28 Over-current neutral
31 Power factor monitor 1
32 Power factor monitor 2
33-40 Demand monitors 1-8
45 Error register cleared
49 Missing voltage L1 x
50 Missing voltage L2 x
51 Missing voltage L3 x
55 Current without voltage L1
56 Current without voltage L2
57 Current without voltage L3
58 Missing additional power supply
59 All registers and profiles cleared
63 Wrong phase sequence
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Number Event Entry in dedicated
event log possible
64 Correct phase sequence
66 Invalid clock
74 Backup memory access error
75 Measuring system access error
76 Time device access error
77 Load profile memory access error
79 Communication unit access error
80 Display board access error
81 Program checksum error
82 Backup data checksum error
83 Parameter checksum error
84 Load profile checksum error
85 Stored values checksum error
86 Event log checksum error
87 Calibration data checksum error
88 Load profile 2 checksum error
89 Invalid start-up sequence
93 Expired watchdog (general system error)
94 Communication locked
96 Wrong extension board identification
104 Count registers cleared
105 SMS delivery to GSM failed
106 Alert occurred
124 Compensation values changed
128 Energy total and rate register cleared
133 Terminal cover removed
134 DC Field detected ON
187 Terminal cover mounted
188 DC Field detected OFF
193 Load profile 2 cleared
211 Control input 1 set
212 Control input 1 reset
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2.7 Communication
The ZMD400xT meters have an optical interface for local communication
via a readout head and a wide range of communication interfaces which
can be inserted in the meter.
2.7.1 Optical interface
The optical interface to IEC 62056-21 is a serial, bi-directional interface. It
is situated at top right on the main face plate (see also section 3 "Mechani-
cal construction") and serves:
for automatic local data recording by means of a suitable acquisition
unit (hand-held terminal) (see section 5.7 "Data readout")
for performing service functions, e.g. to input formatted commands
(see section 5.8 "Input of formatted commands")
as "optical key", i.e. as receiver of a light signal, e.g. generated by a
flashlight acting like the "down" display key (see also section 5.2.2
"Control of display via optical interface")
for communication with a Landis+Gyr MAP110 service tool or a
Landis+Gyr MAP120 parameterisation tool.
2.7.2 Communication units
The communication units which can be inserted in the meter can be used:
for remote reading and for remote tariff control of meters (RS232,
RS485, CS, M-Bus, PSTN modem, GSM modem, GPRS modem,
Ethernet, etc.) or
for recording metering pulses for other physical media, such as
water, gas or heat (S0 interface).*
Access via the communication interfaces is protected for specific access
levels using the meter security system by means of passwords. If the moni-
toring is activated by corresponding parameterisation, communication is in-
hibited for a selected time (max. 24 h) after a selected number of password
attempts with an incorrect password (max. 15). Monitoring takes place in-
dependent of all access levels with password protection and for the IEC W5
password.
The communication devices are accommodated in an easily exchanged
communication unit, which is plugged in behind the front door of the meter
and secured by a utility seal (see also section 3 "Mechanical construction").
It can be fitted and removed at any time in the field without touching the
certification seal. Landis+Gyr recommend exchanging communication units
only if the meter is separated from the network and switched off.
An initial fitting as well as retrofitting without re-parameterisation of the
meters is possible with any version of communication unit. For fitting and
removal of the already parameterised communication units, the installation
personnel do not require any special knowledge of communications. Mod-
ern plug connections ensure a rapid and faultless connection of the com-
munication units.
* As well for the recording and the summation of metering pulses for other
electricity devices.
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Figure 20 Simple fitting of the communication unit
Versions of Communication units (CU) are available in various versions. The document
communication units "Overview of Communication Applications", D000011226 contains a list of
all currently available CU-interfaces with explanations.
Further information More detailed information about Landis+Gyr Dialog communication solu-
sources tions can be found in the following documents.
Technical data for the various communication units
User manuals for the various communication units
Detailed application notes for numerous reference applications with
various communication units for different transmission media:
– Point-to-point Connection with internal PSTN Modem Mx
(D000011505)
– Point-to-point Connection with internal GSM Modem Gx
(D000011506)
– etc.
All these documents as well as advisory services are available from
authorised Landis+Gyr representatives.
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2.8 MAP software tools
There are two software tools available for parameterisation of the E650
meter and for communication with the meter: .MAP110 and MAP120
Areas of application
Figure 21 Application of MAP software tools
.MAP110 The .MAP110 Service Tool covers the following applications normally
required for meter installation and in the service sector:
Billing data readout
Readout and export of profiles (load profile(s), stored values and event
log, dedicated event logs)
TOU (Time of Use) readout and modification
Billing period reset
Register and profile resets
Setting of certain parameter ranges, such as primary data, time switch,
communication parameters etc.
Communication input settings
Communication settings for Landis+Gyr communication units readout
and modification
GSM installation aid for Landis+Gyr communication units (field
strength indicators, telephone number information, PIN-code handling)
Test SMS message transmission
Analysis and diagnostic functions
MAP120 The Landis+Gyr MAP120 software is used to parameterise the meter and
the communication unit, i.e. it is possible to read out and modify all device
parameters.
In contrast to communication devices from other manufacturers, no additi-
onal software and training costs are incurred by the use of Landis+Gyr
communication units, since the MAP software tools support both meters
and communication units.
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2.9 Anti-tampering features
The following anti-tampering features are available for ZMD400xT meters:
DC magnet detection for the detection of strong magnetic fields close
to the meter. This feature is installed during the manufacturing proc-
ess.
Terminal cover detection for the detection of situations when the termi-
nal cover has been opened. This feature can be a retrofit or an inte-
grated version. The integrated version is available if the DC magnet
detection option is selected and must be integrated during manufac-
turing process.
Example of integrated terminal switch available from mid-2012.
2.9.1 DC magnet detection
The meters ZxD410xT, ZxD405xT and ZxD402CT can be ordered with a
feature which detects strong DC magnetic fields. When a magnetic field is
present, event 134 is set; when the magnetic field disappears, event 188 is
set. These events can e.g. be entered into the event log with date and time.
The meter’s type description informs you whether this feature has been
implemented (see page 10).
With the DC magnet detection, it is possible to order the integrated terminal
cover detection option.
2.9.2 Terminal cover detection
Installed ZMD400 meters can be equipped with a terminal cover detection
unit. For this, they need to be parameterised and the unit – consisting of a
switch which detects the removal of the terminal cover – has to be installed.
Whenever the retrofit terminal cover is removed, it detects the switch status
change via control input 1 and enters event 211 in the event log with date
and time. When the terminal cover is mounted again, event 212 is entered
in the event log with date and time.
Please order terminal cover detection units – part number 74 766 0163 0
(minimum order quantity 10) – from:
Landis+Gyr AG
Service & Repair
Theilerstrasse 1
CH-6301 Zug
Switzerland
For installation of the unit see section 4.6 "Installation of terminal cover
detection".
In case of the integrated terminal switch used, the event 133 is set when
the terminal cover is removed and event 187 when the terminal cover is
mounted.
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3 Mechanical construction
This section describes the mechanical construction of the ZxD400xT meter
and shows the most common connection diagrams.
3.1 Housing
The internal construction of the meters is not described here, since they are
protected following calibration and official certification on delivery by a
manufacturer and certification seal. It is not permitted to open the meters
after delivery. The front door is only secured with a utility seal and can be
opened to operate the reset key, to change the battery, to exchange the
tariff face plate with connection diagram or to fit or remove a communica-
tion unit (see figure 23 and separate user manuals for the communication
units available).
The following drawing shows the meter components visible from outside.
Figure 22 Meter ZxD400xT
1 Combined suspension hanger 10 Display key "down"
(open or concealed)
2 Screw with manufacturer seal 11 Front door tariff face plate
3 Optical test output reactive 12 Upper part of case
energy consumption (red),
ZxD400CT only
4 Optical test output active energy 13 Lower part of case
consumption (red)
5 Liquid crystal display (LCD) 14 Utility seal for front door
6 Optical interface 15 Terminal cover
7 Screw with certification seal 16 Terminal cover screws with utility
seals
8 Front section with main face plate 17 Alert LED (optional)
9 Display key "up"
Case The meter case is made of antistatic plastic (polycarbonate). The upper
part of the case is provided with two transparent plastic viewing windows,
affording a view of the main face plate (top) and the tariff face plate (bot-
tom). The lower part of the case is additionally glass-fibre reinforced.
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Viewing window The upper viewing window with the main face plate is secured on the upper
right side with a certification seal, while the upper part of the case is secu-
red on the upper left side with a manufacturer seal (warranty) or a second
certification seal.
The lower viewing window is in the form of a hinged front door, secured
with an utility seal. The tariff face plate with the connection diagram on the
rear side, the battery compartment, the reset key and (if present) the com-
munication unit are situated behind this front door.
Terminal cover The terminal cover is available in various lengths in order to ensure the
required free space for the connections.
Front door The front door must be opened to give access to the battery compartment,
reset key and tariff face plate. To fit or remove the communication unit the
terminal cover must also be removed.
Figure 23 Meter with front door open
1 Battery compartment
2 Reset key R
3 Communication unit or dummy
Figure 24 Meter with communication unit withdrawn
If the meter has no communication unit, this is replaced by a dummy case.
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Seal component An additional component, which is easy to install, allows the use of a stan-
dard padlock instead of a utility seal.
Figure 25 Front door sealing using a padlock
The seal component is stowed away in a holder under the front door when
not in use.
Figure 26 Stowage of seal component when not in use
The seal component is installed as follows:
Slide the seal component into the vertical slot at an angle, as shown,
(position 1) until it contacts the rear wall.
Now turn the seal component until it is horizontal and slide it down into
position 2 as illustrated. The two bulges firmly fix the seal component
into the lateral grooves.
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Figure 27 Seal component for use with padlock
3.2 Face plates
All relevant data for the meter are provided on the face plates inscribed
according to customer specifications.
Main face plate The main face plate is situated behind the plastic viewing window, which is
secured by a certification seal. Recesses permit operation of the display
keys "down" and "up" for control of the liquid crystal display.
1 2 3
Landis+Gyr E650
Readout
imp imp
13 Cl. 1
kvarh
1000
kWh
Cl. 1 4
Three-phase four-wire meter
12 ZMD410CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 5(10) A 50 Hz 5
20XX
6
11 7
10 8
9 T1 T2 T3 SET Test
Figure 28 Main face plate (example ZMD410CT)
1 Optical test output reactive energy
(with accuracy class – ZxD400CT only)
2 Meter constant R1 (referred to primary values) or R2
3 Optical test output active energy (with accuracy class)
4 Optical interface
5 Approval symbol
6 Type of connection
7 Display key "up"/Display key "down"
8 Symbol for double protective insulation
9 Status indication
10 Arrows for present status indication
11 Liquid crystal display (LCD)
12 Meter data (type designation, serial number, rated values, year of
construction)
13 Alert LED (optional)
The operating elements and displays are described more detailed in
section 5 "Operation".
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Tariff face plate The tariff face plate is placed in the front door, which can be swung out
sideways to the left and is secured by a utility seal. The connection diagram
of the meter is shown on the back of the face plate and is therefore visible
with the front door open.
Figure 29 Tariff face plate (example ZxD400CT)
1 General data appearing in the display
2 Measured quantities
3 Pulse input data
4 Output contact data
5 Ownership designation
6 Transformer data and readout factor
7 Communication unit data (if present)
3.3 Connections
Figure 30 Meter with terminal cover removed
The terminal block with all meter connections is situated behind the termi-
nal cover. Two utility seals in the fixing screws of the terminal cover prevent
unauthorised access to the phase connections and therefore also prevent
unrecorded energy consumption.
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Terminal layout The top row of terminals (level 1) consists of spring-loaded terminals and
(example ZMD400xT) comprises
Extension board terminals on the left
Depending on the version, up to 4 control inputs or 6 output contacts, 3
digital inputs and 2 relays outputs or a combination of these with maxi-
mum 6 inputs and outputs, or voltage connections for a separate supply.
Communication unit terminals on the right
The centre row of terminals (level 0) likewise consists of spring-loaded ter-
minals and comprises:
Voltage outputs U1, U2, U3 and N, tapped from the relevant phase input
3 fixed control inputs with a common return line G (electrically isolated)
2 output contacts for transferring fixed valency pulses or control
signals (electrically isolated)
The lower row of terminals comprises the phase connections with input and
output of the circuit for each phase with the voltage connection in between
and neutral conductor.
Figure 31 Terminal layout ZMD400xT according to DIN
Apart from the common terminal layout according to DIN the ZMD400
meters are also available optionally with symmetrical terminal layout.
Figure 32 Symmetrical terminal layout ZMD400xT
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3.4 Connection diagrams (examples)
Binding connection diagrams
The following connection diagrams should be considered examples. The
connection diagrams provided at the rear of the front door and visible when
the door is open are always binding for the installation.
ZFD400xT
for three-phase
three-wire networks
Figure 33 Connection diagram of measuring unit ZFD400xT with current
transformer
Figure 34 Connection diagram of measuring unit ZFD400xT with current and
voltage transformers
Symmetrical terminal layout
The version with symmetrical terminal layout (option) is available only for
ZMD400 meters for three-phase four-wire networks.
Artificial star point
* With the three-wire circuit, the artificial star point (terminal 11) must not be
externally wired.
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ZMD400xT
for three-phase
four-wire networks
Figure 35 Connection diagram of measuring unit ZMD400xT with current
transformer (terminal layout according to DIN)
Figure 36 Connection diagram of measuring unit ZMD400xT with current
transformer (symmetrical terminal layout)
Figure 37 Connection diagram of measuring unit ZMD400xT with current and
voltage transformers (terminal layout according to DIN)
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Control inputs / Basic version:
output contacts 3 control inputs
2 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 38 Connection diagram fixed control inputs/output contacts
Extension board Extension board 4200:
4200 4 control inputs
2 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 39 Connection diagram extension board with 4 control inputs and 2 output
contacts
Extension board Extension board 2400:
2400 2 control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 40 Connection diagram extension board with 2 control inputs and 4 output
contacts
Extension board Extension board 0600:
0600 no control inputs
6 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 41 Connection diagram extension board with 6 output contacts
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Extension board Extension board 0450:
0450 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 42 Connection diagram extension board with auxiliary power supply and 4
output contacts
Extension board Extension board 0460:
0460 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 43 Connection diagram extension board with auxiliary power supply and 4
output contacts
Extension board Extension board 3260:
3260 with auxiliary power supply
3 control inputs
2 relay outputs (8 A)
G + - Signal allocation and numbering of
terminals for free parameterisation
50 51 52 53 15 16 17 18 61 64
Figure 44 Connection diagram extension board with auxiliary power supply,
3 control inputs and 2 relay outputs
Ground terminal connection
Please note that the Ground terminal (G) of the control inputs on the
extension boards is NOT internally connected to the Ground terminal on the
base. If the Ground level is the same, then an external wire must be
connected between the two Ground terminals.
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3.5 Dimensions
6.2 75
extended hook: 230
extended hook: 305.5
standard hook: 206
standard hook: 281.5
190
26
40
150
177 75
Figure 45 Meter dimensions (Standard terminal cover)
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4 Installation and de-installation
This section describes the installation and connection of meters for trans-
former connection. In addition, the necessary steps for checking the con-
nections, commissioning of the meter and the final functional check are
described as well as the de-installation.
Dangerous voltage
Dangers can arise from live electrical installations to which the meters are
connected. Touching live parts is dangerous to life. All safety information
should therefore be strictly observed without fail.
4.1 Basic information for connecting meter
It is recommended to use the following circuits whenever possible for con-
necting the meter to the various voltage levels.
Terminal layout
In the following illustrations the terminal layout is shown according to DIN.
For the version with symmetrical terminal layout, which is optionally avail-
able for ZMD400 meters for three-phase four-wire networks, the different
terminal numbers according to the connection diagram must be observed.
4.1.1 Connection to low voltage with current transformers
Figure 46 Connection to low voltage with current transformers
Test terminal block The secondary circuit of a current transformer must always be closed when
current is flowing in the primary. Opening of the secondary circuit can de-
stroy the transformer. The test terminal block shown in figure 46 allows the
secondary circuits to be short-circuited and the voltage circuits to be opened
in order to exchange the meter without interrupting operation.
Preliminary fuses The preliminary (supply) fuses in the voltage circuit (max. 10 A) protect
against short-circuits in the measuring circuit. The voltage circuits are con-
nected directly to the primary and would only be protected by the main
fuses of 100 A or more if the preliminary fuses were not fitted. A short-cir-
cuit would certainly destroy the measuring device and cause fire and other
damage.
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4.1.2 Connection to medium and high voltage (Aron circuit)
This circuit is used above all in the medium voltage range (3 to 30 kV) and
rarely with high voltage (from 30 kV).
It is also recommended here to insert a test terminal block between trans-
former and measuring device (meters and others). This permits simple ex-
change without interrupting operation. On the other hand, no preliminary
supply fuses are necessary in the voltage circuits, since the voltage trans-
formers cannot produce a high short-circuit capacity on the secondary side.
Grounding On medium and high voltage the secondary side of all voltage transformers
should be grounded for safety reasons. Otherwise potentials could develop,
which could result in dangerous contact voltages.
Grounding
All following drawings can be used without potential transformers but in any
cases fuses must protect the voltage lines (see section 4.1.1). Then ground-
ing neutral meter point isn’t required.
Three-phase
three-wire meter
Figure 47 Connection to medium and high voltage (Aron circuit)
Instead of the three-phase three-wire meter ZFD400 the power supply
company can also use a three-phase four-wire meter ZMD400. The
following two connections are then possible:
with 2 voltage transformers and open star point at the meter
with 3 voltage transformers and star point connected at the meter
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Three-phase four-wire
meter (with open star
point at meter)
Figure 48 Connection to medium and high voltage
four-wire meter with open star point
Three-phase four-wire
meter (with star point
connected at meter)
Figure 49 Connection to medium and high voltage
four-wire meter with star point connected
4.1.3 Connection to medium and high voltage (three-phase four-wire circuit)
This circuit is mainly used with high voltage (from 30 kV). The same condi-
tions then apply as for the Aron circuit.
Figure 50 Connection to medium and high voltage (three-phase four-wire circuit)
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4.2 Mounting the meter
Dangerous voltage on conductors
The connecting conductors at the point of installation must be voltage-free
for installation of the meter. Contact with live components is dangerous to
life. The relevant supply fuses should therefore be removed and kept in a
safe place until finishing work, so that they cannot be re-inserted by other
persons unnoticed.
The jumpers in the voltage connections must also be opened at the test
terminal block (e.g. TVS14). For this purpose, release the screw of the
relevant jumper with an insulated screwdriver, move the jumper away from
the terminal on the meter side and then re-tighten the screw.
If no test terminal block is available, the primary voltage must be inter-
rupted, i.e. the system switched off.
Dangerous voltage on current transformers
The current transformer secondary circuits must not be opened when cur-
rent is flowing in the primary. This would produce a dangerous voltage at
the terminals of several thousand volts and the insulation of the transformer
would be destroyed.
To install the meter, short-circuit the secondary of the current transformer at
the test terminal block (e.g. TVS14). For this purpose, release the screw of
the relevant short-circuiting jumper with an insulated screwdriver, move the
jumper away over the terminals on the meter side and then re-tighten the
screw. The circuit on the meter side can then be opened without danger.
If no test terminal block is available, the primary voltage must be inter-
rupted, i.e. the system switched off.
When you have identified the correct meter position for mounting the meter,
it should be mounted as follows on the meter board or similar device pro-
vided for this purpose:
1. Determine the desired form of fixing (open/covered meter mounting or
extended suspension hook for 230 mm suspension triangle height). If
holes for a suspension triangle height of 230 mm are already present,
use the optional extended suspension hook depicted below. This
hook can be ordered with the part number 74 109 0072 0 (minimum
order quantity 50) from:
Landis+Gyr AG
Service & Repair
Theilerstrasse 1
CH-6301 Zug
Switzerland
Figure 51 Extended suspension hook
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2. Either set the meter suspension hook in the relevant position as shown
below or replace the suspension hook with the extended hook by lifting
the latch slightly and pulling out the shorter hook. Insert the extended
hook into the grooves in the same way the shorter hook was inserted
(bent towards rear) and push it down until it clicks into place.
Figure 52 Positioning of meter suspension eyelet
3. Check with a phase tester or universal measuring instrument whether
the connecting wires are live. If so, remove the corresponding supply
fuses and keep them in a safe place until installation is completed, so
that they cannot be replaced by anyone unnoticed. Open the voltage
connections at the test terminal block with an insulated screwdriver
and check whether the short-circuit jumpers of the circuit are closed.
4. In case there are no holes provided, e.g. as in the case with the
230 mm suspension triangle: Mark the three fixing points (suspension
triangle as in following illustration) on the mounting surface provided:
– horizontal base of suspension triangle = 150 mm
– height of suspension triangle for open mounting = 206 mm
– height of suspension triangle for covered mounting = 190 mm
206 or 190 mm respectively
75 mm
150 mm
Figure 53 Drilling plan
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5. Drill the three holes for the fixing screws.
6. Unscrew the meter terminal cover.
7. Fit the meter with the three fixing screws on the mounting surface pro-
vided.
4.3 Connecting meter
Dangerous voltage on conductors
The connecting conductors at the point of installation must be voltage-free
for installation of the meter. Contact with live components is dangerous to
life. The relevant supply fuses should therefore be removed and kept in a
safe place until finishing work, so that they cannot be re-inserted by other
persons unnoticed.
The jumpers in the voltage connections must also be opened at the test
terminal block (e.g. TVS14). For this purpose release the screw of the rele-
vant jumper with an insulated screwdriver, move the jumper away from the
terminal on the meter side and then re-tighten the screw.
If no test terminal block is available, the primary voltage must be inter-
rupted, i.e. the system switched off.
Dangerous voltage on current transformers
The current transformer secondary circuits must not be opened when cur-
rent is flowing in the primary. This would produce a dangerous voltage at
the terminals of several thousand volts and the insulation of the transformer
would be destroyed.
To install the meter, short-circuit the secondary of the current transformer to
the test terminal block (e.g. TVS14). For this purpose release the screw of
the relevant short-circuiting jumper with an insulated screwdriver, move the
jumper away over the terminals on the meter side and then re-tighten the
screw. The circuit on the meter side can then be opened without danger.
If no test terminal block is available, the primary voltage must be inter-
rupted, i.e. the system switched off.
Preliminary work It is assumed that the transformers and test terminal blocks have already
been correctly fitted, the current transformers are short-circuited and the
voltage connections opened.
Grounding
When using voltage transformers, the secondary star-point (or centre point
in Aron circuit) of the transformer is grounded. The secondary circuits of the
current transformers are also earthed one side (connection k).
Preliminary supply fuses must be used with direct voltage connection. The
current transformers must not be earthed on the secondary side in this
case, see connection diagram.
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Figure 54 Test terminal block status before installing the meter (terminal layout
according to DIN)
Connecting The electrical connections to the meter should be made as follows accord-
ing to the connection diagram:
1. Check whether the preliminary work described above has been per-
formed. If not, complete this work (test terminal blocks should only be
touched with an insulated screwdriver).
2. Check with a phase tester or universal measuring instrument whether
the connecting wires are live. If so, remove the corresponding supply
fuses and keep them in a safe place until installation is completed, so
that they cannot be replaced by anyone unnoticed.
Connecting the phase connection lines
1. Shorten the phase connecting wires to the required length and then
strip them.
2. Insert the phase connecting wires in the relevant terminals (the termi-
nals are numbered as shown in the connection diagram) and tighten
the terminal screws firmly (torque 1.7 Nm).
It is recommended to identify the beginning and end of the relevant
conductors with a suitable test unit (e.g. buzzer) to ensure that the
right consumer is connected to the meter output.
Figure 55 Meter connections (example ZMD400xT, terminal layout according to DIN)
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Artificial star point
With the three-wire circuit the artificial star point (terminal 11) must not be
externally wired.
Connecting the signal inputs and outputs
Maximum current at auxiliary terminals
The circuits connected to the auxiliary terminals must be built in such a way
that the maximum current is never exceeded, as this might damage the meter.
Maximum current of the voltage outputs: 1 A.
Maximum current of the output contacts: 100 mA.
Use fuses or protective relays between external and internal circuits to
avoid defects and a possible exchange of the meter.
1. Shorten the connecting wires of the signal inputs and outputs to the re-
quired length and strip them for approx. 4 mm (wires and strands up to
2.5 mm² can be connected).
Use ferrules with stranded wires
If stranded wire is used, provide it with ferrules for connection.
2. Connect the connecting wires of the signal inputs and outputs as fol-
lows to the screwless spring-loaded terminals (the terminals are num-
bered as shown on the connection diagram):
– Insert a size 1 screwdriver in the upper opening and insert it turning
slightly upwards (figure 56 A).
– Now place the stripped connecting wire in the lower opening and
hold it there securely (figure 56 B).
– Withdraw the screwdriver. The connecting wire is then firmly fixed
(figure 56 C).
Figure 56 Connection in screwless spring-loaded terminals
Bare end of connecting wire must not be too long
The insulation of the connecting line must extend as far as the terminal
indentation, i.e. there must be no further bare part of the connecting line
visible above the terminal edge (as shown in figure 56 C). Touching live
parts is dangerous to life. The stripped part of the connecting wire should
be shortened if necessary.
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Only one wire or ferrule per terminal
Only one wire or ferrule with strand(s) may be connected in screwless
spring-loaded terminals. The terminal could otherwise be damaged or the
contact not properly made.
If a connecting wire must be disconnected again for any reason, this is
performed in the reverse sequence:
Figure 57 Releasing connection from spring-loaded terminal
Damage to terminals
Never withdraw connecting wires with the terminal closed, since this could
damage the terminal.
4.3.1 Connecting the R-S485 interface
If you connect the RS485 interface you must not strip back the shielded ca-
bles, e.g. to connect the individual wires to an external terminal block (see
figure below), as this considerably increases the likelihood of interference.
Figure 58 How to connect RS485 correctly
It is also possible to use RS485 distributors instead of connecting the
RS485 cables directly to the meter.
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4.4 Check of connections
Effects of connection errors
Only a properly connected meter measures correctly!
Every connection error results in a financial loss for the power company!
Before putting into operation, check again whether all meter connections
are connected correctly according to the connection diagram.
4.5 Commissioning, functional check and sealing
Dangerous voltage on conductors
The supply fuses must be re-inserted or the jumpers of the voltage circuits
in the test terminal block re-closed before commissioning and functional
check of the meter.
If the terminal cover is not screwed tight, there is a danger of contact with
the connection terminals. Contact with live components is dangerous to life.
The relevant supply fuses should therefore be removed before making any
modifications to the installation and these kept in a safe place until com-
pleting the work to prevent anyone re-inserting them unnoticed. The jump-
ers in the test terminal block of the voltage circuits should again be opened
and secured.
Dangerous voltage on current transformers
The current transformer circuits must be closed before commissioning and
functional check of the meter. Opening the jumpers short-circuiting the sec-
ondary sides of the transformers permit the transformer current to flow
through the meter. Opening of the short-circuit jumper must never interrupt
the circuit.
Prerequisites for commissioning and functional check
The functional check requires voltage to be applied and load applied to all
phases. If export is possible, determine first the energy direction present.
If no network voltage is present, commissioning and functional check must
be performed at a later date.
Via the test terminal blocks you can also supply the meter from suitable
auxiliary sources on the secondary side with the system switched off.
Repeat the functional check later with the system switched on.
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The installed meter should be put into service and checked as follows:
1. Close the jumpers of the voltage paths in the test terminal block with
an insulated screwdriver and re-insert the supply fuses.
2. Check on the display whether all three phases L1, L2 and L3 are indi-
cated and show the right phase sequence.
– If one phase is not present or less than 20 V, then the relevant
symbol is absent.
– With the normal phase sequence L1-L2-L3 the symbols are
displayed continuously.
– If, however, the meter is connected with reversed phase sequence
(e.g. L2-L1-L3) the symbols flash. The direction of field rotation
(clockwise or anticlockwise) is determined by the parameterisation.
This has no influence, however, on the measuring behaviour of the
meter.
Figure 59 Phase sequence indication
3. Open the short-circuit jumper of phase 1 in the test terminal block with
an insulated screwdriver.
4. Check the display of the energy direction: +P to right, +Q up with
inductive load.
5. Close the short-circuit jumper of phase 1 in the test terminal block
again with an insulated screwdriver.
6. Repeat the same test for the other phases as in points 3 to 5.
7. Then open the short-circuit jumpers of all phases in the test terminal
block with an insulated screwdriver.
Figure 60 Test terminal blocks status after commissioning (terminal layout
according to DIN)
8. Check whether the operating display appears correctly (no error
message).
9. Further values can be checked in the service list obtained via the
service menu if parameterised: phase voltages, angles, currents, etc.
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10. Check the tariff displays and switch the control voltages to the tariff
inputs on and off. The arrow symbols of the tariff display must change.
11. If the meter is connected to a meter readout system via the electrical
interface, a check should be made of correct functioning of the data
transmission.
12. If a GSM modem is connected to the meter, the SMS transmission
function should be checked by sending a test SMS message, e.g. to
your own mobile telephone.
13. Mount the terminal cover if the meter is operating correctly. Otherwise
first locate and eliminate the error.
14. Seal the terminal cover with two utility seals.
15. Set the current date and time with the relevant formatted command
(see section 5.8 "Input of formatted commands") or in the set mode
(see section 5.9 "Set time and date, ID numbers, battery time).
16. Close the front door.
17. Re-seal the front door.
4.6 Installation of terminal cover detection
1. Ensure that control input 1 has been parameterised for this function.
2. Connect cables 1 and 2 to terminal according to the figure below.
1
3 2
Figure 61 Connection of cables of cover detection unit
3. Fix terminal cover detection unit to meter. See figure below.
Figure 62 Fixing of cover detection unit to meter
4. Connect cable 3 as shown above.
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4.7 De-installation
Dangerous voltage on conductors
The connecting conductors must be free from voltage when the meter is
removed. It is dangerous to life to touch live parts. Remove the corre-
sponding supply fuses and ensure that they cannot be re-inserted by any-
one unnoticed before completing the work.
If the meter is connected via voltage transformers, it must be possible to
open the test terminal (e.g. TVS14). For this purpose release the screw of
the relevant jumper with an insulated screwdriver, push the jumper away
from the terminal and then re-tighten the screw.
If there is no test terminal block, the primary voltage must be interrupted,
i.e. the system switched off.
Dangerous voltage on current transformers
The secondary sides of the current transformer circuits must not be opened
if a current is flowing in the primary. This would produce an extremely high
voltage of several thousand volts dangerous to life at the terminals and the
insulation would be destroyed.
Short-circuit the current transformer at the test terminal block (e.g. TVS14)
to remove the meter. For this purpose release the screw of the relevant
short-circuit jumper with an insulated screwdriver, push the short-circuit
jumper over the terminals on the current transformer side and then retigh-
ten the screw. The circuit on the meter side can then be opened without
danger.
If there is no test terminal block, the primary voltage must be interrupted,
i.e. the system switched off.
The meter should be removed as follows:
1. Short-circuit the current transformer with the short-circuit jumpers in
the test terminal block using an insulated screwdriver and interrupt the
voltage connections with the jumpers in the test terminal block.
2. Remove the two utility seals at the screws of the terminal cover.
3. Release the two screws of the terminal cover and remove it.
4. Check that the connecting wires are not live using a phase tester or
universal measuring instrument. If not, check the condition of the test
terminals again according to figure 63. Remove the relevant supply
fuses if necessary and ensure that they cannot be re-inserted by
anyone unnoticed before completing the installation.
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Figure 63 Condition of test terminal block before removing meter (terminal
layout according to DIN)
5. Remove the connecting wires of the signal inputs and outputs from the
screwless spring-loaded terminals as follows:
– Place a size 1 screwdriver in the upper opening and insert it turning
slightly upwards (figure 64 A).
– Then draw the wire from the lower opening (figure 64 B).
– Withdraw the screwdriver (figure 64 C).
Figure 64 Removing connections in screwless spring-loaded terminals
Damage to terminals
Never withdraw connecting wires from closed terminals. The terminals
could be damaged.
6. Release the terminal screws 1 to 11 of the phase connecting wires
with a suitable screwdriver and withdraw the phase connecting wires
from the terminals.
7. Fit a substitute meter as described in section 4.3 "Connecting meter"
and the following sections.
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5 Operation
This section describes the appearance, layout and function of all operating
elements and displays of the ZxD400xT meters as well as operating se-
quences.
Illustrations
The illustrations of the face plate and display in this section always show
the ZxD400CT combi-meter (with additional optical test output for reactive
energy, together with direction of reactive power and quadrant display).
5.1 Operation with auxiliary power supply
Meters equipped with an auxiliary power supply which is supplied with
electricity (see section 3.4 "Connection diagrams (examples)") are com-
pletely functional even in case of a power cut. Despite missing voltage at
the terminals they can be read out via display, remote readout etc. and
parameterised, if desired.
Connect the auxiliary power supply as follows:
1 2 3 4
Figure 65 Auxiliary power supply connections
Type 045x: 1 and 2: 100–240 V AC/DC
Type 046x: 1: + (12–24 V DC)
Type 046x: 2: – (12–24 V DC)
Type 326x: 3: + (12–24 V DC)
Type 326x: 4: – (12–24 V DC)
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5.2 Control elements
E650 meters have the two display keys "down" and "up" and a reset key as
conventional operating elements. The display can also be controlled with
the aid of a light source via the optical interface.
5.2.1 Display keys
The two display keys "down" and "up" are placed on the main face plate
(top) on the right of the liquid crystal display.
Landis+Gyr E650
Readout
imp imp Cl. 1
Cl. 1 kvarh
1000 kWh
Three-phase four-wire meter
ZMD410CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 5(10) A 50 Hz
20XX
Display key
"up"
Display key
"down"
T1 T2 T3 SET Test
Figure 66 Display keys
By pressing the lower display key "down", the display changes to the next
value in the list. By pressing the upper display key "up", the display changes
to the previous value (see also section 5.4.2 "Display menu").
5.2.2 Control of display via optical interface
All E650 meters have an "optical key" in addition to the "up" and "down"
display keys. The optical interface serves to receive a light signal, e.g.
generated by a torch (works only with warm light, i.e. LED torches cannot
be used for this). The light signal acts like the "down" display key and
controls the display in one direction from one value to the next. This type of
display control only functions when voltage is supplied to the meter.
The reader can also control the display at a distance from the meter de-
pending on the light intensity from the source, e.g. through a protective
glass in front of the meter.
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5.2.3 Reset key
The reset key is situated to the right of the battery compartment behind the
front door. To permit operation of the reset key the front door must be
opened and therefore the utility seal be removed.
The reset key can be used to perform a manual reset. If the display check
is displayed (after operation of a display key), however, pressing of the
reset key produces the service menu (see also section 5.4.3 "Service
menu").
Figure 67 Reset key behind front door
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5.3 Display
5.3.1 Introduction
E650 meters are provided with a liquid crystal display (LCD).
The display can be provided with background lighting for easier reading
(optional). This is switched on by pressing one of the display keys and is
extinguished automatically after a short time if no further key is pressed.
5.3.2 Basic layout
The basic layout shows all the indication possibilities of the display.
Figure 68 Basic layout of the liquid crystal display (LCD)
1 Active power direction (+P: import, -P: export)
2 Reactive power direction (not used with ZMD400AT)
3 Phase voltages (flash if rotating field reversed)
4 Battery status (charge voltage)
5 Units field
6 Index field (8 digits)
7 Value field (8 digits)
8 12 arrow symbols for status information (e.g. tariffs)
Active power direction Shows always the sum of the three phases:
positive active energy direction (imported from power
company)
negative active energy direction (exported to power
company)
negative active energy direction of individual phases
(second arrow flashes).
Reactive power Indicates for combi-meters ZMD400CT always the sum of the three phases (not
direction used for active energy meters ZMD400AT).
positive reactive energy direction
negative reactive energy direction
Quadrant display Indicates for combi-meters ZMD400CT in which quadrants the present
measurement is made (not used for active energy meters ZMD400AT):
1st quadrant
2nd quadrant
3rd quadrant
4th quadrant
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Phase voltages Indication of presence of phase voltages.
If the rotating field corresponds to the parameterised,
symbols L1, L2 and L3 are continuously lit. Otherwise
they flash every second.
Battery condition The symbol appears if the charge voltage of the battery
fitted is too low (provided the meter is parameterised as
"fitted with battery").
Units field The following units are shown:
W, var, VA, k..., M..., ...h, V, A, h, Hz, m³
(var and VA only for combi-meters)
Index field Up to 8-digit indices are displayed, which define
the value in the value field.
Value field Up to 8-digit values are displayed.
Arrow symbols An arrow symbol is an additional status indication for tariff
rates, reset block, test mode, etc. The arrow points to a
status description on the face plate.
5.3.3 Index system
The information concerning which data are shown in the display is made
with an index system and is supported by the unit over the value field.
The 8-digit index field permits all currently known index systems such as
DIN, LG, VEOe, OBIS, etc.
The B:C.D.E.F structure applies to OBIS (Object Identification System):
B Defines the channel number, i.e. the number of the input of a metering
device having several inputs for the measurement of energy of the
same or different types (e.g. in data concentrators, registration units).
This enables data from different sources to be identified.
C Defines the abstract or physical data items related to the information
source concerned, e.g. active power, reactive power, apparent power,
cosφ, current or voltage.
D Defines types, or the result of the processing of physical quantities
according to various specific algorithms. The algorithms can deliver
energy and demand quantities as well as other physical quantities.
E Defines the further processing of measurement results to tariff regis-
ters, according to the tariff rates in use. For abstract data or for meas-
urement results for which tariffs are not relevant, this value group can
be used for further classification.
F Defines the storage of data according to different billing periods. Where
this is not relevant, this value group can be used for further classification.
To simplify reading of the index field, individual parts of the OBIS code can
be omitted. The abstract or physical data C and type of data D must be
shown.
For further details about OBIS code see Appendix 1.
Examples 1.8.0: 1 = Active energy import (all phases); 8 = Status; 0 = Total
0.9.1: Local time
Reference is made for examples to the following display list and the read-
out log (see section 5.7 "Data readout").
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5.4 Types of display
The ZxD400xT has the following three types of display:
Operating display The values specified by the parameterisation are shown as a rolling display
in the operating display. The display is always in operating mode when the
display keys are not operated. The meter returns automatically from the
display list to the operating display after a defined time. This display can
consist of one or more values.
Display menu By pressing the display key, the display check is activated, and from there
the user reaches the display menu by pressing the display key again. From
the display menu, values of the display list, the load profile(s), the event log
etc. can be accessed. The values of the display list and also the sequence
can be parameterised. The display keys permit scrolling up and down in the
list.
Service menu The user reaches the service menu by pressing the reset key starting from
the display check. From the service menu, values of the service list, the set
mode etc. can be accessed. The service list, for example, is an extended
display list with additional values.
5.4.1 Operating display
The values always displayed are considered the operating display. This can
be parameterised as a fixed display (only one value present, e.g. the pre-
sent tariff rate) or as a rolling display (several values alternate at a fixed
rate, e.g. every 15 seconds).
running average demand
with status of integrating
period
Figure 69 Example of a fixed display
Error message The meter can generate an error message on the basis of self-tests.
According to parameterisation, this can be permanently included in the
operating display. In the event of a serious error (fatal or critical error), it
replaces the normal operating display. After a fatal error, the meter no
longer operates and must be replaced. In case of a critical error, the error
message can be acknowledged with the display key.
Figure 70 Example of an error message (insufficient battery voltage)
In case of an error message the procedure described in section 6.2 "Data
readout" should be followed.
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5.4.2 Display menu
Figure 71 Display menu overview
Display check Brief operation (< 2s) of the display key "down" or "up" causes a change of
the operating display, e.g.:
to the display check:
All segments of the display are active here. The index and value fields
should be checked each time for missing segments. This can prevent
incorrect readings.
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Display menu Pressing the display key "down" or "up" again briefly, changes to the dis-
play menu or directly to the display list. The first menu item appears, e.g.
"Display list" (standard data):
The menu item only appears when several menu items exist. Otherwise
direct entry is made to the display list.
The next menu item appears for every further brief operation of the "down"
display key, e.g. "Data profile", "Event log" etc. The first menu item appears
again after the last item.
The preceding menu item is displayed again by briefly pressing the "up"
display key.
Both display keys ("down" and "up") must be pressed simultaneously to
return to the operating display from any display menu.
Value display The first value of the list associated with the present menu is displayed by
pressing the display key "down" or "up" for longer (at least 2 seconds), and
is normally the error message:
The next list value appears for every further brief operation of the "down"
display key. Brief operation of the "up" key again displays the preceding
value. The sequence of values in the list is determined by the parameter-
isation.
A rapid run is started by holding down the display key "down" or "up" for
longer (at least 2 seconds). The main values of the list are then displayed
while the key remains pressed, but no stored values.
Examples of values in a display list:
Reset counter
Date of resetting
stored value 03 (March)
Cumulated maximum
demand
active power
rate 1
Active energy
present status
rate 1
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Reactive energy
present status
rate 1
Battery hours counter
Status of signals at
control terminals
Number of total voltage
failures
To return to the menu level from the list at the end of the display list press
the display key "down" or "up" for longer (at least 2 seconds).
Load profile 1 The load profile 1 menu item for selection in the display menu (denoted
P.01) is shown as follows:
The first value of the load profile 1 is displayed by pressing the display key
"down" or "up" for longer (at least 2 seconds).
Load profile 2 The load profile 2 menu item for selection in the display menu (denoted
P.02) is shown as follows:
The first value of the load profile 2 is displayed by pressing the display key
"down" or "up" for longer (at least 2 seconds).
Event log The event log menu item for selection in the display menu (denoted P.98)
is shown as follows:
The first entry in the event log is displayed by pressing the display key
"down" or "up" for longer (at least 2 seconds).
Losses The losses menu item for selection in the display menu is shown as
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follows:
The first losses value is displayed by pressing the display key "down" or
"up" for longer (at least 2 seconds).
5.4.3 Service menu
Figure 72 Service menu overview
Service menu Pressing the reset key during the display check changes the display to the
service menu or directly to the service list. The first menu item appears,
e.g. the service list:
The menu item only appears if there are several items present. Otherwise
pressing the reset key directly leads to the values of the service list.
The next menu item appears for every further brief operation of the "down"
display key, e.g. "Set mode", "Test mode on/off", etc. The first item appears
again following the last menu item "End".
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The preceding menu item appears again by pressing the "up" key briefly.
Both display keys ("down" and "up") must be pressed simultaneously to
return to the operating display from the service menu.
Value display The first value of the list associated with the present menu is displayed by
pressing the display key "down" or "up" for longer (at least 2 seconds).
The next list value appears for every further brief operation of the "down"
display key. Brief operation of the "up" key again displays the preceding
value. The sequence of values in the list is determined by the parameter-
isation.
A rapid run is started by holding down the display key "down" or "up" (at
least 2 seconds). The main values of the list are then displayed while the
key remains pressed, but no stored values.
To return to the menu level from the list at the end of the display list press
the display key "down" or "up" for longer (at least 2 seconds).
Both display keys ("down" and "up") must be pressed simultaneously to
return to the operating display from the list.
Set mode Values can be changed in the set mode with the aid of the reset key and
display keys (for setting time and date, identification numbers, battery
hours counter, etc.). The procedure is described in section 5.9 "Set time
and date, ID numbers, battery time".
5.5 Alert LED
The red alert LED (optional) on the main face plate indicates that certain
event(s) have occurred. Which event(s) trigger the alert LED can be set by
parameterisation.
Landis+Gyr E650
Readout
imp imp
Alert LED Cl. 1 kvarh
1000 kWh Cl. 1
Three-phase four-wire meter
ZMD410CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 5(10) A 50 Hz
20XX
T1 T2 T3 SET Test
Figure 73 Alert LED
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5.6 Optical test output
The optical test outputs – one for active energy in all meters and a second
for reactive energy in combi-meters – are fitted in the main face plate above
the liquid crystal display.
Optical
test output
Landis+Gyr E650
Readout reactive energy
Cl. 1 imp
kvarh
1000 imp
kWh
Cl. 1 (combimeters
Three-phase four-wire meter only)
ZMD410CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 5(10) A 50 Hz
20XX
Optical
test output
active energy
T1 T2 T3 SET Test
Figure 74 Optical test outputs
The optical test outputs are used for testing the meter (see also section 7.1
"Meter testing"). They transmit visible red pulses corresponding to the cur-
rent measured values (active and reactive energy).
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5.7 Data readout
The energy supply company can record the data stored locally in the meter
at any time in two ways:
Reading the liquid crystal display of the meter. The displayed data is
defined by parameterisation.
Automatic data readout via the optical interface with a readout device
(e.g. laptop).
Readout data
For readout to IEC 62056-21 all data determined by the parameterisation
are read out in the specified sequence.
For readout according to dlms (Device Language Message Specification)
the data requested by the readout unit are read out.
If the meter is fitted with the appropriate communication unit (see associ-
ated separate operating instruction) remote readout of the meter data is
also possible.
Procedure for data readout via optical interface
1. Start the readout device (according to the details in the associated
operating instructions).
2. Connect the cable of the reading head to the readout device.
3. Place the reading head in the "Readout" indentation on the plastic
viewing window of the meter. The reading head cable must point to-
wards the terminal cover (when mounted vertically downwards). The
reading head is held magnetically.
4. Start the data readout on the readout device (according to the details
in the associated operating instructions).
5. Remove the reading head from the meter again after completing the
readout.
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5.7.1 Readout to IEC 62056-21
The data read out according to IEC 62056-21 are recorded in the form of
the example shown below. The quantity and sequence of values in the log
is determined by parameterisation.
Log example Significance
/LGZ4\2ZMD4104100 Designation of meter
(reply on transmit request)
F.F (00000000) Error message
0.0.1 (417242) 1st identification number
0.1.0 (28) Number of resets
0.1.2.04 (98-05-01 00:00) Time of last reset
1.2.1 (26068.7*kW) Pmax cumulated Rate 1
1.2.2 (15534.8*kW) Pmax cumulated Rate 2
1.6.1 (192.4*kW)(00-05-06 10:45) Pmax present Rate 1
1)
1.6.1*04 (202.4)(00-04-22 09:30) with April stored value Rate 1
1.6.2 (086.7*kW)(00-05-04 22:30) Pmax present Rate 2
1)
1.6.2*04 (100.9)(00-04-14 23:00) with April stored value Rate 2
1.8.1 (0244948*kWh) Active energy (import) Rate 1
1)
1.8.1*04 (0234520) with April stored value Rate 1
1.8.2 (0082520*kWh) Active energy (import) Rate 2
1)
1.8.2*04 (0078197) with April stored value Rate 2
5.8.1 (0106103*kvarh) Reactive energy (inductive) Rate 1
1)
5.8.1*04 (0100734) with April stored value Rate 1
5.8.2 (0039591*kvarh) Reactive energy (inductive) Rate 2
1)
5.8.2*04 (0036152) with April stored value Rate 2
1.8.0 (0327468*kWh) Total active energy
5.8.0 (0145694*kvarh) Total reactive energy (inductive)
8.8.0 (0001452*kvarh) Total reactive energy (capacitive)
0.9.1 (14:18:06) Time-of-day of readout
0.9.2 (00-05-20) Date of readout
C.7.0 (00087) No. of voltage failures of all phases
C.72.0 (00157) Number of under-voltages
C.73.0 (00000) Number of over-voltages
C.74.0 (00306) Number of over-loads (over-current)
C.3.0 (500) Active pulse constant
C.3.1 (500) Reactive pulse constant
C.2.1 (00-03-26) Date of last parameterisation
! End of log
1)
If the sequence is parameterised as month.
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Notes The energy supply company can select by parameterisation between a
standard identification or its own identification. The standard identification
has the following structure:
/LGZ... Manufacturer (Landis+Gyr)
/LGZ 4... Transmission rate 4 = 4800 bps
/LGZ4 \2... Extended communication possibility
2 = dlms-compatible meter
/LGZ4\2 ZMD410... Meter Type of measuring unit
/LGZ4\2ZMD410 41... Basic version tariff section
/LGZ4\2ZMD41041 00... Additional functions
(auxiliary power supply)
/LGZ4\2ZMD4104100 .B32 Firmware version
Stored values The hyphen following the identification
number and the rate (1.6.1) denotes the
type of resetting:
e.g. 1.6.1*04 *04 Resetting made internally or
remote controlled
e.g. 1.6.1&04 &04 Resetting performed manually
The identification by the energy supply company itself uses an identification
number. ID1.1 (designation of ownership by the energy supply company),
ID1.2 (any desired number) or ID2.1 (serial number) are available. The
identification is comprised as follows in this case:
/LGZ... Manufacturer (Landis+Gyr)
/LGZ 4... Transmission rate 4 = 4800 bps
/LGZ4 \2... Extended communication possibility
2 = dlms-compatible meter
/LGZ4\2 \B32... Meter Firmware version
/LGZ4\2\B32 12345678 Identification number specified
by parameterisation (maximum 8
characters)
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5.7.2 Readout to dlms
While the readout according to IEC 62056-21 uses a predefined protocol,
readout to dlms enables the power supply company to read out values
individually. The company therefore has systematic access to specific
values without being influenced by other values that are not required.
dlms specification Various meter manufacturers – including Landis+Gyr – together with rela-
ted organisations, have compiled the language specification dlms (Device
Language Message Specification).
Objective The objective of dlms is to use a common language for data exchange in
energy measurement and other sectors. In addition to end units such as
meters, tariff units, etc. dlms also defines the interfaces, transmission
channels and system software.
Principle dlms delivery oriented protocol can be compared to sending a letter: the
sender writes the address of the recipient on the letter and hands it to the
post office for transport. The way in which the postal department transports
the letter is of no consequence to the sender and receiver. The only impor-
tant thing is that the address of the recipient is clearly shown and that the
letter is received, read and it can be seen from whom the letter originates.
Units with dlms operate in a similar way. They provide the values – termed
objects – required by the receiver (e.g. control centre) and pass them via
interface to the transport medium (channel). How the values reach the re-
cipient is again immaterial for both parties.
dlms items dlms is an object-oriented language. The dlms objects
have an unique name in the form of the EDIS identification number
contain the value in an exactly defined form and
are configured in a similarly exactly defined format.
Examples are number of resets with date and time, cumulative maxima,
rolling mean values, maxima, energy status, associated stored values, etc.
The sender feeds these objects to a transport medium, e.g. the telephone
network. This transmits them to the receiver, so that the objects are re-
ceived in the same form as supplied by the sender.
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5.8 Input of formatted commands
The following operating data or meter characteristics can be modified by
the input of formatted commands. The user of formatted commands, how-
ever, must have the necessary access authorisation according to the secu-
rity system.
The following commands can be used both according to IEC 62056-21 and
also with dlms:
Set time/date
Set identification numbers for the energy supply company and for the
manufacturer (by line).
Reset
Neutralise reset inputs KA/KB
Set/reset reset counter
Control tariff rates via interface
Set/reset energy registers
Set/reset total energy registers
Set/reset demand maximum registers
Set/reset power factor registers
Reset stored values
Reset battery hours counter
Reset voltage failures registers
Switch on/off increased resolution (test mode)
Define by additional parameters whether the optical test output for
active energy in test mode supplies active or reactive energy pulses
Delete error messages
Change passwords P1,P2 and W5
Reset load profile 1 / load profile 2
Reset event log
Reset dedicated event log groups
The following commands can only be executed with dlms:
Reset event register
– Under- and over-voltages
– Demand messages
– Current messages
– Power factor messages
Set thresholds for messages
Formatted commands are transferred to the meter with a suitable device
via the optical interface or via an interface circuit of the communication unit.
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5.9 Set time and date, ID numbers, battery time
The following values can be changed at any time from the service menu
(set mode):
Date and time
Identification numbers
Operating time of battery
Below is an example on how to set the date and time.
Operating
display
1. All segments of the Display check
display are lit
2. Enter service menu Set mode
R
3. Enter set mode Identification
number
4. Select required Date, old
setting value
5. Select digit to be Digit flashes
R changed
6. Change digit value Digit flashes
7. Select digit to be Next digit
R changed flashes
8. Repeat steps 5 – 7 for all digits to be changed. All digits flash
9. Confirm new Date, new
R setting value
10. Repeat steps 4 – 9 for all settings to be changed.
11. Advance display End of set
until End mode
12. Back to service Service menu
menu
13. Advance display End of service
until End menu
14. Back to operating Operating
display display
15. Close and re-seal the front door.
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6 Service
This section describes the necessary servicing work after the appearance
of operating faults or error messages.
6.1 Operating faults
If the liquid crystal display is illegible or the data readout does not function,
the following points should first be checked:
1. Is the network voltage present (supply fuses intact and test terminals
closed)?
2. Is the maximum permissible ambient temperature exceeded?
3. Is the plastic viewing window over the face plate clean (not scratched,
painted over, misted over or soiled in any way)?
Danger of short-circuits
Never clean soiled meters under running water or with high pressure de-
vices. Water penetration can cause short-circuits. If the meter is heavily
soiled, it should be de-installed if necessary and sent to an authorised
service centre, so that a new plastic viewing window can be fitted.
If none of the points listed is the cause of the fault, the meter should be dis-
connected, removed and sent to the responsible service and repair centre
(according to section 6.3 "Repairing meters").
6.2 Error messages
The meters regularly perform an internal self-test. This checks the correct
function of all important parts.
In case of a serious error detected (fatal or critical error according to
classification in the following degrees of severity), the meters displays an
error code. This error code appears as an eight-digit number together with
"F.F" or "FF" in the display (error code F.F 00000000 = no error).
Classification of The degree of severity of an error occurring is assessed as follows:
degree of severity
A fatal error indicates a severe problem, which prevents the meter main-
taining measuring operation, e.g. a defective hardware component. The
meter stops its operation and the error code is displayed permanently. The
meter must be exchanged.
A critical error indicates a severe problem, but with which the meter conti-
nues to function and measurement is still possible. The data are stored in
the memory and suitably marked in case of doubt. After a critical error, the
error code is displayed until acknowledged with the display key or until the
error register is reset, e.g. via the electrical interface. Depending on the
type of the error this can cyclically occur again, since with the acknowl-
edgement the error cause is usually not repaired. The meter must in this
case be exchanged as soon as possible.
Non-critical errors can influence the meter functions (temporarily or per-
manently). These errors are recorded in the error register. The meter re-
mains serviceable and normally needs not to be exchanged.
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Deleting error If nothing else is specified in the following description of the error groups,
messages the error messages can only be deleted with formatted commands (see
section 5.8 "Input of formatted commands"). If the error occurs again, the
meter should be removed and sent to the responsible service and repair
centre (according to section 6.3 "Repairing meters").
6.2.1 Structure of an error message
An error message has the following form:
Figure 75 Error message on E650 meters
All E650 meters use the same format for error messages. It consists of four
groups of 2 digits each, whereby the groups have the following significance:
Figure 76 Significance of error message
Each group has two digits written in hexadecimal notation and can there-
fore have the values 0 to 9 and letters A to F. Both digits each form the sum
of the individual values of 4 possible types of error as shown in the follow-
ing diagrams.
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6.2.2 Error groups
Time-base errors
Group 1 of error messages
(clock) of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Low battery
Invalid clock
*
*
* * not used
*
*
*
Figure 77 Group 1 of error messages
The first digit in the first group has no significance, since no error messages
are assigned to it.
The second digit can have values between 0 (no error message) and 3
(both error messages set). Significance:
F.F 01 00 00 00 Low battery (non-critical error)
The battery is missing or discharged. If there is no mains voltage at the
meter and the internal supercap is discharged (after about 3 weeks) then
the calendar clock will stop.
The error is deleted automatically when the battery voltage has again
reached a sufficient value (e.g. after inserting a new battery as described in
section 7.2 "Changing the battery").
This error message only appears if the meter is parameterised as "fitted
with battery". Otherwise there is no check of the battery condition.
The same applies to messages where the bit is set:
F.F 03 .. .. ..
F.F 02 00 00 00 Invalid clock (non-critical error)
The meter has found that the calendar clock has stopped at some time,
e.g. due to insufficient power reserve (battery low). The clock is running,
but shows the wrong time and/or date.
The error is deleted automatically when the time and date have been set
correctly by the relevant formatted command or manually in the set mode
(see section 5.8 "Input of formatted commands"). or section 5.9 "Set time
and date, ID numbers, battery time"). If necessary, replace the battery.
The same applies to messages where the bit is set:
F.F 03 .. .. ..
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Errors for write/read
access Group 2 of error message
of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Main memory access error
Backup memory access error
Measuring system access error
Time device access error
Load profile memory access error
not used
Communication unit access error
not used
Figure 78 Group 2 of error messages
In the second group both digits can have values between 0 (no error mes-
sage) and F (all four error messages set). Significance:
F.F 00 x1 00 00 Main memory access error (fatal error)
This error message appears if the main memory could not be accessed
several times during the start-up of the meter.
The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. x3/x5/x7/x9/xB/xD/xF .. ..
F.F 00 x2 00 00 Backup memory access error (non-critical error)
This error message appears if the backup memory could not be accessed
several times.
The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. x3/x6/x7/xA/xB/xE/xF .. ..
F.F 00 x4 00 00 Measuring system access error (non-critical error)
This error message appears in case of repeated failures when accessing
the measuring system, possibly because of a completely discharged super-
cap, which causes an incorrect start-up behaviour.
Power-up meter and wait for a short time, then clear error via com-
munication. If the error does not reoccur, it is recommended to equip the
meter with a battery. If the error reoccurs, replace the meter.
The same applies to messages where the bit is set:
F.F .. x5/x6/x7/xC/xD/xE/xF .. ..
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F.F 00 x8 00 00 Time device access error (non-critical error)
The meter sets this message in the event of repeated failures when
accessing the time device. The calendar clock may display an invalid time
or date.
The error can be reset via communication. If it occurs repeatedly, the
meter must be exchanged.
The same applies to messages where the bit is set:
F.F .. x9/xA/xB/xC/xD/xE/xF .. ..
F.F 00 1x 00 00 Load profile memory access error (critical error)
This error message appears in case of repeated failures when accessing
the load profile memory.
Load profile data will be marked in the status code (bit 2 "corrupted meas-
urement" and bit 0 "critical error" set).
It may not be possible to access the load profile memory. The memory may
contain incorrect data. The meter must be exchanged.
The same applies to messages where the bit is set: F.F .. 5x .. ..
F.F 00 4x 00 00 Communication unit access error (non-critical error)
The meter sets this message in the event of repeated failures to access the
communication unit. Communication fails or is slow.
The error can be reset via communication. If it reoccurs, replace first the
communication unit, check the function again. If the error still occurs, the
meter must be exchanged.
The same applies to messages where the bit is set: F.F .. 5x .. ..
Checksum errors
Group 3 of error messages
of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Program checksum error
Backup data checksum error
Parameter checksum error
Load profile 1 checksum error
Stored values checksum error
Event log checksum error
Calibration data checksum error
Load profile 2 checksum error
Figure 79 Group 3 of error messages
The first digit in the third group can have the value 0 (no error message) or
1 (error message set).
The second digit can have values between 0 (no error message) and F
(all four error messages set). Significance:
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F.F 00 00 x1 00 Program checksum error (fatal error)
The meter does not operate and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x3/x5/x7/x9/xB/xD/xF ..
F.F 00 00 x2 00 Backup data checksum error (critical error)
This error message appears when the backup data checksum test fails.
Load profile data will be marked in the status code (bit 2 "corrupted meas-
urement" and bit 0 "critical error" set). The meter may contain incorrect
data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x3/x6/x7/xA/xB/xE/xF ..
F.F 00 00 x4 00 Parameter checksum error (critical error)
This error message appears when the parameter checksum test fails.
Load profile data will be marked in the status code (""bit 0 "critical error"
set). The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x5/x6/x7/xC/xD/xE/xF ..
F.F 00 00 x8 00 Load profile 1 checksum error (non-critical error)
Load profile 1 data of the defective memory area will be marked in the
status code (bit 2 "corrupted measurement" set).
The error can be reset via communication. Reset the load profile first
and then the error. If it occurs repeatedly, the meter must be replaced as
soon as possible.
The same applies to messages where the bit is set:
F.F .. .. x9/xA/xB/xC/xD/xE/xF ..
F.F 00 00 1x 00 Stored values checksum error (critical error)
Data in the defective memory area will be marked in the status code (bit 0
"critical error" set).
The error can be reset via communication. If it occurs repeatedly, the
meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 3x/5x/7x/9x/Bx/Dx/Fx ..
F.F 00 00 2x 00 Event log checksum error (non-critical error)
Data in the defective memory area will be marked in the status code (bit 0
set).
The error can be reset via communication. If it occurs repeatedly, the
meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 3x/6x/7x/Ax/Bx/Ex/Fx ..
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F.F 00 00 4x 00 Calibration data checksum error (critical error)
Data in the defective memory area will be marked in the status code (bit 0
"critical error" set).
The meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 5x/6x/7x/Cx/Dx/Ex/Fx ..
F.F 00 00 8x 00 Load profile 2 checksum error (non-critical error)
Load profile 2 data of the defective memory area will be marked in the
status code.
The error can be reset via communication. Reset the load profile first
and then the error. If it occurs repeatedly, the meter must be replaced as
soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 9x/Ax/Bx/Cx/Dx/Ex/Fx ..
Other errors
Group 4 of error messages
of E650 meters
Sum of values
Value in hexadecimal code
Invalid power down
*
* * not used
*
Expired watchdog
Communication locked
Wrong EEPROM/Flash identifier
Wrong extension board
Figure 80 Group 4 of error messages
The first digit in the fourth group can have the values 0 to F.
The second digit can have values between 0 (no error message) and 1
(Invalid power down). Significance:
F.F 00 00 00 x1 Invalid power down (non-critical error)
The meter has detected that the last data storage was not performed cor-
rectly. The meter may contain incorrect data or may have lost data since
the last storage, i.e. for 24 hours maximum.
The error can be reset via communication. If it occurs repeatedly, con-
tact Landis+Gyr Customer Services.
F.F 00 00 00 1x Expired watchdog (non-critical error)
The microprocessor was restarted due to a disturbance (e.g. lightning). The
meter may lose all data recorded since the last storage, i.e. for 24 hours
maximum.
The error can be reset via communication. If it occurs repeatedly, con-
tact Landis+Gyr Customer Services.
The same applies to messages where the bit is set:
F.F .. .. .. 3x/5x/7x/9x/Bx/Dx/Fx
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F.F 00 00 00 2x Communication locked (non-critical error)
This error indicates access attempts via the communication interface with
wrong passwords.
The error is automatically deleted after the inhibition time or at midnight.
The same applies to messages where the bit is set:
F.F .. .. .. 3x/6x/7x/Ax/Bx/Ex/Fx
F.F 00 00 00 4x Wrong EEPROM/Flash (fatal error)
Incorrect EEPROM/ Flash memory is installed in meter.
The meter does not operate and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. .. 5x/6x/7x/Cx/Dx/Ex/Fx
F.F 00 00 00 8x Wrong extension board (non-critical error)
Identification of extension board differs from that parameterised in the
meter.
The meter might not have the required functions such as data profile, con-
trol inputs or output signals. The meter has to be exchanged.
The same applies to messages where the bit is set:
F.F .. .. .. 9x/Ax/Bx/Cx/Dx/Ex/Fx
6.3 Repairing meters
Meters must only be repaired by an authorised service and repair centre
(or manufacturer).
The following procedure should be adopted if a meter repair is necessary:
1. If the meter is installed, remove the meter as described in section 4.7
"De-installation"and fit a substitute meter.
2. Describe the error found as exactly as possible and state the name
and telephone number of the person responsible in case of inquiries.
3. Pack the meter to ensure it can suffer no further damage during trans-
port. Preferably use the original packing if available. Do not enclose
any loose components.
4. Send the meter to the responsible service and repair centre.
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7 Maintenance
This section describes the necessary maintenance work.
7.1 Meter testing
Meter tests should be performed at periodic intervals according to the valid
national regulations (either on all meters or on specific random samples). In
principle, the meters should be de-installed for this purpose according to
the instructions in section 4.7 "De-installation" and replaced by a substitute
meter. The meter test can also be performed on the spot in certain circum-
stances.
7.1.1 Test mode
The test mode permits increasing the resolution of the energy registers by 1
to 5 digits. This allows the energy supply company to carry out the so called
measuring unit test in a reasonably short time.
In test mode, the same registers shown as a rolling list in the operating
display are always displayed, but with high resolution and not rolling.
The energy registers comprise a total of 12 digits. A maximum of 8 digits,
however, is shown on the display. The effective number of digits shown and
the number of decimal places are determined by the parameterisation. For
the test mode more decimal places are normally parameterised (maximum
5) to permit a quicker test of the transmission to the energy registers.
Figure 81 Display changeover normal mode – test mode
Changeover from normal to test mode and back is made by formatted
commands (see section 5.8 "Input of formatted commands") or manually in
the service menu.
In test mode, the optical test output for active energy can also provide reac-
tive energy pulses depending on the parameterisation. Reactive energy
pulses are supplied to this test output if the register shown on the display
represents a reactive energy register. Active energy pulses are supplied for
all other measured values shown as in normal operating mode. Formatted
commands can also be used to define whether the optical test output for
active energy in test mode should supply active or reactive energy pulses,
independent of the type of register shown on the display. This permits
changeover without manual intervention.
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7.1.2 Measuring times
For technical reasons, greater measuring deviations can occur during
short-term measurements. It is therefore recommended to use sufficiently
long measuring times in order to achieve the required accuracy.
Table of measuring times required at the optical test output:
ZMD400xT Measuring uncertainty Measuring uncertainty
ZFD400xT 0.1% 0.05%
Un = 58 to 230 V Current 3P 1P 3P 3P 1P 3P
In = 1 A, 5 A % In cos=1 1 0.5 cos=1 1 0.5
1 40 s 40 s 90 s 80 s 80 s 160 s
2 20 s 20 s 40 s 40 s 40 s 80 s
5 10 s 10 s 15 s 16 s 16 s 32 s
10 8s 8s 10 s 14 s 14 s 18 s
20 6s 6s 8s 12 s 12 s 14 s
50 6s 6s 6s 12 s 12 s 12 s
100 6s 6s 6s 12 s 12 s 12 s
200 6s 6s 6s 12 s 12 s 12 s
3 P = universal
1 P = single-phase
7.1.3 Optical test output
The red optical test outputs on the meter above the LCD should be used for
meter testing. These supply pulses at a frequency dependent on the meter
constant R, whereby the rising edge is always decisive for the test.
Note that the digital signal processing provides a delay of 2 seconds be-
tween the instantaneous power at the meter and the appearance of the
pulses at the optical test outputs. No pulses are lost.
The number of pulses per second for the desired power is obtained by
multiplying the meter constant R by the power in kW divided by 3600.
Example: Meter constant R = 1000
Power P = 35 kW
f-test output = R x P / 3600 = 1000 x 35 / 3600 = 10 imp/s
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Test mode Depending on the parameter setting of the behavior of the pulse LED, the
test mode enables you to select which measuring value (active, reactive, I²,
U²) is shown on the optical test output.
In the display, values for active, reactive and apparent energy are available.
Depending on parameter setting, the resolution of the display register can
be increased for faster testing. In the test mode, the resolution is increased
by one decimal point compared with the normal mode. A maximum of 5
decimal points is possible.
Operating
display
1. All segments of the Display check
display are lit
2. Enter service menu Set mode
R
3. Select test mode Test mode
4. Enter test mode First value
5. Select required Value x
value
6. Repeat step 3 for all values to be tested
7. Exit test mode Operating
display
Examples
First value and value x are examples. The real values are defined in the
parameter settings and are the same as the operating display.
The measured values are displayed at the optical test outputs as shown in
the following table:
Test output Test output
Mode Register on display
reactive active
Normal mode Any register |R| |A|
Losses I2h U2h
Test mode Active energy A |R| |A|
Reactive energy R |A| |R|
2
Losses (NLA) Ih U2h
Losses (OLA) U2h I2h
Any other registers not |R| |A|
mentioned
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7.1.4 Creep test
A test voltage Up of 1.15 Un is used for the creep test (no-load test) to IEC
62053-21 (e.g. Up = 265 V with Un = 230 V).
Procedure:
1. Disconnect the meter from the network for at least 10 seconds.
2. Then switch on the test voltage Up and wait approx. 10 seconds. After
this time the energy direction arrows must disappear. The red optical
test outputs are permanently "lit".
3. Switch on test mode (high resolution).
4. The meter must not deliver more than one pulse during the creep test.
Check the energy levels for changes in test mode. They must not in-
crease by more than the value of one pulse (see face plate).
7.1.5 Starting test active part
Procedure:
1. Apply a load current of 0.02% of the nominal current In (IEC-meters) or
0.02% of the reference current Iref (MID-meters) – e.g. 1 mA with In=
Iref= 5 A – and the voltage Un (three-phase in each case) and cosφ =
1. The meter must remain in creep.
2. For ZxD410: Increase the load current to 0.2% In (IEC-meters) or 0.2%
Iref (MID-meters) – e.g. 10 mA with In=Iref= 5 A.
For ZxD405, ZxD402: Increase load current to 0.1% In (=0.1 Iref). The
energy direction arrow "P" must appear within 10 seconds. The optical
test output for active energy consumption is no longer permanently "lit".
7.1.6 Starting test reactive part
Procedure:
1. Apply a load current of 0.02% of the nominal current In (e.g. 1 mA with
In = 5 A) and the voltage Un (three-phase in each case) and sinφ = 1.
The meter must remain in creep.
2. Increase the load current to 0.2% In (i.e. 10 mA with In = 5 A).
The energy direction arrow "Q" must appear within 10 seconds. The
optical test output for reactive energy consumption is no longer perma-
nently "lit".
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7.2 Changing the battery
If the meter is provided with a battery, this must be changed if one of the
following events occurs:
The symbol appears on the display.
The battery has been in the meter for more than 10 years (preventive
servicing). It is recommended to note the date of insertion on the bat-
tery. The 10 years depend on the product and on the age of the battery
when inserting it into the meter.
The battery operating hours counter indicates over 80,000 hours (can
be read under code C.6.0 in service mode).
The battery charge indicates less than 4.8 V (can be read under code
C.6.1 in service mode).
Meters with or without battery
Only meters parameterised as "fitted with battery" have the symbol
and the battery operating hours counter.
Dangerous voltage on contacts in the battery compartment
The contacts in the battery compartment may have mains voltage applied
(F circuit). Therefore only remove the battery with the existing battery
holder and insert the new battery only with the battery holder. Ensure that
the contacts are never touched.
Replacement battery
As a replacement, use only a lithium battery with a rated voltage of 6 V and
the same construction as the original battery.
Procedure:
1. Remove the front door seal.
2. Open the front door.
The battery compartment is on the left below the liquid crystal display.
Figure 82 Battery compartment
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3. Press on the latch of the plastic battery holder until it releases and then
withdraw the battery holder with the old battery.
Figure 83 Removing the battery
4. Mark the current date on the new battery.
5. Withdraw the old battery from the holder and insert the new battery.
6. Push the battery holder with battery into the battery compartment until
the latch engages.
7. Reset the battery hours counter to zero with the relevant formatted
command (see section 5.8 "Input of formatted commands") or in the
set mode (see section 5.9 "Set time and date, ID numbers, battery
time").
8. Close the front door.
9. Re-seal the front door.
10. Dispose of old batteries as hazardous waste in accordance with local
regulations.
Checking time-of-day and date
After inserting the battery, check the time-of-day and date without power
applied and set these values again if necessary.
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8 Disposal
Electronic waste treatment
This product must not be disposed of in regular waste. Use a professional
electronic waste treatment process.
The components used to manufacture the device can, in the main, be
broken down into constituent parts and sent to an appropriate recycling or
disposal facility. When the product is removed from use, the whole product
must be sent to a professional electronic waste treatment process. The
waste treatment and disposal plants must be approved by local regulatory
authorities.
The end processing of the product and recycling of its components must
always be carried out in accordance with the rules and regulations of the
country where the end processing and recycling are done.
On request, Landis+Gyr will provide more information about the
environmental impact of the product.
Disposal and environmental protection regulations
The following are general guidelines and should NOT take priority over
local disposal and environmental policies which should be adhered to
without compromise.
Components Disposal
Printed circuit boards, Delivered to recycling plants
LEDs, LCD display
Metal components Sorted and delivered to metal recycling plants
Plastic components Sorted and delivered to re-granulation if at all
possible
Batteries Removed from meter and delivered to
specialised recycling plants
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9 Index
.MAP110 ....................................................... 30 Connection to medium and high voltage 44, 45
Accuracy class 0.2S ..................................... 11 Connections .................................................. 36
Active component ......................................... 16 Contact voltages ........................................... 44
Active energy ................................................ 19 Control elements .......................................... 58
Active power ........................................... 16, 19 Control inputs ............................................... 11
Active power calculation ............................... 16 Control of display via optical interface .......... 58
Active power direction .................................. 60 Creep test ..................................................... 86
Additional control inputs ............................... 14 Critical error .................................................. 75
Additional output contacts ............................ 14 CS ................................................................. 14
Alert LED ...................................................... 67 Current transformer ...................................... 43
Anti-tampering features ................................ 31 Data preparation for billing............................ 13
Apparent energy ........................................... 20 Data readout ................................................. 69
Apparent energy calculation ......................... 20 Date and time
Aron circuit.............................................. 15, 44 Set ...................................................... 74, 85
Arrow symbols .............................................. 61 DC magnet detection .................................... 31
Arrows for status indication .......................... 35 Decommissioning ......................................... 89
Automatic data readout ................................ 69 Dedicated event log ...................................... 25
Auxiliary power supply .................................. 14 De-installation ............................................... 55
Background lighting ...................................... 60 Device description .......................................... 8
Backup data checksum error ........................ 80 Device Language Message Specification ..... 69
Backup memory access error ....................... 78 Digital intermediate values............................ 15
Basic layout of LCD ...................................... 60 Direction of rotating field ............................... 22
Battery charge status .................................... 87 Display .................................................... 35, 60
Battery compartment .............................. 33, 87 Display changeover normal mode – test mode
Battery condition ........................................... 61 ................................................................. 83
Battery exchange .......................................... 87 Display check ............................................... 63
Battery operating hours counter ................... 87 Display keys ..................................... 32, 35, 58
Billing data .................................................... 13 Display list examples .................................... 64
Block schematic diagram .............................. 11 Display menu .......................................... 63, 64
Buttons ......................................................... 12 Disposal ........................................................ 89
Calculation of apparent energy ..................... 20 Disposal regulations ..................................... 89
Calibration data checksum error ................... 81 dlms items .................................................... 72
Calibration stage ........................................... 15 dlms specification ......................................... 72
Changing values in set mode ....................... 74 Electronic waste treatment ........................... 89
Characteristics of meters ................................ 8 Energy components ...................................... 19
Check of connections ................................... 52 Energy magnitude......................................... 19
Checksum errors .......................................... 79 Entering formatted commands...................... 28
Combi-meters ................................................. 8 Environmental protection regulations ........... 89
Commissioning ............................................. 52 Error code ..................................................... 75
Communication ............................................. 28 Error message .............................................. 62
Communication locked ................................. 82 Error message structure ............................... 76
Communication unit .......................... 14, 33, 73 Error messages ............................................ 75
Communication unit access error ................. 79 Error severity ................................................ 75
Communication unit dummy ......................... 33 Errors for write/read access .......................... 78
Communication units .................................... 28 Event log ................................................. 25, 65
Condition of test terminal block before Expired watchdog ......................................... 81
removing meter ........................................ 56 Extended suspension hook .......................... 46
Connecting meter ......................................... 48 Extension board ............................................ 14
Connecting the meter ................................... 49 Extension boards .................................... 40, 41
Connecting the phase connection lines ........ 49 Face plate ..................................................... 35
Connection check ......................................... 52 Fatal error ..................................................... 75
Connection diagrams (examples) ................. 38 Field of application .......................................... 8
Connection diagrams extension board ......... 40 Firmware version .......................................... 11
Connection of cables of cover detection unit 54 Fixed display ................................................. 62
Connection of RS485 interface ..................... 51 Fixing of cover detection unit to meter .......... 54
Connection to low voltage ............................ 43 Form of fixing ................................................ 46
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Formation of measured quantities ................ 19 Meter characteristics ....................................... 8
formatted commands .................................... 28 Meter characteristics modification ................. 73
Formatted commands ............................. 73, 83 Meter constant .............................................. 84
Four-quadrant measurement ........................ 20 Meter mounting ............................................. 46
Front door sealing with padlock .................... 34 Meter testing ........................................... 68, 83
Functional check ........................................... 52 Modem .......................................................... 14
Grounding ..................................................... 44 Mounting the meter ....................................... 46
Harmonics ..................................................... 16 Natural error compensation .......................... 15
High voltage .............................................. 8, 45 Neutral current .............................................. 21
High voltage range ........................................ 44 No-load test ................................................... 86
Identification numbers ................................... 74 Non-critical errors .......................................... 75
IEC 62056-21 .......................................... 69, 73 Normal mode ................................................ 83
Index field...................................................... 61 Numbering of quandrants ............................. 20
Index system ........................................... 61, 93 OBIS ....................................................... 61, 93
Information for connecting meter .................. 43 Objectivefor dlms .......................................... 72
Input of formatted commands ....................... 73 Operating data modifications ........................ 73
Input signals .................................................. 14 Operating display .......................................... 62
Inputs ............................................................ 11 Operating faults ............................................. 75
Installation ..................................................... 43 Optical interface .......................... 28, 32, 35, 73
Intermediate values....................................... 15 Optical key .................................................... 58
Internal current transformers ......................... 15 Optical test output ....................... 32, 35, 68, 84
Invalid clock .................................................. 77 Output contact data ....................................... 36
Invalid power down ....................................... 81 Outputs ......................................................... 12
Keys .............................................................. 12 Ownership designation ................................. 36
Laptop ........................................................... 69 Packing meter ............................................... 82
LCD ......................................................... 35, 60 Parameter checksum error ........................... 80
Liquid crystal display ............................... 35, 60 Phase angles ................................................ 22
Lithium battery .............................................. 87 Phase connections .................................. 11, 36
Load profile 1 ................................................ 25 Phase current ................................................ 21
Load profile 2 (option) ................................... 25 Phase voltage ............................................... 21
Load profile 2 checksum error ...................... 81 Phase voltages ............................................. 61
Load profile checksum error ......................... 80 Power factor .................................................. 21
Load profile memory access error ................ 79 Power supply ................................................ 14
Log example ................................................. 70 Preliminary fuses .......................................... 43
Losses..................................................... 23, 65 Preliminary work ........................................... 48
Low battery ................................................... 77 Profile 2 ......................................................... 25
Low voltage ..................................................... 8 Program checksum error .............................. 80
Lower part of case ........................................ 32 Pulse input data ............................................ 36
Magnet detection .......................................... 31 Pulse inputs .................................................. 12
Main face plate.............................................. 35 Purpose of this manual ................................... 5
Main memory access error ........................... 78 Quadrant display ........................................... 60
Mains frequency ...................................... 17, 21 Quadrants ..................................................... 19
Maintenance ................................................. 83 Rapid run ...................................................... 64
Manufacturer seal ......................................... 32 Reactive component ..................................... 16
MAP120 ........................................................ 30 Reactive energy ............................................ 19
Mean value formation ................................... 17 Reactive power ............................................. 16
Measured quantities .................... 12, 13, 17, 36 Reactive power calculationt .......................... 16
Measuring deviations .................................... 84 Reactive power direction ............................... 60
Measuring device .......................................... 44 Reading head ................................................ 69
Measuring system ................................... 12, 14 Readout device ............................................. 69
Measuring system access error .................... 78 Readout factor .............................................. 36
Measuring times for meter tests .................... 84 Readout log ................................................... 70
Measuring uncertainty ................................... 84 Readout to dlms ............................................ 72
Medium voltage............................................... 8 Readout to IEC 62056-21 ............................. 70
Medium voltage range .................................. 44 Readout via optical interface ......................... 69
Memory ......................................................... 13 Recording counting pulses of other media ...... 8
Meter board................................................... 46 Reference documents ..................................... 5
Meter case .................................................... 32 Remote reading ............................................ 14
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92/96 Index
Repairing meters .......................................... 82 Terminal cover .............................................. 32
Replacement battery .................................... 87 Terminal cover detection .............................. 31
Reset key ................................................ 33, 59 Terminal layout ............................................. 37
Rolling display .............................................. 62 Test mode ............................................... 83, 85
Rotating field ................................................. 17 Test terminal block ....................................... 43
RS232 ........................................................... 14 Test terminal block status before installation 49
RS485 ........................................................... 14 Test terminal blocks status after
Safety commissioning ......................................... 53
Information ................................................. 6 Test voltage .................................................. 86
Regulations ................................................ 7 Time device access error.............................. 79
Responsibilities .......................................... 6 Time measurement ....................................... 17
Seal component ............................................ 34 Time-base errors .......................................... 77
Sealing.................................................... 32, 52 Total active energy ....................................... 19
Secondary circuit .......................................... 43 Total apparent energy................................... 20
Self-tests ................................................. 62, 75 Total harmonic distortions............................. 22
Series designation ........................................ 10 Total reactive energy .................................... 19
Service .......................................................... 75 Transformer connection .................................. 8
Service and repair centre ............................. 82 Transformer data .......................................... 36
Service menu ................................................ 66 Transmission contact meters .......................... 8
Set date and time ......................................... 74 Transmission contacts .................................... 8
Set identification numbers ............................ 74 Type designation .......................................... 10
Set mode ................................................ 67, 74 Type of measurement ZFD400xT ................. 15
Set operating time of battery ........................ 74 Type of measurement ZMD400xT ................ 14
Severity of errors .......................................... 75 Types of display ............................................ 62
Signal conversion and processing ................ 15 Types of error ............................................... 76
Signal processing ......................................... 12 Units field ...................................................... 61
Signal processor ..................................... 15, 17 Upper part of case ........................................ 32
Signal utilisation ............................................ 13 Utility seal ..................................................... 32
Spring-loaded terminals ................................ 37 Value display ................................................ 64
Starting test .................................................. 86 Value field ..................................................... 61
Status indication arrows ............................... 35 Verification seal ............................................ 32
Stored value profile ....................................... 24 Versions of communication units .................. 29
Stored values checksum error ...................... 80 Voltage circuit................................................ 43
Structure of error message ........................... 76 Voltage divider .............................................. 15
Substitute meter ............................... 56, 82, 83 Voltage transformer ...................................... 44
Summation channels .................................... 24 Wrong EEPROM/Flash ................................. 82
Suspension triangle ...................................... 47 Wrong extension board................................. 82
Symmetrical terminal layout ................... 11, 37 Zero passage .......................................... 17, 22
Target group of this manual ............................ 5 ZFD400AT/CT ................................................ 8
Tariff control .................................................. 13 ZMD400AT/CT................................................ 8
Tariff face plate ............................................. 36
© Landis+Gyr D000030110 en g – E650 Series 3 – ZMD400AT/CT, ZFD400AT/CT – User Manual
Appendix 1 OBIS code 93/96
Appendix 1 OBIS code
Object Identification System
The OBIS code (Object Identification System) is structured as follows:
A B C D E F Value group
M- KK: GG. AA. T W According to VDEW
A: Medium Defines the medium used. If only one medium is used it does not have to
[1 … 9] be specified. The Values represent the following objects:
1 Electricity
2, 3 not used
4 Heating costs
5 Cooling system
6 Heating system
7 Gas
8 Cold water
9 Hot water
B: Channel Defines the channel number, i.e. the number of the input of a metering
[1 … 64] equipment with several inputs for the measurement of energy of the same
or different types (e.g. in data concentrators, registration units). This
enables data from different sources to be identified. If only one channel
(only one meter) is used, it does not have to be specified.
C: Measured quantity Defines the abstract or physical data items related to the information
[1 … 99] source concerned, e.g. active power, reactive power, apparent power,
cos, current or voltage.
General data 0
Active energy + (import) ∑Li 1 L1 21 L2 41 L3 61
– (export) 2 22 42 62
Reactive energy + 3 23 43 63
– 4 24 44 64
QI (quadrant I) 5 25 45 65
QII 6 26 46 66
QIII 7 27 47 67
QIV 8 28 48 68
Apparent energy + (import) 9 29 49 69
– (export) 10 30 50 70
Current 11 31 51 71
Voltage 12 32 52 72
Power factor 13 33 53 73
Frequency 14
Service data C
Error message F
Profile data P
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94/96 Appendix 1 OBIS code
D: Measuring type Defines types, or the result of the processing of physical quantities accor-
[1 ... 73, F, P] ding to various specific algorithms. The algorithms can deliver energy and
demand quantities as well as other physical quantities.
The following list is an excerpt.
Capture period 1 2 3
Cumulated minimum 1 11 21
Cumulated maximum 2 12 22
Minimum 3 13 23
Running average 4 14 24
Last average 5 15 25
Maximum 6 16 26
Instantaneous value 7
Time integral 1 (energy status) 8
Time integral 2 (energy consumption) 9
Time integral 3 (excess consumption) 10
...
Test average 55
Test time integral 4 58
...
Error message F
Load profile 01
E: Tariff Defines the further processing of measurement results to tariff registers,
[1 ... 9] according to the tariffs in use. Total values are marked with ‘0’. For abstract
data or for measurement results for which tariffs are not relevant, this value
group can be used for further classification.
F: Stored value Defines the storage of data according to different billing periods. Where this
[01 ... 99] is not relevant, this value group can be used for further classification.
Display code To simplify the reading of the display code, individual parts of the OBIS
code can be omitted. The abstract or physical data C and type of data D
must be shown.
Examples
1.8.0 1 = all-phase active power in positive direction
8 = cumulative value (meter reading)
0 = total energy (no tariffs)
0.9.1 Local time
© Landis+Gyr D000030110 en g – E650 Series 3 – ZMD400AT/CT, ZFD400AT/CT – User Manual
Appendix 1 OBIS code 95/96
D000030110 en g – E650 Series 3 – ZMD400AT/CT, ZFD400AT/CT – User Manual © Landis+Gyr
Contact:
Landis+Gyr AG
Theilerstrasse 1
CH-6301 Zug
Switzerland
Phone: +41 41 935 6000
www.landisgyr.com
EU-type examination
certificate
Number T10033 revision 12
Project number SO16203981
Page 1 of 1
Issued by NMi Certin B.V.,
designated and notified by the Netherlands to perform tasks with respect to
conformity modules mentioned in article 17 of Directive 2014/32/EU, after having
established that the Measuring instrument meets the applicable requirements of
Directive 2014/32/EU, to:
Manufacturer Landis+Gyr AG
Theilerstrasse 1
CH 6301 Zug
Switzerland
Measuring A static Active Electrical Energy Meter
instrument
Type : (E650) ZMD/ZFD300/400…
(S650) SMA/SFA300/400…
Manufacturer’s mark or name : Landis+Gyr AG
Reference voltage : ZMD/SMA300: 3x220/380V…3x240/415V
ZMD/SMA400: 3x57,7/100V…3x240/415V
ZFD/SFA400: 3x100V…3x415V
Reference current : ZMD/SMA300: 5, 10, 15 or 20 A
ZMD/ZFD/SMA/SFA400: 0,3, 1, 2 or 5 A
Destined for the measurement of : electrical energy, in a
- three-phase four-wire network
- three-phase three-wire network
- two-phase three-wire network
- single-phase two-wire network
Accuracy class : ZMD/SMA300: A or B
ZMD/ZFD/SMA/SFA 400: B or C
Environment classes : M2 / E2
Temperature range : -40 °C / +70 °C
Further properties are described in the annexes:
Description T10033 revision 12;
Documentation folder T10033-10.
Valid until 31 January 2027
Remarks This revision replaces the earlier versions, including its documentation folder.
1
Issuing Authority NMi Certin B.V., Notified Body number 0122
31 January 2017
C. Oosterman
Head Certification Board
NMi Certin B.V. This document is issued under the provision
Hugo de Grootplein 1 that no liability is accepted and that the
3314 EG Dordrecht manufacturer shall indemnify third-party
The Netherlands liability.
T +31 78 6332332
[email protected] The designation of NMi Certin B.V. as Notified
www.nmi.nl Body can be verified at http:// Reproduction of the complete
ec.europa.eu/enterprise/newapproach/nando/ document only is permitted.
101
Description
Number T10033 revision 12
Project number SO16203981
Page 1 of 4
1 General information about the instrument
All properties of the static active electrical energy meter, whether mentioned or not, shall
not be in conflict with the legislation.
1.1 Essential parts
Description Document Remarks
current sensor 10033/0-05 or 10033/4-05
main board All parts of the printed
- E650 10033/0-06, 10033/0-08 circuit boards are
10033/1-01, 10033/1-03 essential, except the
10033/3-05, 10033/3-07 or 10033/4-07 components which are
related to parts as
- S650/E650 10033/7-04, 10033/7-05 described in paragraph
10033/8-03, 10033/8-04 or 10033/9-02 1.4 or 1.6.
sensor board
(only for ZMD/SMA300) 10033/0-09, 10033/0-10
10033/2-01, 10033/7-06
Shielding: 10033/2-03
Display board
- E650 10033/8-05, 10033/8-07
- S650 / E650 10033/8-06, 10033/8-08
1.2 Essential characteristics
1.2.1 See EU-type examination certificate T10033 revision 12 and the characteristics mentioned
below.
1.2.2 Approved meter types : ZMD/SMA300... (direct connected version)
ZMD/ZFD/SMA/SFA400… (indirect connected version)
An explanation of all type designations is presented in document no. 10033/9-01.
1.2.3 Frequency : 50 Hz
1.2.4 Meter constant : 500, 1.000, 2.000, 5.000, 10.000, 20.000, 40.000, 50.000,
: 100.000 or 200.000 imp./kWh
1.2.5 Number of registers : max. 32
1.2.6 Error messages : “FF” or “F.F” followed by an error code
1.2.7 Phase sequence : the meter is not sensitive to the direction of the applied phase
sequence.
1.2.8 Export energy : the meter is capable of measuring energy in 2 directions
1.2.9 Software specification (refer to WELMEC guide 7.2):
Software type P;
Risk Class C;
Extension L (Stored Value Profile only), while extensions D, S and T are not applicable.
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Description
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Software Checksum Remarks
version
B22 or n.a. All changes to the software will lead to an
B23 or increment of the version number. This is
B24 or assured by the quality system of the
B30 or manufacturer.
B31
B32 or 0xF84F The software version is displayed in the
B33 0x89D2 or 0xC1C3 display sequence and can be read via the
communication interface (OBIS code 0.2.0).
The software version is displayed in the display sequence.
1.3 Essential shapes
1.3.1 The nameplate is bearing at least, good legible, the information as mentioned in the
regulations on energy meters. An example of the markings is shown in documents
no. 10033/12-01 and 10033/12-02.
1.3.2 Sealing: see chapter 2.
1.3.3 The registration observation is executed by means of a LED.
1.4 Conditional parts
1.4.1 Terminal block
The connections for the current cables on the terminal block have a diameter of at least 7
mm (ZMD/SMA300) or 5 mm (ZMD/ZFD/SMA/SFA400). The cables are connected with the
terminal block via 2 screws.
Maximum current Document no. Remarks
120 A 10033/4-02 ZMD/SMA300
20 A 10033/4-03 ZMD/ZFD/SMA/SFA400
1.4.2 Housing
The meter has got a dustproof housing, which has sufficient tensile strength. The cover is
made of synthetic material.
1.4.3 Terminal cover
The terminal cover is made of synthetic material.
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Description
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1.4.4 Register
The quantity of measured energy is presented by means of a display with at least 6 elements.
The way of presentation is described in document no. 10033/4-04.
For test purposes an indication with a least significant element of at least 0,01 kWh, can be
arranged via the communication interface.
1.4.5 Tariff control
When the meter is provided with more than one register, a tariff control is available by
means of tariff inputs or internal clock, whereby the EMC-requirements are fulfilled as
described in Annex V of Directive 2014/32/EU.
1.4.6 Communication module
When the meter is equipped with an exchangeable or integrated communication module,
EMC requirements as described in Annex V of Directive 2014/32/EU must be fulfilled. No
legal data can be altered via the communication modules.
1.4.7 Optical communication
The meter is provided with optical communication. Via the communication no legally
relevant data can be altered.
1.4.8 Option boards
When the meter is equipped with an option boards, the EMC-requirements are fulfilled as
described in Annex V of Directive 2014/32/EU.
Description Document Remarks
060x 10033/8-09, 10033/8-10 6 outputs
240x 10033/8-11, 10033/8-12 2 control inputs, 4 outputs
420x 10033/8-13, 10033/8-14 4 control inputs, 2 outputs
326x 10033/8-15, 10033/8-16 3 control inputs, 2 outputs,
auxiliary power supply 12-12 VDC
045x 10033/8-17, 10033/8-18 4 outputs,
auxiliary power supply 100 to 240 VAC/VDC
046x 10033/8-19, 10033/8-20 4 outputs,
auxiliary power supply 12 to 24 VDC
008x 10033/8-21, 10033/8-22 Super cap board for SMS support
047x 10033/9-03, 10033/9-04 4 outputs,
auxiliary power supply 12 to 60 VDC
421x 10033-12-02, 10033-12- 4 control inputs, 2 outputs (8A relays)
03
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1.5 Conditional characteristics
1.5.1 Maximum current:
ZMD/SMA300: smaller than or equal to 120 A, and at least 5 times higher
than the reference current.
ZMD/ZFD/SMA/SFA400: smaller than or equal to 20 A, and at least 1,2 times higher
than the reference current.
1.5.2 Minimum current:
ZMD/SMA300: 0,25 A (Iref = 5 A), 0,5 A (Iref = 10 A),
0,75 A (Iref = 15 A), 1 A (Iref = 20 A).
ZMD/ZFD/SMA/SFA400: 0,003 A (Iref = 0,3 A), 0,01 A (Iref = 1 A),
0,02 A (Iref = 2 A), 0,05 A (Iref = 5 A).
1.6 Non-essential parts
1.6.1 Pulse output
2 Seals
Both screws of the meter cover are sealed.
An example of the sealing is presented in document no. 10033/0-04.
3 Conditions for conformity assessment according to module D or F
The influence factors for temperature, frequency and voltage, which are necessary to
perform the conformity assessment according to module D or F, are presented in Annex 1,
belonging to this EU-type examination certificate.
Based on the WELMEC Guide 11.1, section 2.5.6, the sum of the square values is presented.
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Annex 1
Number T10033 revision 12
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Influence factors for temperature, frequency and voltage
During the type approval examination the influence factors for temperature, frequency and voltage
are determined per load point. The values depicted in the table below present the root sum square
values per load point, determined via the following formula:
e (T ,U , f ) e 2 (T , I , cos ) e 2 (U , I , cos ) e 2 ( f , I , cos )
with:
- e(T, I, cos ) = the additional percentage error due to the variation of the temperature at a
certain load;
- e(U, I, cos ) = the additional percentage error due to the variation of the voltage at the same
load;
- e(f, I, cos ) = the additional percentage error due to the variation of the frequency at the
same load.
ZMD/SMA300:
+23°C [%]
+40°C [%]
+55°C [%]
+70°C [%]
-40°C [%]
-25°C [%]
-10°C [%]
+5°C [%]
Current Power factor
Imin *) 1 0,6 0,5 0,5 0,5 0,1 0,7 0,7 0,9
1 0,3 0,2 0,2 0,2 0,0 0,4 0,5 0,7
Itr *) 0,5 ind. 0,3 0,3 0,3 0,3 0,1 0,6 0,7 0,9
0,8 cap. 0,3 0,2 0,2 0,2 0,1 0,4 0,5 0,6
1 0,6 0,5 0,4 0,4 0,0 0,6 0,7 0,8
Itr phase R
0,5 ind. 0,6 0,5 0,4 0,5 0,1 0,7 0,8 1,0
1 0,1 0,1 0,1 0,1 0,1 0,2 0,3 0,5
Itr phase S
0,5 ind. 0,2 0,3 0,2 0,2 0,1 0,2 0,4 0,6
1 0,1 0,1 0,1 0,1 0,1 0,2 0,3 0,4
Itr phase T
0,5 ind. 0,2 0,2 0,2 0,2 0,1 0,2 0,4 0,6
1 0,1 0,1 0,1 0,1 0,1 0,2 0,3 0,5
10 Itr *) 0,5 ind. 0,2 0,2 0,2 0,2 0,1 0,3 0,4 0,6
0,8 cap. 0,1 0,0 0,0 0,0 0,0 0,2 0,3 0,4
1 0,2 0,1 0,1 0,1 0,1 0,2 0,3 0,5
10 Itr phase R
0,5 ind. 0,2 0,2 0,2 0,2 0,2 0,3 0,4 0,6
1 0,1 0,1 0,1 0,1 0,0 0,2 0,3 0,5
10 Itr phase S
0,5 ind. 0,2 0,2 0,2 0,2 0,1 0,2 0,4 0,7
1 0,1 0,1 0,1 0,1 0,1 0,2 0,3 0,5
10 Itr phase T
0,5 ind. 0,2 0,2 0,2 0,2 0,1 0,3 0,4 0,6
1 0,1 0,1 0,1 0,1 0,1 0,2 0,3 0,5
Imax *) 0,5 ind. 0,2 0,2 0,2 0,2 0,2 0,3 0,4 0,6
0,8 cap. 0,1 0,0 0,0 0,0 0,0 0,2 0,3 0,4
1 0,2 0,1 0,1 0,1 0,1 0,2 0,3 0,5
Imax phase R
0,5 ind. 0,2 0,2 0,2 0,2 0,2 0,3 0,4 0,7
1 0,1 0,1 0,1 0,1 0,0 0,2 0,3 0,5
Imax phase S
0,5 ind. 0,3 0,3 0,2 0,2 0,1 0,3 0,4 0,7
1 0,1 0,1 0,1 0,1 0,1 0,2 0,3 0,5
Imax phase T
0,5 ind. 0,2 0,2 0,2 0,2 0,2 0,3 0,4 0,6
*) These values can be taken in case of single phase – two wire applications.
In case of two phase – three wire applications the values for the applicable phases are taken
into account.
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Annex 1
Number T10033 revision 12
Project number SO16203981
Page 2 of 2
ZMD/ZFD/SMA/SFA400:
+23°C [%]
+40°C [%]
+55°C [%]
+70°C [%]
-40°C [%]
-25°C [%]
-10°C [%]
+5°C [%]
Current Power factor
Imin *) 1 0,4 0,3 0,2 0,1 0,1 0,1 0,2 0,2
1 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,2
Itr *) 0,5 ind. 0,4 0,3 0,2 0,1 0,1 0,1 0,2 0,3
0,8 cap. 0,3 0,2 0,2 0,1 0,0 0,1 0,1 0,2
1 0,4 0,3 0,2 0,1 0,1 0,1 0,2 0,2
Itr phase R
0,5 ind. 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,3
1 0,3 0,3 0,2 0,1 0,0 0,1 0,1 0,2
Itr phase S
0,5 ind. 0,4 0,3 0,2 0,1 0,1 0,1 0,2 0,2
1 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,2
Itr phase T
0,5 ind. 0,5 0,4 0,3 0,2 0,1 0,2 0,3 0,4
1 0,4 0,3 0,2 0,1 0,1 0,1 0,2 0,2
20 Itr *) 0,5 ind. 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,3
0,8 cap. 0,3 0,2 0,2 0,1 0,0 0,1 0,1 0,2
1 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,2
20 Itr phase R
0,5 ind. 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,3
1 0,3 0,2 0,2 0,1 0,0 0,1 0,1 0,2
20 Itr phase S
0,5 ind. 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,2
1 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,2
20 Itr phase T
0,5 ind. 0,5 0,4 0,3 0,1 0,1 0,1 0,2 0,3
1 0,3 0,3 0,2 0,1 0,0 0,1 0,2 0,2
Imax *) 0,5 ind. 0,4 0,3 0,2 0,1 0,1 0,1 0,2 0,2
0,8 cap. 0,3 0,2 0,2 0,1 0,1 0,1 0,2 0,2
1 0,4 0,3 0,2 0,1 0,0 0,1 0,1 0,2
Imax phase R
0,5 ind. 0,4 0,3 0,2 0,1 0,1 0,1 0,2 0,3
1 0,3 0,2 0,2 0,1 0,0 0,1 0,2 0,2
Imax phase S
0,5 ind. 0,4 0,3 0,2 0,1 0,0 0,1 0,1 0,2
1 0,4 0,3 0,2 0,1 0,0 0,1 0,2 0,2
Imax phase T
0,5 ind. 0,4 0,3 0,2 0,2 0,1 0,1 0,2 0,3
*) These values can be taken in case of single phase – two wire applications.
In case of two phase – three wire applications the values for the applicable phases are taken into
account.
500
Electricity Meters IEC/MID
Industrial and Commercial
SMA300AT/CT
S650 Series 3
User Manual
Date: 22.04.2016
File name: D000045597 S650 SMA300xT Series 3 User Manual en c.docx
© Landis+Gyr D000045597 en c
2/86 Revision history
Revision history
Version Date Comments
a 26.09.2012 First edition
b 29.10.2013 Synchronised document version indicators across all languages.
Updated disclaimer.
Reformatted warnings, cautions and notes.
Corrected minor terminology, spelling and punctuation errors.
Added extension board 047x to section 2.3 “Type designation”.
Added information on 3-phase, 3-wire (no neutral) connections to section 3.4
“Connection diagrams (examples)”.
Added extension board 0470 to section 3.4 “Connection diagrams (examples)”.
c 22.04.2016 Updated to firmware version B33:
Updated section 2.5.3 “Measured quantities” (TTHD and losses)
Updated section 2.5.4 “Formation of measured quantities” (TTHD and losses).
Updated section 2.6.3 “Event log”.
Updated section 5.1 “Operation with auxiliary power supply”.
Although the information contained within this document are presented in good faith and believed to be correct, Landis+Gyr (including its
affiliates, agents and employees) disclaim any and all liability for any errors, inaccuracies or incompleteness relating to the product.
Landis+Gyr makes no warranty, representation or guarantee regarding the performance, quality, durability or suitability of the products for
any particular purpose. To the fullest extent permitted by law Landis+Gyr disclaims (1) any and all liability arising out of the use of the
product, (2) any and all liability, including, but without limitation to, special, consequential and indirect damages and losses, and (3) any and
all implied warranties, including, but without limitation to, fitness for purpose and merchantability.
The information contained in this document is strictly confidential and is intended for the addressee only. The unauthorised use, disclosure,
copying, alteration or distribution of this document or the contents thereof is strictly prohibited and may be unlawful.
All product information are subject to change without notice.
© Landis+Gyr D000045597 en c – S650 Series 3 – SMA300AT/CT – User Manual
Table of contents 3/86
Table of contents
Revision history...................................................................................................................................... 2
Table of contents ................................................................................................................................... 3
About this document .............................................................................................................................. 5
1 Safety ............................................................................................................................................. 6
1.1 Safety information ..................................................................................................................... 6
1.2 Responsibilities ......................................................................................................................... 6
1.3 Safety regulations ..................................................................................................................... 7
1.4 Radio Interference .................................................................................................................... 7
2 Device description........................................................................................................................ 8
2.1 Field of application .................................................................................................................... 8
2.2 Characteristics .......................................................................................................................... 8
2.3 Type designation..................................................................................................................... 10
2.4 Block schematic diagram ........................................................................................................ 11
2.5 Measuring system ................................................................................................................... 14
2.5.1 Input signals ...................................................................................................................... 14
2.5.2 Signal processor ................................................................................................................ 15
2.5.3 Measured quantities .......................................................................................................... 17
2.5.4 Formation of measured quantities ..................................................................................... 18
2.5.5 Summation channels ......................................................................................................... 24
2.6 Data profile.............................................................................................................................. 24
2.6.1 Stored value profile ........................................................................................................... 25
2.6.2 Load profile 1 and load profile 2 (option) ........................................................................... 25
2.6.3 Event log ........................................................................................................................... 25
2.7 Communication ....................................................................................................................... 29
2.7.1 Optical interface ................................................................................................................ 29
2.7.2 Communication units ......................................................................................................... 29
2.8 MAP software tools ................................................................................................................. 30
2.9 Anti-tampering features ........................................................................................................... 31
2.9.1 DC magnet detection ......................................................................................................... 32
2.9.2 Terminal cover detection ................................................................................................... 32
3 Mechanical construction ........................................................................................................... 33
3.1 Housing ................................................................................................................................... 33
3.2 Faceplates .............................................................................................................................. 36
3.3 Connections ............................................................................................................................ 37
3.4 Connection diagrams (examples) ........................................................................................... 38
3.5 Dimensions ............................................................................................................................. 42
4 Installation and uninstallation ................................................................................................... 43
4.1 Basic information for connecting the meter ............................................................................. 43
4.1.1 Connection with 3 phases and neutral .............................................................................. 43
4.1.2 Connection with 3 phases without neutral (Aron circuit).................................................... 43
4.2 Mounting the meter ................................................................................................................. 43
4.3 Connecting the meter .............................................................................................................. 45
4.3.1 Connecting the phase connection lines ............................................................................. 46
4.3.2 Connecting the signal inputs and outputs.......................................................................... 47
4.3.3 Connecting the RS485 interface........................................................................................ 48
4.4 Check of connections .............................................................................................................. 49
4.5 Commissioning, functional check and sealing ........................................................................ 49
4.6 Installation of terminal cover detection .................................................................................... 50
4.7 Uninstallation .......................................................................................................................... 51
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5 Operation .....................................................................................................................................53
5.1 Operation with auxiliary power supply .....................................................................................53
5.2 Control elements .....................................................................................................................53
5.2.1 Display buttons ..................................................................................................................53
5.2.2 Control of display via optical interface................................................................................54
5.2.3 Reset button .......................................................................................................................54
5.3 Display .....................................................................................................................................55
5.3.1 Introduction ........................................................................................................................55
5.3.2 Basic layout ........................................................................................................................55
5.3.3 Index system ......................................................................................................................56
5.4 Types of display .......................................................................................................................57
5.4.1 Operating display ...............................................................................................................57
5.4.2 Display menu .....................................................................................................................58
5.4.3 Service menu .....................................................................................................................61
5.5 Alert LED .................................................................................................................................62
5.6 Optical test output ....................................................................................................................62
5.7 Data readout ............................................................................................................................63
5.7.1 Readout to IEC 62056-21 ..................................................................................................63
5.7.2 Readout to DLMS...............................................................................................................65
5.8 Input of formatted commands ..................................................................................................66
5.9 Set time and date, ID numbers, battery time ...........................................................................67
6 Service .........................................................................................................................................68
6.1 Operating faults .......................................................................................................................68
6.2 Error messages .......................................................................................................................68
6.2.1 Structure of an error message ...........................................................................................69
6.2.2 Error groups .......................................................................................................................69
6.3 Repairing meters .....................................................................................................................74
7 Maintenance ................................................................................................................................75
7.1 Meter testing ............................................................................................................................75
7.1.1 Test mode ..........................................................................................................................75
7.1.2 Measuring times .................................................................................................................75
7.1.3 Optical test output ..............................................................................................................76
7.1.4 No-load test ........................................................................................................................77
7.1.5 Starting test active part ......................................................................................................77
7.1.6 Starting test reactive part ...................................................................................................78
7.2 Changing the battery ...............................................................................................................78
8 Disposal .......................................................................................................................................80
9 Index .............................................................................................................................................81
Appendix 1 OBIS code ..................................................................................................................84
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About this document
Range of validity The present user manual applies to the meters specified on the title page.
Purpose The user manual contains all the information required for metering
applications for the intended purpose. This includes:
Provision of knowledge concerning the characteristics, construction
and function of the meters
Information about potential dangers, their consequences and
measures to prevent any danger
Details about the performance of all activities throughout the service
life of the meters (parameterisation, installation, commissioning,
operation, maintenance, decommissioning and disposal)
Target group The content of this user manual is intended for technically qualified
personnel of utilities (energy supply companies), responsible for system
planning, installation and commissioning, operation, maintenance,
decommissioning and disposal of meters.
Reference documents The following documents provide further information related to the subject
of this document:
D000045768 "S650 SMA300AT/CT Series 3 Technical Data"
D000030112 "E650 ZxD/S650 SxA Series 3 Functional Description"
Conventions The structure and significance of meter type designations are described in
section 2.3 "Type designation". The following conventions are employed in
this user manual for representing type designations:
The lower case letter "x" can be used as an unknown to indicate
different versions (e.g. SMA310xT for the SMA310AT and SMA310CT
meters).
The following collective terms are also sometimes used instead of the
type designation:
– "Active energy meters" for the SMA300AT meters
– "Combi-meters" for the SMA300CT meters
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1 Safety
This section describes the safety information used in this manual, outlines
the responsibilities and lists the safety regulations to be observed.
1.1 Safety information
The following symbols are used to draw your attention to the relevant
danger level, i.e. the severity and probability of any danger, in the individual
sections of this document.
Warning
Used to indicate a dangerous situation that could cause bodily injury or
death.
Caution
Used to indicate a situation/ action that could result in material damage or
loss of data.
Note
Used to indicate general guidelines and other useful information.
In addition to the danger level, safety information also describes the type
and source of the danger, its possible consequences and measures for
avoiding the danger.
1.2 Responsibilities
The owner of the meters – usually the utility company – is responsible for
ensuring that all persons working with meters:
Have read and understood the relevant sections of the user manual.
Are appropriately qualified for the work to be performed.
Strictly observe the safety regulations (laid down in section 1.3) and
the operating instructions as specified in the individual sections.
In particular, the owner of the meters bears responsibility for the protection
of persons, prevention of material damage and the training of personnel.
For this purpose, Landis+Gyr provides training on a variety of products and
solutions. Contact your local Landis+Gyr representative if interested.
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1.3 Safety regulations
The following safety regulations must be observed at all times:
The meter connections must be disconnected from all voltage sources
during installation or when opening.
Contact with live parts can be fatal. The relevant supply fuses should,
therefore, be removed and kept in a safe place until the work is
completed so that other persons cannot replace them unnoticed.
Local safety regulations must be observed. Only technically qualified
and appropriately trained personnel are authorised to install the
meters.
Only appropriate tools shall be used for the job. This means, e.g. that
the screwdriver must be of the correct size for the screws, and the
handle of the screwdriver must be insulated.
The meters must be held securely during installation. They can cause
injuries if dropped.
Meters that have been dropped must not be installed, even if no
damage is apparent, but must be returned to the service and repair
department (or the manufacturer) for testing. Internal damage may
result in malfunctions or short-circuits.
The meters must never be cleaned under running water or with
compressed air. Water ingress can cause short-circuits.
1.4 Radio Interference
Possible radio interference in residential environments
This meter is normally a class B product. In combination with some
communication modules it can become a Class A product. In a domestic
environment, this may then cause radio interference, in which case the user
may be required to take adequate measures.
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2 Device description
This section provides you with a brief overview of the design and function of
the S650 SMA300AT/CT meters (smart grid terminals).
2.1 Field of application
SMA300xT meters can be used for direct connection at the low voltage
level. They are primarily used by medium consumers.
SMA300xT meters have a comprehensive tariff structure. This extends
from seasonal tariffs to multiple energy and demand tariff rates.
SMA300xT meters are well suited for street light applications with
embedded astronomical clock and combinations of control saving signals
coming from light sensors, measurements or other digital inputs.
SMA300CT combi-meters record active and reactive energy consumption,
SMA300AT active energy meters only the active energy in three-phase
four-wire networks on low voltage, and from this determine the required
electrical measured quantities. They are connected directly to the phase
conductors at the measuring point.
The data determined are displayed (LCD) and are also available at the
optical interface for data acquisition, with an appropriate communication
unit also as required via CS, RS232, RS485, PSTN modem, GSM modem,
etc. When equipped with transmitting contacts, the meters can also be
used as transmitting meters for telemetering. The tariff rates can be
controlled internally or externally.
With a communication unit, the meters can also be used for recording
counter pulses for other physical media (e.g. water or gas volumes).
2.2 Characteristics
SMA300xT meters have the following basic characteristics:
Recording of active, reactive and apparent energy in all four quadrants
(SMA300CT)
Tariff system with energy and demand tariff rates, stored values, load
profiles, etc.
Astronomical clock generating 2 energy saving signals to control 2
relays outputs, if option selected
Extended functions such as monitoring functions, sliding maximum
demand, (for SMA300CT additionally power factor and displacement
power factor), voltage/current unbalance
Tariff control
– External
- via control inputs (SMA300xT21 and SMA300xT41)
- via communication interfaces using formatted commands
– Internal
- by integral time switch (SMA300xT24 and SMA300xT44)
- by event signals based on monitored values, such as voltage,
current and demand.
Display of data on a liquid crystal display (LCD)
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Active and reactive power per phase and true RMS values of voltages
and currents by means of digital signal processing (DSP) chips
Accuracy: Compliance with IEC class 1 and with MID accuracy class B
for active energy consumption (SMA310xT) and IEC class 1 for
reactive energy (SMA310CT).
Flexible measuring system through parameterisation (definition of
different variables by software)
Correct measurement even with failure of individual phases, or when
used in two- or single-phase networks
Wide range of measurement from starting current to maximum current
Optical interface according to IEC 62056-21 and DLMS
– For direct readout of meter data
– For service functions of the meter, extension board and
communication unit (e.g. parameterisation)
Inputs for recording fixed valence pulses (communication unit)
Output contacts (solid-state relays) for fixed valence pulses, control
signals and status messages
Output contacts (relays) for control signals and status messages
Input contact for alarm monitoring and sending advanced SMS
messages, if suitable optional communication unit selected
Installation aids
– Indication of phase voltages, phase angles, rotating field and
direction of energy
Storage of event information, e.g. voltage failures, exceeding of thresh-
olds or error messages. Event information can be read out via the
available interfaces. Important events can be communicated to the
energy supply company as operational messages (sending of
advanced SMS messages, control of an arrow in the display, drive for
an output contact, etc.).
Interfaces such as CS, RS232, RS485, modem, etc. for remote trans-
mission of data (communication unit)
Auxiliary power supply for communication with the meter if no
measuring voltage is present
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2.3 Type designation
SMA 3 10 C T 44 4207 S3
Network type
SMA 3-phase, 4-wire network (M-circuit)
Connection type
3 Direct connection
Accuracy class
10 Active energy class 1 (IEC), B (MID)
Measured quantities
C Active and reactive energy
A Active energy
Construction
T With exchangeable communication units
Tariffication
21 Energy rates, external rate control via control inputs
24 Energy rates, internal rate control via time switch
(additionally possible via control inputs)
41 Energy and demand rates, external rate control via control inputs
44 Energy and demand rates, internal rate control via time switch
(additionally possible via control inputs)
All versions with 3 control inputs and 2 output contacts
Additional functions
000x No extension board
060x 6 outputs
240x 2 control inputs, 4 outputs
326x 3 control inputs. 2 relays outputs, auxiliary power supply 12–24 VDC
420x 4 control inputs, 2 outputs
045x 4 outputs, auxiliary power supply 100–240 VAC/VDC
046x 4 outputs, auxiliary power supply 12–24 VDC
047x 4 outputs, auxiliary power supply 12–60 VDC
008x Supercapacitor board
xxx0 No additional functions
xxx2 DC magnet detection
xxx7 Load profile
xxx9 DC magnet detection and load profile (integrated terminal cover switch option only available
in this configuration)
Series 3
The communication unit is not a part of this type designation, since it is a
complete unit in itself. Users can change it at any time without opening the
certification seal. Every communication unit has its own user manual.
Series designation S3 (Series 3) represents the newest hardware generation.
Firmware version The firmware version and firmware checksum stored in the meter can be
shown on the display or read out as IEC readout list, if parameterised
accordingly (see section 5.7 "Data readout"). Specific meter characteristics
are present or not depending on the firmware version.
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2.4 Block schematic diagram
This section provides an overview of the function of SMA300xT meters
based on a block schematic diagram.
Figure 1. Block schematic diagram SMA300xT
The SMA300AT active energy meters record the imported and exported
active energy consumption, while the SMA300CT combi-meters record the
active and reactive energy consumption in all four quadrants.
The SMA300xT meters can be fitted with modular communication
interfaces in a communication unit, which can be exchanged or used in the
field as required.
Inputs The main meter inputs are:
Connections of phase voltages (U1, U2, U3), phase currents (I1, I2, I3)
and neutral conductor N
– For processing in the measuring system
– For the three-phase power supply to the meter and voltage monitor
Control inputs Ut (3 fixed, plus up to 4 others on extension board) for:
– Changeover of energy and demand tariff rates
– Resetting
– Demand inhibition
– Synchronising
Optocouplers protect the internal circuitry from interference, which
could otherwise enter via the control inputs.
Buttons
– For display control (display buttons, optical interface)
– For resetting or service functions (reset button)
Pulse inputs for connection of external pulse transmitters (only for
meters equipped with a communication unit)
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Outputs The meter has the following outputs:
LCD display with buttons for local reading of billing data (single 8-digit
display with additional information, such as energy direction, energy
type, presence of phase voltages and identification number)
Optical test outputs (red, 1 in active energy meters, 2 in combi-meters)
Optional alert LED (red) to indicate alerts on the front face of the meter
Static relay with freely parameterised signal assignment (2 fixed, plus
up to 6 others on the extension board)
Relay outputs with limited parameterised signal assignment due to
limited life expectancy (up to 2 on the extension board)
Optical interface for automatic local data acquisition by a suitable
acquisition unit (handheld terminal)
Communication interfaces of various kinds in the communication unit (also see
section 0 "* Firmware version B33 or higher.
Communication)
Measuring system The input circuits (voltage dividers and current shunts with voltage
transformer) record voltage and current in the individual phases. Analogue-
digital converters digitise these values and feed them as instantaneous
digital values via calibration stages to a signal processor.
Signal processing The signal processor determines the following measured quantities from
the instantaneous digital values of voltage and current for each phase and
forms their mean value over one second:
Active power per phase
Reactive power per phase (combi-meters SMA300CT only)
Phase voltages
Phase currents
Network (mains) frequency
Phase angles
Signal utilisation For signal utilisation in the various registers, the microprocessor scans the
measured quantities every second to determine the following values:
Active energy (sum and individual phases, separated according to
energy direction, if required in the combi-meters SMA300CT also
assigned to the 4 quadrants)
Reactive energy (only for combi-meters SMA300CT, sum and
individual phases, separated according to energy direction, assigned
to the 4 quadrants)
Apparent energy (only for combi-meters SMA300CT, sum and
individual phases, separated according to energy direction)
Power factor and displacement power factor cosφ (only for combi-
meters SMA300CT, individual phases and mean value)
Phase voltages
Phase currents and neutral current
Voltage and current unbalance
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Active and reactive power
Direction of rotating field
Total harmonic distortions of active energy, voltage and current
Rate control Rate control is performed:
Externally via control inputs (3 fixed, plus up to 4 others on the
extension board)
Externally via communication interfaces using formatted commands
Internally by time switch and calendar clock
By event signals based on threshold values of the monitoring functions
Data preparation for The following registers are available for evaluation of the individual
billing measured values:
32 for energy rates
27 for total energy
10 for running mean demand values
24 for demand rates
2 for power factors (combi-meters SMA300CT only)
Up to 41 diagnostic registers
Others for values of voltage and current, network frequency and phase
angles
Memory A non-volatile flash memory serves to record data profiles and also
contains the configuration and parameterisation data of the meter and
secures the billing data against loss due to voltage failures.
Power supply The supply voltages for the meter electronics are obtained from the three-
phase network, whereby the phase voltage can vary over the entire voltage
range without the supply voltage having to be adjusted. A voltage monitor
ensures correct operation and reliable data recovery in the event of a power
failure and correct restarting when the voltage is restored.
Auxiliary power For medium or high-voltage applications in particular, the measuring
supply voltage can be switched off. Since the meter normally obtains its supply
from the measuring voltage, it is also switched off and cannot be read. The
auxiliary power supply connected in parallel with the normal power supply
ensures operation of the meter free from interruption, so that it can be read
at any time. The auxiliary power supply is situated on an extension board.
Extension board The extension board is fitted inside the meter and is secured by the
certification seals. It cannot be exchanged. It can have the following
components:
Up to 4 control inputs in combination with
Up to 6 output contacts (solid-state relays)
Up to 2 relays outputs
An auxiliary power supply
A supercapacitor board
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Communication unit The communication unit for fitting only in the SMA300xT meters is a
complete unit in its own case. If present, it is situated behind the front door,
and is therefore secured by a utility seal and can be exchanged or inserted
in the field if necessary. It contains:
Communication interfaces as required for remote readout of the meter
(e.g. CS, RS232, RS485, modem)
Two signal inputs (S0 interfaces) for processing external pulse
transmitters
2.5 Measuring system
Figure 2. Block schematic diagram of measuring system
2.5.1 Input signals
The meter has the analogue current values I1, I2 and I3 and analogue
voltage values U1, U2 and U3 available as input signals.
SMA300xT
Figure 3. Type of measurement SMA300xT
Since the SMA300xT measures the individual phases mutually
independently with one measuring element each, it can record the sum of
the three phases, the individual phases themselves, the phase angle
between voltage and current as well as the angle between voltages U1–U2
and U1–U3.
Voltage input High resistance voltage dividers reduce the voltages U1, U2 and U3 (58 to
240 V) applied to the meter to a proportionate amount of a few mV (UU) for
further processing.
Current input Internal current transformers reduce the input currents I1, I2 and I3 to the
meter (0 to 10 A) for further processing. The secondary currents of these
current transformers develop voltages proportional to the input currents
across resistors, also of a few mV (UI).
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2.5.2 Signal processor
Figure 4. Principle of signal processor
SMA300AT active energy meters do not measure reactive energy.
Digitising The analogue signals Ux and Ix are digitised in Sigma-Delta converters
(analogue-digital converters with highest resolution) with a sample rate of
1.6 kHz and then filtered. A following calibration stage compensates for the
natural errors of the voltage divider or current transformer, so that no
further adjustment is necessary in the subsequent processing.
Calibrated digital instantaneous values of voltage (u) and current (i) for all
three phases are then available as intermediate values for the formation of
the required values in the signal processor.
Calculation of active The instantaneous value of active power p is produced by multiplying the
power instantaneous values of voltage u and current i (the active component
corresponds to the product of voltage component with the current
component parallel to the voltage). Thereby the harmonics up to 1 kHz are
measured correctly.
IQ I
Calculation per phase of
P = U . I . cos
IP U
Figure 5. Active power calculation
Instantaneous power If the meter is parameterised to calculate instantaneous power as signed
with sign values, the following values of power are available:
Active P: + in QI and QIV, - in QII and QIII
Reactive P: + in QI and QII, - in QIII and QIV
Calculation of reactive There are two possibilities to calculate the instantaneous value of reactive
power power (SMA300Cx combi-meters only):
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Measured:
For the instantaneous value of reactive power q, the instantaneous value of
voltage u must be rotated by 90° before multiplication (the reactive
component is the product of the voltage component with the current
component vertical to the voltage). Thereby, no harmonics are measured
since only the fundamental wave is rotated through 90°.
IQ I
Calculation per phase of
Q = U . I . sin
IP U
Figure 6. Reactive power calculation (method: measured)
Calculated vectorial (not recommended):
The instantaneous value of reactive power is calculated using the values of
active power and apparent power.
The reactive power is the square root of the square value of apparent
power minus the square value of active power. This method includes the
harmonics.
URMS, IRMS calculation The square values of voltage and current are obtained by multiplying the
instantaneous values of voltage and current by themselves. From these
values the signal processor forms the corresponding single-phase RMS
values URMS and IRMS.
Time measurement The network frequency can be calculated from the time measured between
two zero passages (change from negative to positive value of voltage U1).
The times between zero passage of the phase voltage U1 and those of the
other phase voltages U2 and U3 serves to determine the phase angle
between the voltages and of the rotating field.
U1 U2 U3 Time measurement
for rotating field,
frequency, phase angle
1 : T U1-U2
2 : T U1-U3
1
2
3 : TU1-U1 (fn)
3
Figure 7. Time measurement
The phase angle between voltage and current is determined by the times
between zero passage of the phase voltage U1 and those of the phase
currents I1, I2 and I3.
Mean value formation For further processing of the individual signal, the signal processor
generates mean values over one second, which the following
microprocessor scans at intervals of one second.
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2.5.3 Measured quantities
Measured quantity SMA300
Active energy in quadrant I A (QI) Sum / Phases
Active energy in quadrant II A (QII) Sum / Phases
Active energy in quadrant III A (QIII) Sum / Phases
Active energy in quadrant IV A (QIV) Sum / Phases
Active energy import +A (QI+QIV) Sum / Phases
Active energy export –A (QII+QIII) Sum / Phases
Active energy, absolute value +A+-A Sum / Phases
Active energy, absolute value +A--A Sum / Phases
Active energy import summation Σ +A Sum
Active energy export summation Σ -A Sum
Active energy by single quantity Σ ALx Sum
Reactive energy in quadrant I R (QI) Sum / Phases
Reactive energy in quadrant II R (QII) Sum / Phases
Reactive energy in quadrant III R (QIII) Sum / Phases
Reactive energy in quadrant IV R (QIV) Sum / Phases
Reactive energy import +R (QI+QII) Sum / Phases
Reactive energy export –R (QIII+QIV) Sum / Phases
Reactive energy import +R (QI+QIV) Sum / Phases
Reactive energy export –R (QII+QIII) Sum / Phases
Reactive energy, combined R (QI+QIII) Sum / Phases
Reactive energy, combined R (QII+QIV) Sum / Phases
Reactive energy, absolute value +R+-R Sum / Phases
Reactive energy, absolute value +R--R Sum / Phases
Reactive energy import summation Σ +R Sum
Reactive energy export summation Σ -R Sum
Apparent energy import +S (QI+QIV) Sum / Phases
Apparent energy export -S (QII+QIII) Sum / Phases
Phase voltages (RMS) U1, U2, U3
Phase voltages (RMS) U12, U23, U31
Phase currents (RMS) I1, I2, I3
Neutral current I0 yes
Network frequency fn yes
Active power ±P Sum / Phases
Reactive power ±Q Sum / Phases
Phase angle between voltages U U1-U2 / U1-U3*
Phase angle between voltage and U-I U1-I1, U1-I2, U1-I3 *
current or
U1-I1, U2-I2, U3-I3
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Measured quantity SMA300
Power factor PF Sum / Phases
Displacement power factor cosφ Sum / Phases
Voltage unbalance ∆U yes
Current unbalance ∆I yes
Direction of rotating field yes
THD of active energy import +THDA Sum
THD of active energy export -THDA Sum
THD of active energy (percent) THDA [%] Sum
THD of phase voltages (absolute) THDU Phase 1, 2, 3
THD of voltage (percent) THDU [%] Sum
THD of phase currents (absolute) THDI Phase 1, 2, 3
THD of current (percent) THDI [%] Sum
TTHD of active power TTHDA [0;1] Sum
TTHD of phase current TTHDV [0:1] Phase 1, 2, 3
TTHD of phase voltage TTHDI [0:1] Phase 1, 2, 3
TTHD of voltage TTHDV [0:1] Sum
TTHD of current TTHDI [0:1] Sum
Line (copper) losses of active OLA Sum
energy **
Transformer (iron) losses of active NLA Sum
energy **
Signed line (copper) losses of ±OLA Sum
active energy **
Signed transformer (iron) losses of ±NLA Sum
active energy **
Voltage square hours U2h Sum
Ampere square hours I2h Sum
* Only if U1 is present.
** Firmware version B33 or higher. OLA/NLA not accessible, if
±OLA/±NLA selected.
2.5.4 Formation of measured quantities
By scanning the mean values of active power P, and in combi-meters also
reactive power Q every second, energy components are produced (Ws or
vars) at fixed intervals (every second) and with varying energy magnitudes
or demand. These energy components are scaled by the microprocessor
corresponding to the meter constant and are then available as measured
quantities for selection of the measured values. The measured values are
fed directly to the following registers to record the energy and the maximum
demand (in combi-meters also of minimum power factor).
Active energy The active energy in the individual phases ±A1, ±A2 and ±A3 are formed
directly from the mean values of active power P1, P2 and P3.
By summating the mean values of active energy A1, A2 and A3 the
microprocessor calculates the total active energy import +A or the total
active energy export -A.
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Mean values
per second Measured quantities
± A1
+A (Import)
±A 2 -A (Export)
±A3
Figure 8. Total active energy
Reactive energy The reactive energy values of the individual phases ±R1, ±R2 and ±R3 are
obtained in the combi-meters directly from the mean values of reactive
power Q1, Q2 and Q3. The reactive energy can therefore also be
calculated vectorially (see 2.5.2).
By summating the mean values of reactive energy R1, R2 and R3, the
microprocessor calculates the total positive reactive energy +R or the total
negative reactive energy -R.
Mean values
per second Measured quantities
± R1
+R
±R2 -R
±R3
Figure 9. Total reactive energy
The microprocessor can allocate the reactive energy to the 4 quadrants in
the combi-meters from the signs of R and A:
Reactive energy in 1st quadrant: +Ri
Reactive energy in 2nd quadrant: +Rc
Reactive energy in 3rd quadrant: –Ri
Reactive energy in 4th quadrant: –Rc
In the same way, it can allocate the reactive energy of the individual phases
to the 4 quadrants.
+R
+ kvarh + kvarh
+Rc +Ri
Quadrant II Quadrant I
Export -A +A Import
- kWh Quadrant III Quadrant IV + kWh
- kvarh
-Ri -Rc - kvarh
-R
Figure 10. 4-quadrant measurement
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The quadrants are numbered from top right as 1st quadrant (+A/+Ri) anti-
clockwise to the 4th quadrant (+A/–Rc) at bottom right.
Apparent energy The apparent energy is calculated in the combi-meters in two ways:
By vectorial addition of the active and reactive energy of the individual
phases
By multiplying the rms values of voltage and current of the individual
phases
The method of calculation can be parameterised (only one possible in each
case).
Calculation method 1 From the mean values A1, A2 and A3 and R1, R2 and R3, the
(vectorial addition) microprocessor calculates the apparent energy of the individual phases
±S1, ±S2 and ±S3 as well as the total apparent energy ±S.
Mean values
per second
±A1
±A2 Measured quantities
±A3
2 2 +S (Import)
(A1 + A2 + A3) + (R1 + R2 + R3)
±R1 -S (Export)
±R2
±R3
Figure 11. Total apparent energy according to calculation method 1
Only fundamental wave considered for reactive energy
Only the fundamental wave is considered for the calculation of the reactive
energy share; possible harmonics are not taken into account.
Calculation method 2 From the mean values U1rms, U2rms, U3rms and I1rms, I2rms, I3rms, the
(from rms values) microprocessor calculates by multiplication the apparent power of the
individual phases ±VA1, ±VA2 and ±VA3 and summates these for the total
apparent power ±VA.
Mean values
per second
I1rm s
U1rm s
I1rm s U1 rm s
å Measured quantities
I2rm s +S (Import)
U2rm s
I2rm s U2 rm s
å -S (Export)
I3rm s
U3rm s
I3rm s U3 rm s
å
Figure 12. Total apparent power according to calculation method 2 (SMA300Cx
combi-meters only)
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Harmonics considered for reactive energy
As RMS values are used for the calculation of the apparent energy with
calculation method 2, not only the fundamental wave but also the
harmonics are taken into account. Therefore, if harmonics are present, the
measured values are greater than those of calculation method 1.
Summation channels The values of two measurement quantities (incl. pulse inputs EX1 and EX2)
can be added.
Power factor The power factor (PF) is calculated in combi-meters as follows:
The meter uses the method of calculation employed for calculating the
apparent power.
The PF calculation includes harmonics versus the displacement power
factor cosφ.
In case of high harmonic perturbations, the difference between PF and
cosφ can be significant.
For instance, THD I ~50% involves PF 10% lower than cosφ.
Displacement The displacement power factor (dPF) cosφ is calculated in combi-meters as
power factor cosφ follows:
It takes into account only the fundamental wave versus PF that includes
rms values.
Phase voltages The rms values of the voltages U1rms, U2rms and U3rms are obtained from
the mean values of the squares of the voltages by extracting the root and
directly from these the phase voltages U1, U2 and U3.
U12, U23 and U31 voltages are computed from U1, U2 and U3.
Voltage unbalance The voltage unbalance is computed according to the ratio of the maximum
difference between phase voltage maximum and averaged 3 phase
voltage.
| – |
∗ 100
3
Phase currents The rms values of the currents I1rms, I2rms and I3rms are obtained from the
mean values of the squares of the currents by extracting the root and
directly from these the phase currents I1, I2 and I3.
Current unbalance The current unbalance is computed according to the maximum difference
between maximum phase current and averaged 3 phase current.
| – |
∗ 100
3
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Neutral current The signal processor calculates the instantaneous neutral current i0 by
adding the instantaneous phase currents i1, i2 and i3.
i2
i0 = i1 + i2 + i3
i1 (vectorial addition)
i3
i0
Figure 13. Neutral current I0
Network frequency The signal processor calculates the network frequency fn by forming the
reciprocal from the time tU1-U1 between two zero passages of voltage U1.
Phase angles The signal processor calculates the phase angles between voltages U1-U2
and U1-U3 from the times tU1-U1, tU1-U2 and tU1-U3 between zero passages of
the various voltages.
The signal processor calculates the phase angle between voltage U1 and
current per phase from the times tU1-I1, tU1-I2 and tU1-I3 between zero
passages of the voltage U1 and the phase currents.
Two forms of representation are available for displaying the phase angle.
These can be selected by parameterisation.
Case 1: All voltage and current angles are displayed clockwise with
reference to the voltage in phase 1. The values of the angles are always
positive and can be from 0 to 360°.
Figure 14. Phase angle case 1
Case 2: The voltage angles are displayed as in case 1. The angles of the
currents are displayed, however, with reference to the associated phase
voltage and can have values between -180° and +180°.
Figure 15. Phase angle case 2
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Direction of rotating The direction of the rotating field is calculated by the microprocessor based
field on the phase angle of the 3 voltages. If the direction of rotation
corresponds to that specified by the parameterisation, the phase voltage
indications L1, L2 and L3 are continuously lit. Otherwise they flash every
second.
Total harmonic The measuring system produces information about the total harmonic
distortion distortion of the active energy.
For that purpose, the voltages are fed through notch filters, which remove
the fundamental wave.
+A +THDA
+THD A = +A - (+A fundamental)
-A -THDA
-THD A = -A - (-A fundamental )
Figure 16. Calculation of total harmonic distortion
In addition, the following absolute and relative THD values available:
THD of active energy (relative to the nominal active energy)
THD of phase voltages (absolute)
THD of voltage (relative to the nominal voltage)
THD of phase currents (absolute)
THD of phase current (relative to the nominal current)
True total harmonic The TTHD information is calculated based on a comparison of the values of
distortion the harmonic contents and the value of the fundamental (in firmware
version B33 or higher).
TTHD of active power
TTHD of phase voltage
TTHD of phase current
TTHD of voltage
TTHD of current
Losses (firmware Depending on the metering point in the network, the meter does not only
version B33 or higher) measure the net energy that is transferred from the power station to the
user but also the line losses (caused by the copper resistance RCu) and the
transformer losses (caused by the iron resistance RFe).
Metering point A Metering point B Metering point C
RFe
RCu
Generator Load
Transmission
Production Meter A Meter B Customer
Figure 17. Calculation of Losses
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Line losses are caused by the copper resistance RCu of the transmitting
line. The copper resistance is only effective if there is a load and therefore
current is actually flowing.
On Load Active OLA for line losses of active energy
The transformer losses represent all losses of the transformer. They are
mainly caused by the iron core of the transformer. Transformer losses
(equivalent resistance RFe) are present whenever the transformer is
connected to the network.
No Load Active NLA for transformer losses of active energy
Based on the IRMS and URMS values, the microprocessor generates the
following measured quantities:
OLA On load active. Line (copper) losses of active energy.
OLA = I2h x RCu. The value of RCu can be set by parameterisation.
NLA No load active. Transformer (iron) losses of active energy.
NLA = U2h / RFe. The value of RFe can be set by parameterisation.
I2h (Cu) Ampere square hours (with RCu = 1)
2
U h (Fe) Voltage square hours (with RFe 1 M)
It is also possible to track signed losses (±NLA/OLA). If this option is
chosen, NLA and OLA losses are not available any more as these registers
are used for signed losses.
2.5.5 Summation channels
The values of two measurement quantities (incl. pulse inputs EX1 and EX2)
can be added. The added quantities must be of the same energy type
(active, reactive or apparent). The sum is stored in a total energy register.
Energy registers which contain the summation of two measured quantities
(summation channels) cannot be used for tariffication.
ME1
EX1
EX2
MExx
+ Total energy register
Figure 18. Summation channels
2.6 Data profile
A non-volatile memory (FLASH memory) contains the data of:
The stored value profile
The load profile 1
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The load profile 2 (optional)
The event log
The three groups of dedicated event logs
The flash memory stores data without data loss in case of voltage failures.
No battery is required for this purpose.
The total size of the available memory for the stored billing value profile, the
load profile(s), the event log and the dedicated event logs is 1.8 MB.
2.6.1 Stored value profile
At the end of the billing period, the meter stores the current value of the
registers to the stored value profile. Which energy registers and/or demand
registers are stored to the stored billing value profile can be selected by
parameterisation.
Memory organisation The stored value profile is organised as a circular buffer, i.e. the oldest
entry will be overwritten by the most recent entry. The memory capacity
which is available for the stored value profile depends on parameterisation.
2.6.2 Load profile 1 and load profile 2 (option)
The load profiles are used to save the values of various registers at regular
intervals. The measured values that are captured in the load profile can be
selected by parameterisation.
Load profile 2 is optional
The second load profile is optional.
Consult your sales representative for further details.
Profile 1 The first load profile is generally used for billing purposes. Its capture
period has a range of 1...60 min. This load profile may also contain
instantaneous values and detailed status information for data processing in
central stations.
Profile 2 The second load profile can be used to store instantaneous values over a
period which differs from the period of the first load profile. Apart from the
differing capture period, the second load profile is identical with the first
load profile.
Memory organisation The load profile is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry. The memory capacity which is
available for the load profile(s) depends on parameterisation. If both load
profiles are activated, they share the memory capacity which is allocated to
the load profile(s).
2.6.3 Event log
Events that occur sporadically are stored in the event log. The user may
select which events trigger an entry in the event log. The event log is used
to analyse the behaviour of the network as well as to supervise the correct
function of the meter.
Memory organisation In the event log, a maximum of 500 event entries can be stored. The
individual entries consist of the time stamp and the event number.
Additional information such as the error register or energy total registers
can also be stored with every event.
The event log is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry.
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Dedicated event log Network quality events, can be stored in the dedicated event log. The
dedicated event log consists of three groups of logs.
Overvoltage events
Undervoltage events
Missing voltage events
In the dedicated event logs, important information can be stored per entry
such as:
Duration of the events
Extreme values of the events (not for missing voltage).
Instantaneous values
Maximum three energy registers
Additional information can be read from the header of the event logs, such
as the longest entry, the shortest entry, the total number of occurrence and
the total duration of the event.
Memory organisation The dedicated event logs are organised as circular buffers, i.e. the oldest
entry will be overwritten by the most recent entry.
List of events The table below lists all events which can be captured in the event log.
Depending on the parameterisation, some events may never occur.
Events which can be stored in the dedicated event log are marked in the
corresponding column.
Number Event Entry in dedicated
event log possible
2 All energy registers cleared
3 Stored values and/or load profile cleared
4 Event log profile cleared
5 Battery voltage low
7 Battery ok
8 Billing period reset
9 Daylight saving time enabled or disabled
10 Clock adjusted (old time/date)
11 Clock adjusted (new time/date)
17 Undervoltage L1 (below threshold 1*) x*
18 Undervoltage L2 (below threshold 1*) x*
19 Undervoltage L3 (below threshold 1*) x*
20 Overvoltage L1 (above threshold 1*) x*
21 Overvoltage L2 (above threshold 1*) x*
22 Overvoltage L3 (above threshold 1*) x*
23 Power down
24 Power up
25 Overcurrent L1
26 Overcurrent L2
27 Overcurrent L3
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Number Event Entry in dedicated
event log possible
28 Overcurrent neutral
31 Power factor monitor 1
32 Power factor monitor 2
33-40 Demand monitors 1-8
45 Error register cleared
49 Missing voltage L1 x
50 Missing voltage L2 x
51 Missing voltage L3 x
55 Current without voltage L1
56 Current without voltage L2
57 Current without voltage L3
58 Missing additional power supply
59 All registers and profiles cleared
63 Wrong phase sequence
64 Correct phase sequence
66 Invalid clock
74 Backup memory access error
75 Measuring system access error
76 Time device access error
77 Load profile memory access error
79 Communication unit access error
80 Display board access error
81 Program checksum error
82 Backup data checksum error
83 Parameter checksum error
84 Load profile checksum error
85 Stored values checksum error
86 Event log checksum error
87 Calibration data checksum error
88 Load profile 2 checksum error
89 Invalid start-up sequence
93 Expired watchdog (general system error)
94 Communication locked
96 Wrong extension board identification
104 Count registers cleared
105 SMS delivery to GSM failed
106 Alert occurred
124 Compensation values changed
128 Energy total and rate register cleared
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Number Event Entry in dedicated
event log possible
133 Terminal cover removed
134 DC Field detected ON
179 Undervoltage L1 above threshold 1*
180 Undervoltage L2 above threshold 1*
181 Undervoltage L3 above threshold 1*
182 Overvoltage L1 below threshold 1*
183 Overvoltage L2 below threshold 1*
184 Overvoltage L3 below threshold 1*
187 Terminal cover mounted
188 DC Field detected OFF
193 Load profile 2 cleared
201 Under-voltage L12 x
202 Under-voltage L23 x
203 Under-voltage L31 x
204 Over-voltage L12 x
205 Over-voltage L23 x
206 Over-voltage L31 x
207 Voltage unbalance
208 Voltage unbalance disappeared
209 Current unbalance
210 Current unbalance disappeared
211 Control input 1 set
212 Control input 1 reset
213 Control input 2 set
214 Control input 2 reset
215 Control input 3 set
216 Control input 3 reset
217 Control input 4 set
218 Control input 4 reset
219 Control input 5 set
220 Control input 5 reset
221 Control input 6 set
222 Control input 6 reset
223 Control input 7 set
224 Control input 7 reset
225 Undervoltage L1 below threshold 2*
226 Undervoltage L2 below threshold 2*
227 Undervoltage L3 below threshold 2*
228 Undervoltage L1 above threshold 2*
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Number Event Entry in dedicated
event log possible
229 Undervoltage L2 above threshold 2*
230 Undervoltage L2 above threshold 2*
231 Undervoltage L1 below threshold 3*
232 Undervoltage L2 below threshold 3*
233 Undervoltage L3 below threshold 3*
234 Undervoltage L1 above threshold 3*
235 Undervoltage L2 above threshold 3*
236 Undervoltage L3 above threshold 3*
* Firmware version B33 or higher.
2.7 Communication
The SMA300xT meters have an optical interface for local communication
via a readout head, and a wide range of communication interfaces which
can be inserted in the meter.
2.7.1 Optical interface
The optical interface to IEC 62056-21 is a serial, bi-directional interface.
It is situated at top right on the main faceplate (also see section 3
"Mechanical construction") and serves:
For automatic local data recording by means of a suitable acquisition
unit (hand-held terminal) (see section 5.7 "Data readout")
For performing service functions, e.g. to input formatted commands
(see section 5.8 "Input of formatted commands")
As "optical button", i.e. as receiver of a light signal, e.g. generated by a
flashlight acting like the "down" display button (also see section 5.2.2
"Control of display via optical interface")
For communication with a Landis+Gyr .MAP110 service tool or a
Landis+Gyr MAP120 parameterisation tool.
2.7.2 Communication units
The communication units which can be inserted in the meter can be used:
For remote reading and for remote tariff control of meters (RS232,
RS485, CS, M-Bus, PSTN modem, GSM modem, GPRS modem,
Ethernet, etc.) or
For recording metering pulses for other physical media, such as
water, gas or heat (S0 interface).
Access via the communication interfaces is protected for specific access
levels using the meter security system by means of passwords. If the
monitoring is activated by corresponding parameterisation, communication
is inhibited for a selected time (max. 24 h) after a selected number of
password attempts with an incorrect password (max. 15). Monitoring takes
place independent of all access levels with password protection and for the
IEC W5 password.
The communication devices are accommodated in an easily exchanged
communication unit, which is plugged in behind the front door of the meter
and secured by a factory seal (also see section 3 "Mechanical
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construction"). It can be fitted and removed at any time in the field without
touching the certification seal. Landis+Gyr recommend exchanging
communication units only if the meter is separated from the network and
switched off.
An initial fitting as well as retrofitting without re-parameterisation of the
meters is possible with any version of communication unit. For fitting and
removal of the already parameterised communication units, the installation
personnel do not require any special knowledge of communications.
Modern plug connections ensure a rapid and faultless connection of the
communication units.
Figure 19. Simple fitting of the communication unit
Versions of Communication units (CU) are available in various versions. The document
communication units "Overview of Communication Applications", D000011226 contains a list of
all currently available CU-interfaces with explanations.
Further information More detailed information about Landis+Gyr communication solutions can
sources be found in the following documents.
Technical data for the various communication units
User manuals for the various communication units
Detailed application notes for numerous reference applications with
various communication units for different transmission media:
– Point-to-point Connection with internal PSTN Modem Mx
(D000011505)
– Point-to-point Connection with internal GSM Modem Gx
(D000011507)
– Etc.
All these documents as well as advisory services are available from
authorised Landis+Gyr representatives.
2.8 MAP software tools
There are two software tools available for parameterisation of the S650
meter and for communication with the meter: .MAP110 and MAP120
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Areas of application
Figure 20. Application of MAP software tools
.MAP110 The .MAP110 Service Tool covers the following applications normally
required for meter installation and in the service sector:
Billing data readout
Readout and export of profiles (load profile(s), stored values and event
log, dedicated event logs)
TOU (Time of Use) readout and modification
Billing period reset
Register and profile resets
Setting of certain parameter ranges, such as primary data, time switch,
communication parameters, etc.
Communication input settings
Communication settings for Landis+Gyr communication units readout
and modification
GSM installation aid for Landis+Gyr communication units (field
strength indicators, telephone number information, PIN-code handling)
Test SMS message transmission
Analysis and diagnostic functions
MAP120 The Landis+Gyr MAP120 software is used to parameterise the meter and
the communication unit, i.e. it is possible to read out and modify all device
parameters.
In contrast to communication devices from other manufacturers, no
additional software and training costs are incurred by the use of Landis+Gyr
communication units, since the MAP software tools support both meters
and communication units.
2.9 Anti-tampering features
The following anti-tampering features are available for SMA310xT meters:
DC magnet detection for the detection of strong magnetic fields close
to the meter. This feature is installed during the manufacturing
process.
Terminal cover detection for the detection of situations when the
terminal cover has been opened. This feature can be a retrofit or an
integrated version. The integrated version is available if the DC
magnet detection option is selected and must be integrated during
manufacturing process.
Example of integrated terminal cover switch available from mid-2012.
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2.9.1 DC magnet detection
The SMA310xT meters can be ordered with a feature which detects strong
DC magnetic fields. When a magnetic field is present, event 134 is set;
when the magnetic field disappears, event 188 is set. These events can
e.g. be entered into the event log with date and time. The meter’s type
description informs you whether this feature has been implemented (see
section 2.3 "Type designation").
With the DC magnet detection, it is possible to order the integrated terminal
cover detection option.
2.9.2 Terminal cover detection
Installed SMA300 meters can be equipped with a terminal cover detection
unit. For this, they need to be parameterised and the unit – consisting of a
switch which detects the removal of the terminal cover – has to be installed.
Whenever the retrofit terminal cover is removed, it detects the switch status
change via control input 1 and enters event 211 in the event log with date
and time. When the terminal cover is mounted again, event 212 is entered
in the event log with date and time.
Order terminal cover detection units – part number 74 766 0163 0
(minimum order quantity 10) – from:
Landis+Gyr AG
Service & Repair
Theilerstrasse 1
CH-6301 Zug
Switzerland
For installation of the unit, see section 4.6 "Installation of terminal cover
detection".
In case of the integrated terminal cover switch used, the event 133 is set
when the terminal cover is removed and event 187 when the terminal cover
is mounted.
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3 Mechanical construction
This section describes the mechanical construction of the SMA300xT meter
and shows the most common connection diagrams.
3.1 Housing
The internal construction of the meters is not described here, since they are
protected following calibration and official certification on delivery by a
manufacturer and certification seal. It is not permitted to open the meters
after delivery. The front door is only secured with a utility seal and can be
opened to operate the reset button, to change the battery, to exchange the
tariff faceplate with connection diagram, or to fit or remove a
communication unit (see figure 22 and separate user manuals for the
communication units available).
The following drawing shows the meter components visible from outside.
Figure 21. Meter SMA300xT
1 Combined suspension hanger 10 Display button "down"
(open or concealed)
2 Screw with manufacturer seal 11 Front door with tariff faceplate
3 Optical test output reactive energy 12 Upper part of case
consumption (red), SMA300CT
only
4 Optical test output active energy 13 Lower part of case
consumption (red)
5 Liquid crystal display (LCD) 14 Utility seal for front door
6 Optical interface 15 Terminal cover
7 Screw with certification seal 16 Terminal cover screws with plate
utility seals
8 Front section with main faceplate 17 Alert LED (optional)
9 Display button "up"
Case The meter case is made of antistatic plastic (polycarbonate). The upper
part of the case is provided with two transparent plastic viewing windows,
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affording a view of the main faceplate (top) and the tariff faceplate (bottom).
The lower part of the case is additionally glass-fibre reinforced.
Viewing window The upper viewing window with the main faceplate is secured on the upper
right side with a certification seal, while the upper part of the case is
secured on the upper left side with a manufacturer seal (warranty) or a
second certification seal.
The lower viewing window is in the form of a hinged front door, secured
with a utility seal. The tariff faceplate with the connection diagram on the
rear side, the battery compartment, the reset button and (if present) the
communication unit are situated behind this front door.
Terminal cover The terminal cover is available in various lengths in order to ensure the
required free space for the connections.
Front door The front door must be opened to give access to the battery compartment,
reset button and tariff faceplate. To fit or remove the communication unit,
the terminal cover must also be removed.
Figure 22. Meter with front door open
1 Battery compartment
2 Reset button R
3 Communication unit or dummy
Figure 23. Meter with communication unit withdrawn
If the meter has no communication unit, this is replaced by a dummy case.
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Seal component An additional component, which is easy to install, allows the use of a
standard padlock instead of a utility seal.
Figure 24. Front door sealing using a padlock
The seal component is stowed away in a holder under the front door when
not in use.
Figure 25. Stowage of seal component when not in use
The seal component is installed as follows:
Slide the seal component into the vertical slot at an angle, as shown,
(position 1) until it contacts the rear wall.
Now turn the seal component until it is horizontal and slide it down into
position 2 as illustrated. The two bulges firmly fix the seal component
into the lateral grooves.
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Figure 26. Seal component for use with padlock
3.2 Faceplates
The faceplate is divided into two parts and is designed to customer
specifications. It contains all relevant data about the meter.
Main faceplate The main faceplate is situated behind the plastic viewing window, which is
secured by a certification seal. Recesses permit operation of the display
buttons "down" and "up" for control of the liquid crystal display.
1 2 3
Landis+Gyr S650
Readout
imp imp
13 Cl. 1 kvarh
1000 kWh Cl. 1 4
Three-phase four-wire meter
12 SMA310CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 10(80) A 50 Hz 5
20XX
6
11 7
10 8
9 T1 T2 T3 SET Test
Figure 27. Main faceplate (example SMA310CT)
1 Optical test output reactive energy
(with accuracy class – SMA300CT only)
2 Meter constant R1 (referred to primary values) or R2
3 Optical test output active energy (with accuracy class)
4 Optical interface
5 Approval symbol
6 Type of connection
7 Display button "up"/Display button "down"
8 Symbol for double protective insulation
9 Status indication
10 Arrows for present status indication
11 Liquid crystal display (LCD)
12 Meter data (type designation, serial number, rated values, year of
construction)
13 Alert LED (optional)
The operating elements and displays are described more detailed in
section 5 "Operation".
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Tariff faceplate The tariff faceplate is placed in the front door, which can be swung out
sideways to the left and is secured by a utility seal. The connection diagram
of the meter is shown on the back of the faceplate and is therefore visible
with the front door open.
8.8... Display check 0.1.0 Reset counter C.6.0 Battery hours counter
1 F.F Functional error 0.9.1 Time-of-day 2:1.8.0 S01
73 994 032
0.0 Identification 0.9.2 Date 3:1.8.0 S02
+A -A +Ri +Rc -Ri -Rc
1.2.0 2.2.0 5.2.0 6.2.0 7.2.0 8.2.0 Pmax cumulated
2 1.4.0 2.4.0 5.4.0 6.4.0 7.4.0 8.4.0 Last tm/P running
1.5.0 2.5.0 5.5.0 6.5.0 7.5.0 8.5.0 Plast integr. period
1.6.0 2.6.0 5.6.0 6.6.0 7.6.0 8.6.0 Pmax
1.8.T 2.8.T 5.8.T 6.8.T 7.8.T 8.8.T Energy
1.8.0 2.8.0 5.8.0 6.8.0 7.8.0 8.8.0 Total energy
T = Energy tariff
S01: 1 imp = 10 Wh K1: 1 imp = 10 Wh (+A)
3 S02: 1 imp = 10 Wh K2: 1 imp = 10 Wh (-A)
K3: 1 imp = 10 varh (+Ri)
K4: 1 imp = 10 varh (+Rc)
4
5 Ownership designation K5: 1 imp = 10 varh (-Ri)
K6: 1 imp = 10 varh (-Rc)
6
Figure 28. Tariff faceplate (example SMA310CT)
1 General data appearing in the display
2 Measured quantities
3 Pulse input data
4 Output contact data
5 Ownership designation
6 Communication unit data (if present)
3.3 Connections
Figure 29. Meter with terminal cover removed (example SMA300CT)
The terminal block with all meter connections is situated behind the
terminal cover. Two utility seals in the fixing screws of the terminal cover
prevent unauthorised access to the phase connections and therefore also
prevent unrecorded energy consumption.
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Terminal layout The top row of terminals (level 1) consists of spring-loaded terminals and
(example SMA300xT) comprises
Extension board terminals on the left
Depending on the version, up to 4 control inputs or 6 output contacts, 3
digital inputs and 2 relays outputs or a combination of these with
maximum 6 inputs and outputs, or voltage connections for a separate
supply.
Communication unit terminals on the right
The centre row of terminals (level 0) likewise consists of spring-loaded
terminals and comprises
Voltage outputs U1, U2, U3 and N, tapped from the relevant phase
input
3 fixed control inputs with a common return line G (electrically isolated)
2 output contacts for transferring fixed valence pulses or control
signals (electrically isolated)
The lower row of terminals comprises the phase connections with input and
output of the circuit for each phase with the voltage connection in between
and neutral conductor at far right.
Inputs and/or Pulse Communication
output contacts of inputs interfaces
extension board Communication unit
Control inputs and
U1 U2 U3 N output contacts
Voltage outputs
L1 L2 L3 N
Phase connections
Figure 30. Terminal layout SMA300xT
3.4 Connection diagrams (examples)
Binding connection diagrams
The following connection diagrams should be considered examples. The
connection diagrams provided at the rear of the front door and visible when
the door is open are always binding for the installation.
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SMA300xT
for three-phase
four-wire networks
Figure 31. Connection diagram of measuring unit SMA300xT
In case the SMA300 is used in a 3-wire network without neutral:
For a 3-phase, 3-wire connection, the measurement of phase-to-neutral
voltage as well as the measurement of single-phase energy have no
meaning, as no neutral voltage is supplied to the meter.
Control inputs / Basic version:
output contacts 3 control inputs
2 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 32. Connection diagram fixed control inputs/output contacts
Extension board Extension board 4200:
4200 4 control inputs
2 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 33. Connection diagram extension board with 4 control inputs and 2 output
contacts
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Extension board Extension board 2400:
2400 2 control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 34. Connection diagram extension board with 2 control inputs and 4 output
contacts
Extension board Extension board 0600:
0600 no control inputs
6 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 35. Connection diagram extension board with 6 output contacts
Extension board Extension board 0450:
0450 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 36. Connection diagram extension board with auxiliary power supply and 4
output contacts
Extension board Extension board 0460:
0460 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 37. Connection diagram extension board with auxiliary power supply and 4
output contacts
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Extension board Extension board 0470:
0470 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 38. Connection diagram extension board with auxiliary power supply and 4
output contacts
Extension board Extension board 3260:
3260 with auxiliary power supply
3 control inputs
2 relay outputs (8 A)
G + - Signal allocation and numbering of
terminals for free parameterisation
50 51 52 53 15 16 17 18 61 64
Figure 39. Connection diagram extension board with auxiliary power supply,
3 control inputs and 2 relay outputs
Extension board No terminal accessible Extension board 0080:
0080 Supercapacitor energy backup to
send an SMS in case of power
failure
Ground terminal connection
Note that the Ground terminal (G) of the control inputs on the extension
boards is NOT internally connected to the Ground terminal on the base. If
the Ground level is the same, then an external wire must be connected
between the two Ground terminals.
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3.5 Dimensions
6.2 75
extended hook: 230
extended hook: 305.5
standard hook: 206
standard hook: 281.5
190
26
40
150
177 75
Figure 40. Meter dimensions (Standard terminal cover)
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4 Installation and uninstallation
This section describes the installation and connection of meters for direct
connection. In addition, the necessary steps for checking the connections,
commissioning of the meter and the final functional check are described as
well as the uninstallation.
Dangerous voltage
Dangers can arise from live electrical installations to which the meters are
connected. Touching live parts is dangerous to life. All safety information
should therefore be strictly observed without fail.
4.1 Basic information for connecting the meter
It is recommended to use the following circuits whenever possible for
connecting the meter to the various voltage levels.
4.1.1 Connection with 3 phases and neutral
L1 L2 L3 N
Connecting
fuses
Consumer
fuses
Loads
Figure 41. Connection with 3 phases and neutral
Neutral The neutral is normally looped through terminals 10 and 12. Some power
supply companies, however, make a simple connection between terminal
10 or 12 and the neutral. This avoids possible contact errors in the neutral
conductor.
4.1.2 Connection with 3 phases without neutral (Aron circuit)
A version SFA300xT for the rarely encountered three-phase networks
without neutral with 3 x 230 V is not available.
4.2 Mounting the meter
Dangerous voltage on conductors
The connecting conductors at the point of installation must be voltage-free
for installation of the meter. Contact with live components is dangerous to
life. The relevant supply fuses should therefore be removed and kept in a
safe place until finishing work, so that they cannot be re-inserted by other
persons unnoticed.
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When you have identified the correct meter position for mounting the meter,
it should be mounted as follows on the meter board or similar device
provided for this purpose:
1. Determine the desired form of fixing (open/covered meter mounting or
extended suspension hook for 230 mm suspension triangle height). If
holes for a suspension triangle height of 230 mm are already present,
use the optional extended suspension hook depicted below. This
hook can be ordered with the part number 74 109 0072 0 (minimum
order quantity 50) from:
Landis+Gyr AG
Service & Repair
Theilerstrasse 1
CH-6301 Zug
Switzerland
Figure 42. Extended suspension hook for installations with 230 mm
suspension triangle height
2. Either set the meter suspension hook in the relevant position as shown
below or replace the suspension hook with the extended hook by lifting
the latch slightly and pulling out the shorter hook. Insert the extended
hook into the grooves in the same way the shorter hook was inserted
(bent towards rear) and push it down until it clicks into place.
Figure 43. Positioning of meter suspension eyelet
3. Check with a phase tester or universal measuring instrument whether
the connecting wires are live. If so, remove the corresponding supply
fuses and keep them in a safe place until installation is completed, so
that they cannot be replaced by anyone unnoticed. Open the voltage
connections at the test terminal block with an insulated screwdriver
and check whether the short-circuit jumpers of the circuit are closed.
4. In case there are no holes provided, e.g. as in the case with the 230
mm suspension triangle: Mark the three fixing points (suspension
triangle as in following illustration) on the mounting surface provided:
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– Horizontal base of suspension triangle = 150 mm
– Height of suspension triangle for open mounting = 206 mm
– Height of suspension triangle for covered mounting = 190 mm
206 or 190 mm respectively
75 mm
150 mm
Figure 44. Drilling plan
5. Drill the three holes for the fixing screws.
6. Unscrew the meter terminal cover.
7. Fit the meter with the three fixing screws on the mounting surface
provided.
4.3 Connecting the meter
Dangerous voltage on conductors
The connecting conductors at the point of installation must be voltage-free
for installation of the meter. Contact with live components is dangerous to
life. The relevant supply fuses should therefore be removed and kept in a
safe place until finishing work, so that they cannot be re-inserted by other
persons unnoticed.
Connecting conductor cross-section
SMA310CT meters with a maximum current of 100 or 120 A require
connecting conductors of 35 mm² cross-section. Owing to the terminal
opening of 9.5 mm, only cable is possible.
The electrical connections to the meter should be made as follows
according to the connection diagram:
1. Check with a phase tester or universal measuring instrument whether
the connecting wires are live. If so, remove the corresponding supply
fuses and keep them in a safe place until installation is completed, so
that they cannot be replaced by anyone unnoticed.
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4.3.1 Connecting the phase connection lines
1. Shorten the phase connecting wires to the required length and then
strip them.
2. Insert the phase connecting wires in the relevant terminals (the
terminals are numbered as shown in the connection diagram) and
tighten the terminal screws firmly (torque 3 to 5 Nm).
With small conductor cross-sections (e.g. 4 mm²) the connecting line
must be placed in the indentation (stamping) of the current loops, so
that it cannot shift sideways when tightening the terminal screws.
Ensure that the connecting line remains in the indentation when
tightening.
Indentation (stamping) for smaller connection lines
Current loop conductor
Figure 45. Cross-section through current loop conductor
If smaller connection lines are used, it is possible to adapt the cable
section with terminal holes using "assembly aids" or "centering parts"
in order to have a safe connection:
P000225650 (x100 pcs) – 8.5 mm
P000172980 (x100 pcs) – 9.5 mm
Contact your sales representative for ordering.
It is recommended to identify the beginning and end of the relevant
conductors with a suitable test unit (e.g. buzzer) to ensure that the
right consumer is connected to the meter output.
Inputs and/or Pulse Communication
output contacts of inputs interfaces
extension board Communication unit
Control inputs and
U1 U2 U3 N output contacts
Voltage outputs
L1 L2 L3 N
Phase connections
Figure 46. Meter connections (example SMA300xT)
Power losses at the terminals
Insufficiently tightened screws at the phase connections can lead to
increased power losses at the terminals and therefore to undesirable
heating. A contact resistance of 1 mΩ causes a power loss of 10 W at 100
A!
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4.3.2 Connecting the signal inputs and outputs
Maximum current at auxiliary terminals
The circuits connected to the auxiliary terminals must be built in such a way
that the maximum current is never exceeded, as this might damage the
meter.
Maximum current of the voltage outputs: 1 A.
Maximum current of the output contacts: 100 mA.
Use fuses or protective relays between external and internal circuits to
avoid defects and a possible exchange of the meter.
1. Shorten the connecting wires of the signal inputs and outputs to the
required length and strip them for approx. 4 mm (wires and strands up
to 2.5 mm² can be connected).
Use ferrules with stranded wires
If stranded wire is used, provide it with ferrules for connection.
2. Connect the connecting wires of the signal inputs and outputs as
follows to the screwless spring-loaded terminals (the terminals are
numbered as shown on the connection diagram):
– Insert a size 1 screwdriver in the upper opening and insert it turning
slightly upwards (figure 47 A).
– Now place the stripped connecting wire in the lower opening and
hold it there securely (figure 47 B).
– Withdraw the screwdriver. The connecting wire is then firmly fixed
(figure 47 C).
Figure 47. Connection in screwless spring-loaded terminals
Bare end of connecting wire must not be too long
The insulation of the connecting line must extend as far as the terminal
indentation, i.e. there must be no further bare part of the connecting line
visible above the terminal edge (as shown in figure 47 C). Touching live
parts is dangerous to life. The stripped part of the connecting wire should
be shortened if necessary.
Only one wire or ferrule per terminal
Only one wire or ferrule with strand(s) may be connected in screwless
spring-loaded terminals. The terminal could otherwise be damaged or the
contact not properly made.
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If a connecting wire must be disconnected again for any reason, this is
performed in the reverse sequence:
Figure 48. Releasing connection from spring-loaded terminal
Damage to terminals
Never withdraw connecting wires with the terminal closed, since this could
damage the terminal.
4.3.3 Connecting the RS485 interface
If you connect the RS485 interface you must not strip back the shielded
cables, e.g. to connect the individual wires to an external terminal block
(see figure below), as this considerably increases the likelihood of
interference.
Figure 49. How to connect RS485 correctly
It is also possible to use RS485 distributors instead of connecting the
RS485 cables directly to the meter.
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4.4 Check of connections
Effects of connection errors
Only a properly connected meter measures correctly!
Every connection error results in a financial loss for the power company!
Before putting into operation, check again whether all meter connections
are connected correctly according to the connection diagram.
4.5 Commissioning, functional check and sealing
Dangerous voltage on conductors
The supply fuses must be re-inserted before commissioning and functional
check of the meter. If the terminal cover is not screwed tight, there is a
danger of contact with the connection terminals. Contact with live
components is dangerous to life. The relevant supply fuses should
therefore be removed before making any modifications to the installation
and these kept in a safe place until completing the work to prevent anyone
re-inserting them unnoticed.
Prerequisites for commissioning and functional check
If no mains voltage is present, commissioning and functional check must be
performed at a later date.
The installed meter should be put into service and checked as follows:
1. Insert the supply fuses removed for installation. The meter is switched
on.
2. Check whether the operating display is correct (no error message).
3. Check on the display whether all three phases L1, L2 and L3 are
indicated and show the right phase sequence.
– If one phase is not present or less than 20 V, then the relevant
symbol is absent.
– With the normal phase sequence L1-L2-L3 the symbols are dis-
played continuously.
– If, however, the meter is connected with reversed phase sequence
(e.g. L2-L1-L3) the symbols flash. The direction of field rotation
(clockwise or anticlockwise) is determined by the parameterisation.
This has no influence on the measuring behaviour of the meter.
Figure 50. Phase sequence indication
4. Remove all supply fuses.
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5. Insert the supply fuse of phase 1 and check the display of the energy
direction: +P to right. If the energy direction arrow P points to the left,
the input and output of phase 1 are interchanged. If the meter displays
no energy direction, the calibration link is open, the supply fuse is
defective or the neutral is not connected.
6. Remove the supply fuse of phase 1 again.
7. Repeat the same test for the other phases as in points 5 and 6.
8. You can now check further values such as phase voltages. This is
preferably done with .MAP110 or, if parameterised, via the service list,
which you can reach via the service menu.
9. Check the tariff displays and switch the control voltages to the tariff
inputs on and off. The arrow symbols of the tariff display must change.
10. If the meter is connected to a meter readout system via the electrical
interface, check the data transmission.
11. If a GSM modem is connected to the meter, the SMS transmission
function should be checked by sending a test SMS message according
to the instructions found in the respective application note or user
manual, e.g. to your own mobile telephone.
12. Mount the terminal cover if the meter is operating correctly. Otherwise
first locate and eliminate the error.
13. Seal the terminal cover with two utility seals.
14. Set the current date and time with the relevant formatted command
(see section 5.8 "Input of formatted commands") or in the set mode
(see section 5.9 "Set time and date, ID numbers, battery time").
15. Close the front door.
16. Re-seal the front door.
4.6 Installation of terminal cover detection
1. Ensure that control input 1 has been parameterised for this function.
2. Connect cables 1 and 2 to terminal according to the figure below.
1
3 2
Figure 51. Connection of cables of cover detection unit
3. Fix terminal cover detection unit to meter. See figure below.
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Figure 52. Fixing of cover detection unit to meter
4. Connect cable 3 as shown above.
4.7 Uninstallation
Dangerous voltage on conductors
The connecting wires at the place of installation must not be live when
removing the meter. Touching of live parts is dangerous to life. Remove the
corresponding supply fuses and keep these in a safe place until work is
completed, so that they cannot be replaced by anyone unnoticed.
The meter should be removed as follows:
1. Remove the two utility seals at the screws of the terminal cover.
2. Release the two screws of the terminal cover and remove it.
3. Check that the connecting wires are not live using a phase tester or
universal measuring instrument. If they are live, remove the
corresponding supply fuses and keep these in a safe place until work
is completed, so that they cannot be replaced by anyone unnoticed.
4. Remove the connecting wires of the signal inputs and outputs from the
screwless spring-loaded terminals as follows:
– Place a size 1 screwdriver in the upper opening and insert it turning
slightly upwards (figure 53 A).
– Then draw the wire from the lower opening (figure 53 B).
– Withdraw the screwdriver (figure 53 C).
Figure 53. Removing connections in screwless spring-loaded terminals
Damage to terminals
Never withdraw connecting wires from closed terminals. The terminals
could be damaged.
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5. Release the terminal screws 1, 3, 4, 6, 7, 9, 10 and 12 of the phase
connecting wires with a suitable screwdriver and withdraw the phase
connecting wires from the terminals.
6. Fit a substitute meter as described in section 4.3 "Connecting the
meter" and the following sections.
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5 Operation
This section describes the location and function of all operating elements
and displays of the S650 SMA300xT meters as well as operating sequences.
Illustrations
The illustrations of the faceplate and display in this section always show the
SMA300CT combi-meter (with additional optical test output for reactive
energy, together with direction of reactive power and quadrant display).
5.1 Operation with auxiliary power supply
Meters equipped with an auxiliary power supply which is supplied with
electricity (see section 3.4 "Connection diagrams (examples)") are
completely functional even in case of a power cut. Despite missing voltage
at the terminals they can be read out via display, remote readout, etc. and
parameterised, if desired.
Connect the auxiliary power supply as follows:
1 2 3 4
Figure 54. Auxiliary power supply connections
Type 045x: 1 and 2: 100–240 V AC/DC
Type 046x: 1: + (12–24 V DC)
Type 046x: 2: – (12–24 V DC)
Type 047x: 1: + (12–60 V DC)
Type 047x: 2: – (12–60 V DC)
Type 326x: 3: + (12–24 V DC)
Type 326x: 4: – (12–24 V DC)
5.2 Control elements
S650 meters have the two display buttons "down" and "up" and a reset
button as conventional operating elements. The display can also be
controlled with the aid of a light source via the optical interface.
5.2.1 Display buttons
The two display buttons "down" and "up" are placed on the main faceplate
(top) on the right of the liquid crystal display.
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Landis+Gyr S650
Readout
imp imp Cl. 1
Cl. 1 kvarh
1000 kWh
Three-phase four-wire meter
SMA310CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 10(80) A 50 Hz
20XX
Display key
"up"
Display key
"down"
T1 T2 T3 SET Test
Figure 55. Display buttons
By pressing the lower display button "down", the display changes to the
next value in the list. By pressing the upper display button "up", the display
changes to the previous value (also see section 5.4.2 "Display menu").
5.2.2 Control of display via optical interface
All S650 meters have an "optical button" in addition to the "up" and "down"
display buttons. The optical interface serves to receive a light signal, e.g.
generated by a torch (works only with warm light, i.e. LED torches cannot
be used for this). The light signal acts like the "down" display button and
controls the display in one direction from one value to the next. This type of
display control only functions when voltage is supplied to the meter.
The reader can also control the display at a distance from the meter
depending on the light intensity from the source, e.g. through a protective
glass in front of the meter.
5.2.3 Reset button
The reset button is situated to the right of the battery compartment behind
the front door. To permit operation of the reset button the front door must
be opened and therefore the utility seal be removed.
The reset button can be used to perform a manual reset. If the display
check is displayed (after operation of a display button), however, pressing
the reset button produces the service menu (also see section 5.4.3 "Service
menu").
Figure 56. Reset button behind front door
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5.3 Display
5.3.1 Introduction
S650 meters are provided with a liquid crystal display (LCD).
The display can be provided with background lighting for easier reading
(optional). This is switched on by pressing one of the display buttons and is
extinguished automatically after a short time if no further button is pressed.
5.3.2 Basic layout
The basic layout shows all the indication possibilities of the display.
Figure 57. Basic layout of the liquid crystal display (LCD)
1 Active power direction (+P: import, -P: export)
2 Reactive power direction (not used with SMA300AT)
3 Phase voltages (flash if rotating field reversed)
4 Battery status (charge voltage)
5 Units field
6 Index field (8 digits)
7 Value field (8 digits)
8 12 arrow symbols for status information (e.g. tariffs)
Active power direction Shows always the sum of the three phases:
Positive active energy direction (imported from power
company)
Negative active energy direction (exported to power
company)
Negative active energy direction of individual phases
(second arrow flashes).
Reactive power Indicates for combi-meters SMA300CT always the sum of the three phases (not
direction used for active energy meters SMA300AT).
Positive reactive energy direction
Negative reactive energy direction
Quadrant display Indicates for combi-meters SMA300CT in which quadrants the present
measurement is made (not used for active energy meters SMA300AT):
1st quadrant
2nd quadrant
3rd quadrant
4th quadrant
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Phase voltages Indication of presence of phase voltages.
If the rotating field corresponds to the parameterised,
symbols L1, L2 and L3 are continuously lit. Otherwise
they flash every second.
Battery condition The symbol appears if the charge voltage of the battery
fitted is too low (provided the meter is parameterised as
"fitted with battery").
Units field The following units are shown:
W, var, VA, k..., M..., ...h, V, A, h, Hz, m³
(var and VA only for combimeters)
Index field Up to 8-digit indices are displayed, which define
the value in the value field.
Value field Up to 8-digit values are displayed.
Arrow symbols An arrow symbol is an additional status indication for tariff
rates, reset block, test mode, etc. The arrow points to a
status description on the faceplate.
5.3.3 Index system
The information concerning which data are shown in the display is made
with an index system and is supported by the unit over the value field.
The 8-digit index field permits all currently known index systems, such as
DIN, LG, VEOe, OBIS, etc.
The B:C.D.E.F structure applies to OBIS (Object Identification System):
B Defines the channel number, i.e. the number of the input of a metering
device having several inputs for the measurement of energy of the
same or different types (e.g. in data concentrators, registration units).
This enables data from different sources to be identified.
C Defines the abstract or physical data items related to the information
source concerned, e.g. active power, reactive power, apparent power,
cosφ, current or voltage.
D Defines types, or the result of the processing of physical quantities
according to various specific algorithms. The algorithms can deliver
energy and demand quantities as well as other physical quantities.
E Defines the further processing of measurement results to tariff
registers, according to the tariff rates in use. For abstract data or for
measurement results for which tariffs are not relevant, this value group
can be used for further classification.
F Defines the storage of data according to different billing periods. Where
this is not relevant, this value group can be used for further classification.
To simplify reading of the index field, individual parts of the OBIS code can
be omitted. The abstract or physical data C and type of data D must be
shown.
For further details about OBIS code, see Appendix 1 "OBIS code".
Examples 1.8.0: 1 = Active energy import (all phases); 8 = Status; 0 = Total
0.9.1: Local time
Reference is made for examples to the following display list and the
readout log (see section 5.7 "Data readout")
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5.4 Types of display
The SMA300xT has the following three types of display:
Operating display The values specified by the parameterisation are shown as a rolling display
in the operating display. The display is always in operating mode when the
display buttons are not operated. The meter returns automatically from the
display list to the operating display after a defined time. This display can
consist of one or more values.
Display menu By pressing the display button, the display check is activated, and from
there the user reaches the display menu by pressing the display button
again. From the display menu, values of the display list, the load profile(s),
the event log, etc. can be accessed. The values of the display list and also
the sequence can be parameterised. The display buttons permit scrolling
up and down in the list.
Service menu The user reaches the service menu by pressing the reset button starting
from the display check. From the service menu, values of the service list,
the set mode, etc. can be accessed. The service list, for example, is an
extended display list with additional values.
5.4.1 Operating display
The values always displayed are considered the operating display. This can
be parameterised as a fixed display (only one value present, e.g. the
present tariff rate) or as a rolling display (several values alternate at a fixed
rate, e.g. every 15 seconds).
running average demand
value with status of
integrating period
Figure 58. Example of a fixed display
Error message The meter can generate an error message on the basis of self-tests.
According to parameterisation, this can be permanently included in the
operating display. In the event of a serious error (fatal or critical error), it
replaces the normal operating display. After a fatal error, the meter no
longer operates and must be replaced. In case of a critical error, the error
message can be acknowledged with the display button.
Figure 59. Example of an error message (insufficient battery voltage)
In case of an error message, the procedure described in section 6.2 "Error
messages" should be followed.
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5.4.2 Display menu
Figure 60. Display menu overview
Display check Brief operation (< 2s) of the display button "down" or "up" causes a change
of the operating display, e.g.:
to the display check:
All segments of the display are active here. The index and value fields
should be checked each time for missing segments. This can prevent
incorrect readings.
Display menu Pressing the display button "down" or "up" again briefly changes to the
display menu or directly to the display list. The first menu item appears, e.g.
"Display list" (standard data):
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The menu item only appears when several menu items exist. Otherwise
direct entry is made to the display list.
The next menu item appears for every further brief operation of the "down"
display button, e.g. "Data profile", "Event log", etc. The first menu item
appears again after the last item.
The preceding menu item is displayed again by briefly pressing the "up"
display button.
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from any display menu.
Value display The first value of the list associated with the present menu is displayed by
pressing the display button "down" or "up" for longer (at least 2 seconds),
and is normally the error message:
The next list value appears for every further brief operation of the "down"
display button. Brief operation of the "up" button again displays the
preceding value. The sequence of values in the list is determined by the
parameterisation.
A rapid run is started by holding down the display button "down" or "up" for
longer (at least 2 seconds). The main values of the list are then displayed
while the button remains pressed, but no stored values.
Examples of values in a display list:
Reset counter
Date of resetting
stored value 03 (March)
Cumulated maximum
demand
active power
rate 1
Active energy
present status
rate 1
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Reactive energy
present status
rate 1
Battery hours counter
Status of signals at
control terminals
Number of total voltage
failures
To return to the menu level from the list at the end of the display list press
the display button "down" or "up" for longer (at least 2 seconds).
Load profile 1 The load profile 1 menu item for selection in the display menu (denoted
P.01) is shown as follows:
The first value of the load profile 1 is displayed by pressing the display
button "down" or "up" for longer (at least 2 seconds).
Load profile 2 The load profile 2 menu item for selection in the display menu (denoted
P.02) is shown as follows:
The first value of the load profile 2 is displayed by pressing the display
button "down" or "up" for longer (at least 2 seconds).
Event log The event log menu item for selection in the display menu (denoted P.98)
is shown as follows:
The first entry in the event log is displayed by pressing the display button
"down" or "up" for longer (at least 2 seconds).
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5.4.3 Service menu
Figure 61. Service menu overview
Service menu Pressing the reset button during the display check changes the display to
the service menu or directly to the service list. The first menu item appears,
e.g. the service list:
The menu item only appears if there are several items present. Otherwise
pressing the reset button directly leads to the values of the service list.
The next menu item appears for every further brief operation of the "down"
display button, e.g. "Set mode", "Test mode on/off", etc. The first item
appears again following the last menu item "End".
The preceding menu item appears again by pressing the "up" button
briefly.
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from the service menu.
Value display The first value of the list associated with the present menu is displayed by
pressing the display button "down" or "up" for longer (at least 2 seconds).
The next list value appears for every further brief operation of the "down"
display button. Brief operation of the "up" button again displays the
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preceding value. The sequence of values in the list is determined by the
parameterisation.
A rapid run is started by holding down the display button "down" or "up" for
longer (at least 2 seconds). The main values of the list are then displayed
while the button remains pressed, but no stored values.
To return to the menu level from the list at the end of the display list press
the display button "down" or "up" for longer (at least 2 seconds).
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from the list.
Set mode Values can be changed in the set mode with the aid of the reset button and
display buttons (for setting time and date, identification numbers, battery
hours counter, etc.). The procedure is described in section 5.9 "Input of
formatted commands".
5.5 Alert LED
The red alert LED (optional) on the main faceplate indicates that certain
event(s) have occurred. Which event(s) trigger the alert LED can be set by
parameterisation.
Landis+Gyr S650
Readout
imp imp
Alert LED Cl. 1 kvarh
1000 kWh Cl. 1
Three-phase four-wire meter
SMA310CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 10(80) A 50 Hz
20XX
T1 T2 T3 SET Test
Figure 62. Alert LED
5.6 Optical test output
The optical test outputs – one for active energy in all meters and a second
for reactive energy in combimeters – are fitted in the main faceplate above
the liquid crystal display.
Optical
test output
Landis+Gyr S650
Readout reactive energy
Cl. 1
imp
kvarh
1000 kWh
imp
Cl. 1 (combimeters
Three-phase four-wire meter only)
SMA310CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 10(80) A 50 Hz
20XX
Optical
test output
active energy
T1 T2 T3 SET Test
Figure 63. Optical test outputs
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The optical test outputs are used for testing the meter (also see section 7.1
"Meter testing"). They transmit visible red pulses corresponding to the
current measured values (active and reactive energy).
5.7 Data readout
The energy supply company can record the data stored locally in the meter
at any time in two ways:
Reading the liquid crystal display of the meter. The displayed data is
defined by parameterisation.
Automatic data readout via the optical interface with a readout device
(e.g. laptop).
Readout data
For readout to IEC 62056-21, all data determined by the parameterisation
are read out in the specified sequence.
For readout according to DLMS (Device Language Message Specification),
the data requested by the readout unit are read out.
If the meter is fitted with the appropriate communication unit (see
associated separate operating instruction), remote readout of the meter
data is also possible.
Procedure for data readout via optical interface
1. Start the readout device (according to the details in the associated
operating instructions).
2. Connect the cable of the reading head to the readout device.
3. Place the reading head in the "Readout" indentation on the plastic
viewing window of the meter. The reading head cable must point to-
wards the terminal cover (when mounted vertically downwards). The
reading head is held magnetically.
4. Start the data readout on the readout device (according to the details
in the associated operating instructions).
5. Remove the reading head from the meter again after completing the
readout.
5.7.1 Readout to IEC 62056-21
The data read out according to IEC 62056-21 are recorded in the form of
the example shown below. The quantity and sequence of values in the log
is determined by parameterisation.
Log example Significance
/LGZ4\2SMA3104100 Designation of meter
(reply on transmit request)
F.F (00000000) Error message
0.0.1 (417242) 1st identification number
0.1.0 (28) Number of resets
0.1.2.04 (98-05-01 00:00) Time of last reset
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1.2.1 (26068.7*kW) Pmax cumulated Rate 1
1.2.2 (15534.8*kW) Pmax cumulated Rate 2
1.6.1 (192.4*kW)(00-05-06 10:45) Pmax present Rate 1
1.6.1*04 (202.4)(00-04-22 09:30) with April stored value 1) Rate 1
1.6.2 (086.7*kW)(00-05-04 22:30) Pmax present Rate 2
1)
1.6.2*04 (100.9)(00-04-14 23:00) with April stored value Rate 2
1.8.1 (0244948*kWh) Active energy (import) Rate 1
1)
1.8.1*04 (0234520) with April stored value Rate 1
1.8.2 (0082520*kWh) Active energy (import) Rate 2
1)
1.8.2*04 (0078197) with April stored value Rate 2
5.8.1 (0106103*kvarh) Reactive energy (inductive) Rate 1
5.8.1*04 (0100734) with April stored value 1) Rate 1
5.8.2 (0039591*kvarh) Reactive energy (inductive) Rate 2
1)
5.8.2*04 (0036152) with April stored value Rate 2
1.8.0 (0327468*kWh) Total active energy
5.8.0 (0145694*kvarh) Total reactive energy (inductive)
8.8.0 (0001452*kvarh) Total reactive energy (capacitive)
0.9.1 (14:18:06) Time-of-day of readout
0.9.2 (00-05-20) Date of readout
C.7.0 (00087) No. of voltage failures of all phases
C.72.0 (00157) Number of under-voltages
C.73.0 (00000) Number of over-voltages
C.74.0 (00306) Number of over-loads (over-current)
C.3.0 (500) Active pulse constant
C.3.1 (500) Reactive pulse constant
C.2.1 (00-03-26) Date of last parameterisation
! End of log
1)
If the sequence is parameterised as month.
Notes The energy supply company can select by parameterisation between a
standard identification or its own identification. The standard identification
has the following structure:
/LGZ... Manufacturer (Landis+Gyr)
/LGZ 4... Transmission rate 4 = 4800 bps
/LGZ4 \2... Extended communication possibility
2 = DLMS-compatible meter
/LGZ4\2 SMA310... Meter Type of measuring unit
/LGZ4\2SMA310 41... Basic version tariff section
/LGZ4\2SMA31041 00... Additional functions
(auxiliary power supply)
/LGZ4\2SMA3104100 .B32 Firmware version
Stored values The hyphen following the identification
number and the rate (1.6.1) denotes the
type of resetting:
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e.g. 1.6.1*04 *04 Resetting made internally or
remote controlled
e.g. 1.6.1&04 &04 Resetting performed manually
The identification by the energy supply company itself uses an identification
number. ID1.1 (designation of ownership by the energy supply company),
ID1.2 (any desired number) or ID2.1 (serial number) are available. The
identification is comprised as follows in this case:
/LGZ... Manufacturer (Landis+Gyr)
/LGZ 4... Transmission rate 4 = 4800 bps
/LGZ4 \2... Extended communication possibility
2 = DLMS-compatible meter
/LGZ4\2 \B32... Meter Firmware version
/LGZ4\2\B32 12345678 Identification number specified
by parameterisation (maximum
8 characters)
5.7.2 Readout to DLMS
While the readout according to IEC 62056-21 uses a predefined protocol,
readout to DLMS enables the power supply company to read out values
individually. The company therefore has systematic access to specific
values without being influenced by other values that are not required.
DLMS specification Various meter manufacturers – including Landis+Gyr – together with
related organisations, have compiled the language specification DLMS
(Device Language Message Specification).
Objective The objective of DLMS is to use a common language for data exchange in
energy measurement and other sectors. In addition to end units such as
meters, tariff units, etc. DLMS also defines the interfaces, transmission
channels and system software.
Principle DLMS delivery oriented protocol can be compared to sending a letter: the
sender writes the address of the recipient on the letter and hands it to the
post office for transport. The way in which the postal department transports
the letter is of no consequence to the sender and receiver. The only
important thing is that the address of the recipient is clearly shown and that
the letter is received, read and it can be seen from whom the letter
originates.
Units with DLMS operate in a similar way. They provide the values –
termed objects – required by the receiver (e.g. control centre) and pass
them via interface to the transport medium (channel). How the values reach
the recipient is again immaterial for both parties.
DLMS items DLMS is an object-oriented language. The DLMS objects:
Have an unique name in the form of the EDIS identification number
Contain the value in an exactly defined form and
Are configured in a similarly exactly defined format.
Examples are number of resets with date and time, cumulative maxima,
rolling mean values, maxima, energy status, associated stored values, etc.
The sender feeds these objects to a transport medium, e.g. the telephone
network. This transmits them to the receiver, so that the objects are
received in the same form as supplied by the sender.
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5.8 Input of formatted commands
The following operating data or meter characteristics can be modified by
the input of formatted commands. The user of formatted commands,
however, must have the necessary access authorisation according to the
security system.
The following commands can be used both according to IEC 62056-21 and
also with DLMS:
Set time/date
Set identification numbers for the energy supply company and for the
manufacturer (by line).
Reset
Neutralise reset inputs KA/KB
Set/reset counter
Control tariff rates via interface
Set/reset energy registers
Set/reset total energy registers
Set/reset demand maximum registers
Set/reset power factor registers
Reset stored values
Reset battery hours counter
Reset voltage failures registers
Switch on/off increased resolution (test mode) of energy registers
Define by additional parameters whether the optical test output for
active energy in test mode supplies active or reactive energy pulses
Delete error messages
Change passwords P1,P2 and W5
Reset load profile 1 / load profile 2
Reset event log
Reset dedicated event log groups
The following commands can only be executed with DLMS:
Reset event register
– Under- and overvoltages
– Demand messages
– Current messages
– Power factor messages
Set thresholds for messages
Formatted commands are transferred to the meter with a suitable device
via the optical interface or via an interface circuit of the communication unit.
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5.9 Set time and date, ID numbers, battery time
The following values can be changed at any time from the service menu
(set mode):
Date and time
Identification numbers
Operating time of battery
Below is an example on how to set the date and time.
Operating
display
1. All segments of the Display check
display are lit
2. Enter service menu Set mode
R
3. Enter set mode Identification
number
4. Select required Date, old
setting value
5. Select digit to be Digit flashes
R changed
6. Change digit value Digit flashes
7. Select digit to be Next digit
R changed flashes
8. Repeat steps 5 – 7 for all digits to be changed. All digits flash
9. Confirm new Date, new
R setting value
10. Repeat steps 4 – 9 for all settings to be changed.
11. Advance display End of set
until End mode
12. Back to service Service menu
menu
13. Advance display End of service
until End menu
14. Back to operating Operating
display display
15. Close and re-seal the front door.
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6 Service
This section describes the necessary servicing work after the appearance
of operating faults or error messages.
6.1 Operating faults
If the liquid crystal display is illegible or the data readout does not function,
the following points should first be checked:
1. Is the network voltage present (supply fuses intact and test terminals
closed)?
2. Is the maximum permissible ambient temperature exceeded?
3. Is the plastic viewing window over the faceplate clean (not scratched,
painted over, misted over or soiled in any way)?
Danger of short-circuits
Never clean soiled meters under running water or with high pressure
devices. Water penetration can cause short-circuits. If the meter is heavily
soiled, it should be uninstalled if necessary and sent to an authorised
service and repair centre, so that a new plastic viewing window can be
fitted.
If none of the points listed is the cause of the fault, the meter should be
disconnected, removed and sent to the responsible service and repair
centre (according to section 6.3 "Repairing meters").
6.2 Error messages
The meters regularly perform an internal self-test. This checks the correct
function of all important parts.
In case of a serious error detected (fatal or critical error according to
classification in the following degrees of severity), the meters displays an
error code. This error code appears as an eight-digit number together with
"F.F" or "FF" in the display (error code F.F 00000000 = no error).
Classification of The degree of severity of an error occurring is assessed as follows:
degree of severity
A fatal error indicates a severe problem, which prevents the meter
maintaining measuring operation, e.g. a defective hardware component.
The meter stops its operation and the error code is displayed permanently.
The meter must be exchanged.
A critical error indicates a severe problem, but with which the meter
continues to function and measurement is still possible. The data are stored
in the memory and suitably marked in case of doubt. After a critical error,
the error code is displayed until acknowledged with the display button or
until the error register is reset, e.g. via the electrical interface. Depending
on the type of the error this can cyclically occur again, since with the
acknowledgement the error cause is usually not repaired. The meter must
in this case be exchanged as soon as possible.
Non-critical errors can influence the meter functions (temporarily or
permanently). These errors are recorded in the error register. The meter
remains serviceable and normally needs not to be exchanged.
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Deleting error If nothing else is specified in the following description of the error groups,
messages the error messages can only be deleted with formatted commands (see
section 5.8 "Input of formatted commands"). If the error occurs again, the
meter should be removed and sent to the responsible service and repair
centre (according to section 6.3 "Repairing meters").
6.2.1 Structure of an error message
An error message has the following form:
Figure 64. Error message on S650 meters
All S650 meters use the same format for error messages. It consists of four
groups of 2 digits each, whereby the groups have the following significance:
Figure 65. Significance of error message
Each group has two digits written in hexadecimal notation and can there-
fore have the values 0 to 9 and letters A to F. Both digits each form the sum
of the individual values of 4 possible types of error as shown in the
following diagrams.
6.2.2 Error groups
Time-base errors
Group 1 of error messages
(clock) of S650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Low battery
Invalid clock
*
*
* * not used
*
*
*
Figure 66. Group 1 of error messages
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The first digit in the first group has no significance, since no error messages
are assigned to it.
The second digit can have values between 0 (no error message) and 3
(both error messages set). Significance:
F.F 01 00 00 00 Low battery (non-critical error)
The battery is missing or discharged. If there is no mains voltage at the
meter and the internal supercapacitor is discharged (after about 3 weeks)
then the calendar clock will stop.
The error is deleted automatically when the battery voltage has again
reached a sufficient value (e.g. after inserting a new battery as described in
section 7.2 "Changing the battery").
This error message only appears if the meter is parameterised as "fitted
with battery". Otherwise there is no check of the battery condition.
The same applies to messages where the bit is set:
F.F 03 .. .. ..
F.F 02 00 00 00 Invalid clock (non-critical error)
The meter has found that the calendar clock has stopped at some time,
e.g. due to insufficient power reserve (battery low). The clock is running,
but shows the wrong time and/or date.
The error is deleted automatically when the time and date have been set
correctly by the relevant formatted command or manually in the set mode
(see section 5.8 "Input of formatted commands"). or section 5.9 "Set time
and date, ID numbers, battery time"). If necessary, replace the battery.
The same applies to messages where the bit is set:
F.F 03 .. .. ..
Errors for write/read
access Group 2 of error message
of S650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Main memory access error
Backup memory access error
Measuring system access error
Time device access error
Load profile memory access error
not used
Communication unit access error
not used
Figure 67. Group 2 of error messages
In the second group both digits can have values between 0 (no error
message) and F (all four error messages set). Significance:
F.F 00 x1 00 00 Main memory access error (fatal error)
This error message appears if the main memory could not be accessed
several times during the start-up of the meter.
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The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. x3/x5/x7/x9/xB/xD/xF .. ..
F.F 00 x2 00 00 Backup memory access error (non-critical error)
This error message appears if the backup memory could not be accessed
several times.
The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. x3/x6/x7/xA/xB/xE/xF .. ..
F.F 00 x4 00 00 Measuring system access error (non-critical error)
This error message appears in case of repeated failures when accessing
the measuring system, possibly because of a completely discharged
supercapacitor, which causes an incorrect start-up behaviour.
Power-up meter and wait for a short time, then clear error via
communication. If the error does not reoccur, it is recommended to equip
the meter with a battery. If the error reoccurs, replace the meter.
The same applies to messages where the bit is set:
F.F .. x5/x6/x7/xC/xD/xE/xF .. ..
F.F 00 x8 00 00 Time device access error (non-critical error)
The meter sets this message in the event of repeated failures when
accessing the time device. The calendar clock may display an invalid time
or date.
The error can be reset via communication. If it occurs repeatedly, the
meter must be exchanged.
The same applies to messages where the bit is set:
F.F .. x9/xA/xB/xC/xD/xE/xF .. ..
F.F 00 1x 00 00 Load profile memory access error (critical error)
This error message appears in case of repeated failures when accessing
the load profile memory.
Load profile data will be marked in the status code (bit 2 "corrupted
measurement" and bit 0 "critical error" set).
It may not be possible to access the load profile memory. The memory may
contain incorrect data. The meter must be exchanged.
The same applies to messages where the bit is set: F.F .. 5x .. ..
F.F 00 4x 00 00 Communication unit access error (non-critical error)
The meter sets this message in the event of repeated failures to access the
communication unit. Communication fails or is slow.
The error can be reset via communication. If it reoccurs, replace first the
communication unit, check the function again. If the error still occurs, the
meter must be exchanged.
The same applies to messages where the bit is set: F.F .. 5x .. ..
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Checksum errors
Group 3 of error messages
of S650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Program checksum error
Backup data checksum error
Parameter checksum error
Load profile 1 checksum error
Stored values checksum error
Event log checksum error
Calibration data checksum error
Load profile 2 checksum error
Figure 68. Group 3 of error messages
The first digit in the third group can have the value 0 (no error message) or
1 (error message set).
The second digit can have values between 0 (no error message) and F
(all four error messages set). Significance:
F.F 00 00 x1 00 Program checksum error (fatal error)
The meter does not operate and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x3/x5/x7/x9/xB/xD/xF ..
F.F 00 00 x2 00 Backup data checksum error (critical error)
This error message appears when the backup data checksum test fails.
Load profile data will be marked in the status code (bit 2 "corrupted
measurement" and bit 0 "critical error" set). The meter may contain
incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x3/x6/x7/xA/xB/xE/xF ..
F.F 00 00 x4 00 Parameter checksum error (critical error)
This error message appears when the parameter checksum test fails.
Load profile data will be marked in the status code (""bit 0 "critical error"
set). The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x5/x6/x7/xC/xD/xE/xF ..
F.F 00 00 x8 00 Load profile 1 checksum error (non-critical error)
Load profile 1 data of the defective memory area will be marked in the
status code (bit 2 "corrupted measurement" set).
The error can be reset via communication. Reset the load profile first
and then the error. If it occurs repeatedly, the meter must be replaced as
soon as possible.
The same applies to messages where the bit is set:
F.F .. .. x9/xA/xB/xC/xD/xE/xF ..
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F.F 00 00 1x 00 Stored values checksum error (critical error)
Data in the defective memory area will be marked in the status code (bit 0
"critical error" set).
The error can be reset via communication. If it occurs repeatedly, the
meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 3x/5x/7x/9x/Bx/Dx/Fx ..
F.F 00 00 2x 00 Event log checksum error (non-critical error)
Data in the defective memory area will be marked in the status code (bit 0
set).
The error can be reset via communication. If it occurs repeatedly, the
meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 3x/6x/7x/Ax/Bx/Ex/Fx ..
F.F 00 00 4x 00 Calibration data checksum error (critical error)
Data in the defective memory area will be marked in the status code (bit 0
"critical error" set).
The meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 5x/6x/7x/Cx/Dx/Ex/Fx ..
F.F 00 00 8x 00 Load profile 2 checksum error (non-critical error)
Load profile 2 data of the defective memory area will be marked in the
status code.
The error can be reset via communication. Reset the load profile first
and then the error. If it occurs repeatedly, the meter must be replaced as
soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 9x/Ax/Bx/Cx/Dx/Ex/Fx ..
Other errors
Group 4 of error messages
of S650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Invalid power down
*
* * not used
*
Expired watchdog
Communication locked
Wrong EEPROM/Flash identifier
Wrong extension board
Figure 69. Group 4 of error messages
The first digit in the fourth group can have the values 0 to F.
The second digit can have values between 0 (no error message) and 1
(Invalid power down). Significance:
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F.F 00 00 00 x1 Invalid power down (non-critical error)
The meter has detected that the last data storage was not performed
correctly. The meter may contain incorrect data or may have lost data since
the last storage, i.e. for 24 hours maximum.
The error can be reset via communication. If it occurs repeatedly,
contact Landis+Gyr Customer Services.
F.F 00 00 00 1x Expired watchdog (non-critical error)
The microprocessor was restarted due to a disturbance (e.g. lightning). The
meter may lose all data recorded since the last storage, i.e. for 24 hours
maximum.
The error can be reset via communication. If it occurs repeatedly,
contact Landis+Gyr Customer Services.
The same applies to messages where the bit is set:
F.F .. .. .. 3x/5x/7x/9x/Bx/Dx/Fx
F.F 00 00 00 2x Communication locked (non-critical error)
This error indicates access attempts via the communication interface with
wrong passwords.
The error is automatically deleted after the inhibition time or at midnight.
The same applies to messages where the bit is set:
F.F .. .. .. 3x/6x/7x/Ax/Bx/Ex/Fx
F.F 00 00 00 4x Wrong EEPROM/Flash (fatal error)
Incorrect EEPROM/ Flash memory is installed in meter.
The meter does not operate and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. .. 5x/6x/7x/Cx/Dx/Ex/Fx
F.F 00 00 00 8x Wrong extension board (non-critical error)
Identification of extension board differs from that parameterised in the
meter.
The meter might not have the required functions such as data profile,
control inputs or output signals. The meter has to be exchanged.
The same applies to messages where the bit is set:
F.F .. .. .. 9x/Ax/Bx/Cx/Dx/Ex/Fx
6.3 Repairing meters
Meters must only be repaired by the responsible service and repair centre
(or manufacturer).
The following procedure should be adopted if a meter repair is necessary:
1. If the meter is installed, remove the meter as described in section 4.7
"Uninstallation" and fit a substitute meter.
2. Describe the error found as exactly as possible and state the name
and telephone number of the person responsible in case of inquiries.
3. Pack the meter to ensure it can suffer no further damage during
transport. Preferably use the original packing if available. Do not
enclose any loose components.
4. Send the meter to the responsible service and repair centre.
© Landis+Gyr D000045597 en c – S650 Series 3 – SMA300AT/CT – User Manual
Maintenance 75/86
7 Maintenance
This section describes the necessary maintenance work.
7.1 Meter testing
Meter tests should be performed at periodic intervals according to the valid
national regulations (either on all meters or on specific random samples). In
principle, the meters should be uninstalled for this purpose according to the
instructions in section 4.7 "Uninstallation" and replaced by a substitute
meter. The meter test can also be performed on the spot in certain
circumstances.
7.1.1 Test mode
The test mode permits increasing the resolution of the energy registers by 1
to 5 digits. This allows the energy supply company to carry out the so called
measuring unit test in a reasonably short time.
In test mode, the same registers shown as a rolling list in the operating
display are always displayed, but with high resolution and not rolling.
The energy registers comprise a total of 12 digits. A maximum of 8 digits,
however, is shown on the display. The effective number of digits shown and
the number of decimal places are determined by the parameterisation. For
the test mode, more decimal places are normally parameterised (maximum
5) to permit a quicker test of the transmission to the energy registers.
Figure 70. Display changeover normal mode – test mode
Changeover from normal to test mode and back is made by formatted
commands (see section 5.8 "Input of formatted commands") or manually in
the service menu.
In test mode, the optical test output for active energy can also provide
reactive energy pulses depending on the parameterisation. Reactive
energy pulses are supplied to this test output if the register shown on the
display represents a reactive energy register. Active energy pulses are
supplied for all other measured values shown as in normal operating mode.
Formatted commands can also be used to define whether the optical test
output for active energy in test mode should supply active or reactive
energy pulses, independent of the type of register shown on the display.
This permits changeover without manual intervention.
7.1.2 Measuring times
For technical reasons, greater measuring deviations can occur during
short-term measurements. It is therefore recommended to use sufficiently
long measuring times in order to achieve the required accuracy.
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Table of measuring times required at the optical test output:
SMA300xT Measuring uncertainty
0.1 %
Un = 230 V Current 3P 1P 3P
Ib = 5 A % Ib cosφ=1 1 0,5
5 40 s 40 s 90 s
10 20 s 20 s 40 s
20 10 s 10 s 20 s
50 8s 8s 10 s
100 6s 6s 8s
1000 6s 6s 6s
2000 6s 6s 6s
2400 6s 6s 6s
3 P = universal
1 P = single-phase
7.1.3 Optical test output
The red optical test outputs on the meter above the LCD should be used for
meter testing. These supply pulses at a frequency dependent on the meter
constant R, whereby the rising edge is always decisive for the test.
Note that the digital signal processing provides a delay of 2 seconds
between the instantaneous power at the meter and the appearance of the
pulses at the optical test outputs. No pulses are lost.
The number of pulses per second for the desired power is obtained by
multiplying the meter constant R by the power in kW divided by 3600.
Example: Meter constant R = 1000
Power P = 35 kW
f-test output = R x P / 3600 = 1000 x 35 / 3600 = 10 imp/s
The optical test outputs are continuously lit at no-load.
Test mode The test mode enables you to select which measuring value (active,
reactive) is shown on the optical test output.
In the display, values for active, reactive and apparent energy are available.
Depending on parameter setting, the resolution of the display register can
be increased for faster testing. In the test mode, the resolution is increased
by one decimal point compared with the normal mode. A maximum of 5
decimal points is possible.
Operating
display
1. All segments of the Display check
display are lit
2. Enter service menu Set mode
R
3. Select test mode Test mode
© Landis+Gyr D000045597 en c – S650 Series 3 – SMA300AT/CT – User Manual
Maintenance 77/86
4. Enter test mode First value
5. Select required Value x
value
6. Repeat step 3 for all values to be tested
7. Exit test mode Operating
display
Examples
First value and value x are examples. The real values are defined in the
parameter settings and are the same as the operating display.
The measured values are displayed at the optical test outputs as shown in
the following table:
Test output Test output
Mode Register on Display
reactive active
Normal mode Some sort of register |R| |A|
Test mode Reactive energy register |A| |R|
Active energy register or one |R| |A|
of not mentioned registers in
this table.
7.1.4 No-load test
A test voltage Up of 1.15 Un is used for the no-load test (creep test) to IEC
62053-21 (e.g. Up = 265 V with Un = 230 V).
Procedure:
1. Disconnect the meter from the network for at least 10 seconds.
2. Then switch on the test voltage Up and wait approx. 10 seconds. After
this time the energy direction arrows must disappear. The red optical
test outputs are permanently "lit".
3. Switch on test mode (high resolution).
4. The meter must not deliver more than one pulse during the no-load
test. Check the energy levels for changes in test mode. They must not
increase by more than the value of one pulse (see faceplate).
7.1.5 Starting test active part
Procedure:
1. Apply a load current of 0.1% of the base current Ib (IEC-meters) or
0.1% of the reference current Iref (MID-meters) – e.g. 5 mA with Ib=Iref=
5 A – and the voltage Un (three-phase in each case) and cosφ = 1.
The meter must remain in no-load.
2. Increase the load current to 0.4% Ib (IEC-meters) or 0.4% Iref (MID-
meters) – e.g. 20 mA with Ib= Iref = 5 A. The energy direction arrow "P"
must appear within 10 seconds. The optical test output for active
energy consumption is no longer permanently "lit".
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7.1.6 Starting test reactive part
Procedure:
1. Apply a load current of 0.1% of the basic current Ib (e.g. 5 mA with Ib =
5 A) and the voltage Un (three-phase in each case) and sinφ = 1. The
meter must remain in no-load.
2. Increase the load current to 0.4% Ib (i.e. 20 mA with Ib = 5 A). The
energy direction arrow "Q" must appear within 10 seconds. The optical
test output for active energy consumption is no longer permanently "lit".
7.2 Changing the battery
If the meter is provided with a battery, this must be changed if one of the
following events occurs:
The symbol appears on the display.
The battery has been in the meter for more than 10 years (preventive
servicing). It is recommended to note the date of insertion on the
battery. The 10 years depend on the product and on the age of the
battery when inserting it into the meter.
The battery operating hours counter indicates over 80,000 hours (can
be read under code C.6.0 in service mode).
The battery charge indicates less than 4.8 V (can be read under code
C.6.1 in service mode).
Meters with or without battery
Only meters parameterised as "fitted with battery" have the
and the battery operating hours counter.
symbol
Dangerous voltage on contacts in the battery compartment
The contacts in the battery compartment may have mains voltage applied.
Therefore, only remove the battery with the existing battery holder and
insert the new battery only with the battery holder. Ensure that the contacts
are never touched.
Replacement battery
As a replacement, use only a lithium battery with a rated voltage of 6 V and
the same construction as the original battery.
Procedure:
1. Remove the front door seal.
2. Open the front door.
The battery compartment is on the left below the liquid crystal display.
© Landis+Gyr D000045597 en c – S650 Series 3 – SMA300AT/CT – User Manual
Maintenance 79/86
Figure 71. Battery compartment
3. Press on the latch of the plastic battery holder until it releases and then
withdraw the battery holder with the old battery.
Figure 72. Removing the battery
4. Mark the current date on the new battery.
5. Withdraw the old battery from the holder and insert the new battery.
6. Push the battery holder with battery into the battery compartment until
the latch engages.
7. Reset the battery hours counter to zero with the relevant formatted
command (see section 5.8 "Input of formatted commands") or in the
set mode (see section 5.9 "Set time and date, ID numbers, battery
time").
8. Close the front door.
9. Re-seal the front door.
10. Dispose of old batteries as hazardous waste in accordance with local
regulations.
Checking time-of-day and date
After inserting the battery, check the time-of-day and date without power
applied and set these values again, if necessary.
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80/86 Disposal
8 Disposal
Electronic waste treatment
This product must not be disposed of in regular waste. Use a professional
electronic waste treatment process.
The components used to manufacture the device can, in the main, be
broken down into constituent parts and sent to an appropriate recycling or
disposal facility. When the product is removed from use, the whole product
must be sent to a professional electronic waste treatment process. The
waste treatment and disposal plants must be approved by local regulatory
authorities.
The end processing of the product and recycling of its components must
always be carried out in accordance with the rules and regulations of the
country where the end processing and recycling are done.
On request, Landis+Gyr will provide more information about the
environmental impact of the product.
Disposal and environmental protection regulations
The following are general guidelines and should NOT take priority over
local disposal and environmental policies which should be adhered to
without compromise.
Components Disposal
Printed circuit boards, Delivered to recycling plants
LEDs, LCD display
Metal components Sorted and delivered to metal recycling plants
Plastic components Sorted and delivered to re-granulation if at all
possible
Batteries Removed from meter and delivered to
specialised recycling plants
© Landis+Gyr D000045597 en c – S650 Series 3 – SMA300AT/CT – User Manual
Index 81/86
9 Index
.MAP110 ....................................................... 31 Control of display via optical interface ........... 54
Active component ......................................... 15 Cover detection unit ...................................... 51
Active energy ................................................ 18 Creep test...................................................... 77
Active power ................................................. 15 Critical error................................................... 68
Active power calculation ............................... 15 CS interface .................................................. 14
Active power direction ................................... 55 Data preparation for billing ............................ 13
Additional control inputs ................................ 13 Data readout ................................................. 63
Additional output contacts ............................. 13 Data readout via optical interface.................. 63
Alert LED....................................................... 62 Date and time
Anti-tampering features ................................. 31 Set ...................................................... 67, 76
Apparent energy ........................................... 20 DC magnet detection .................................... 32
Apparent energy calculation ......................... 20 Decommissioning .......................................... 80
Aron circuit .................................................... 43 Dedicated event log ...................................... 26
Arrow symbols .............................................. 56 Deleting error messages ............................... 69
Arrows for status indication ........................... 36 Device description ........................................... 8
Automatic data readout ................................. 63 Digital intermediate values ............................ 15
Auxiliary power supply .................................. 13 Dimensions ................................................... 42
Background lighting for LCD ......................... 55 Direct connection ............................................ 8
Backup data checksum error ........................ 72 Direction of rotating field ............................... 23
Backup memory access error ....................... 71 Display .................................................... 36, 55
Basic information for meter connection ......... 43 Display buttons........................................ 33, 53
Basic layout of LCD ...................................... 55 Display check ................................................ 58
Battery charge status .................................... 78 Display examples .......................................... 59
Battery compartment ............................... 34, 79 Display menu ................................................ 58
Battery condition ........................................... 56 Display range changeover ............................ 75
Battery exchange .......................................... 78 Disposal ........................................................ 80
Battery operating hours counter.................... 78 Disposal regulations ...................................... 80
Billing data .................................................... 13 DLMS items................................................... 65
Block schematic diagram .............................. 11 DLMS specification ....................................... 65
Block schematic diagram of measuring unit . 14 Dummy communication unit .......................... 34
Buttons .......................................................... 11 Electronic waste treatment ............................ 80
Calculation of apparent energy ..................... 20 Energy components ...................................... 18
Calibration data checksum error ................... 73 Energy consumption recording ..................... 63
Calibration stage ........................................... 15 Energy magnitude ......................................... 18
Case of meter ............................................... 33 Environmental protection regulations ............ 80
Changing the battery..................................... 78 Error code ..................................................... 68
Changing values in set mode ........................ 67 Error message......................................... 57, 68
Characteristics of meters ................................ 8 Error severity ................................................. 68
Check of connections.................................... 49 Errors for write/read access .......................... 70
Checksum errors........................................... 72 Event log ................................................. 25, 60
Combimeter .................................................... 8 Expired watchdog.......................................... 74
Commissioning ............................................. 49 Extended suspension hook ........................... 44
Communication ............................................. 29 Extension board ............................................ 13
Communication interface .............................. 14 Extension boards .............................. 39, 40, 41
Communication locked.................................. 74 External pulse transmitter ............................. 14
Communication unit ................................ 14, 66 Faceplate ...................................................... 36
Communication unit access error ................. 71 Fatal error...................................................... 68
Connecting conductor ............................. 43, 45 Field of application of meters .......................... 8
Connecting phase connection lines .............. 46 Fixing of cover detection unit ........................ 51
Connecting signal inputs and outputs ........... 47 Form of fixing ................................................ 44
Connecting the meter .................................... 45 Formation of mean values............................. 16
Connection diagrams .......................... 2, 38, 53 Formation of measured quantities................. 18
Connection diagrams extension board ......... 39 Four-quadrant measurement ........................ 19
Connections .................................................. 37 Front door...................................................... 34
Control elements ........................................... 53 Functional check ........................................... 49
Control inputs ................................................ 11 Harmonics ..................................................... 15
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Identification numbers ...................................67 Normal mode ................................................ 75
IEC 62056-21 ..........................................63, 66 Numbering of quadrants ............................... 20
Impulse inputs ...............................................14 OBIS ............................................................. 84
Index field ......................................................56 Objective for DLMS....................................... 65
Index system ...........................................56, 84 Operating display .......................................... 57
Input of formatted commands ........................66 Operating faults ............................................ 68
Input signals ..................................................14 Optical button................................................ 54
Inputs .............................................................11 Optical interface ................................ 33, 36, 66
Installation .....................................................43 Optical test output ............................. 33, 62, 76
Interfaces .......................................................14 Output contacts............................................. 37
Intermediate values .......................................15 Outputs ......................................................... 12
Internal current transformers .........................14 Ownership designation ................................. 37
Invalid clock ...................................................70 Parameter checksum error ........................... 72
Invalid power down ........................................74 Phase angles ................................................ 22
Laptop............................................................63 Phase connections ....................................... 11
LCD .........................................................36, 55 Phase current ............................................... 21
Liquid crystal display .....................................36 Phase voltage ............................................... 21
Lithium battery ...............................................78 Phase voltages ............................................. 56
Load profile 1 .................................................25 Power factor.................................................. 21
Load profile 2 (option) ....................................25 Power supply ................................................ 13
Load profile 2 checksum error .......................73 Profile 2......................................................... 25
Load profile checksum error ..........................72 Program checksum error .............................. 72
Load profile memory access error .................71 Pulse inputs ...................................... 11, 14, 37
Log example ..................................................63 Purpose of this manual ................................... 5
Losses ...........................................................23 Push buttons ................................................. 11
Low battery ....................................................70 Quadrant display........................................... 55
Main characteristics of meters .........................8 Quadrants ..................................................... 19
Main faceplate ...............................................36 Rapid run ................................................ 59, 62
Main memory access error ............................70 Reactive component ..................................... 16
Mains frequency ......................................16, 22 Reactive energy ............................................ 19
Maintenance ..................................................75 Reactive power ....................................... 15, 16
Manufacturer seal ....................................33, 34 Reactive power calculation ........................... 15
MAP120 .........................................................31 Reactive power direction .............................. 55
Mean value formation ....................................16 Reading head ............................................... 63
Measured quantities ................................12, 17 Readout device ............................................. 63
Measured quantity indication .........................37 Readout log .................................................. 63
Measuring deviations .....................................75 Readout to DLMS ......................................... 65
Measuring system .........................................12 Readout to IEC 62056-21 ............................. 63
Measuring system access error .....................71 Recording counting pulses for other physical
Measuring times ............................................75 media ......................................................... 8
Measuring uncertainty ...................................76 Reference documents..................................... 5
Measuring unit ...............................................14 Releasing connection from spring-loaded
Mechanical construction ................................33 terminal .................................................... 48
Memory ..........................................................13 Removing connections in spring-loaded
Meter board ...................................................44 terminals................................................... 51
Meter case .....................................................33 Removing meter ........................................... 51
Meter connection ...........................................45 Repairing meters .......................................... 74
Meter connections .........................................37 Replacement battery..................................... 78
Meter constant ...............................................76 Reset button ................................................. 34
Meter tests .....................................................75 Reset button R .............................................. 54
Modem ...........................................................14 Rolling display............................................... 57
Modifying operating data or meter Rotating field ................................................. 16
characteristics ...........................................66 RS232 interface ............................................ 14
Natural error compensation ...........................15 RS485 interface ............................................ 14
Neutral ...........................................................43 S0 interface................................................... 14
Neutral current ...............................................22 Safety
No-load test ...................................................77 Information ................................................. 6
Non-critical errors ..........................................68 Regulations ................................................ 7
© Landis+Gyr D000045597 en c – S650 Series 3 – SMA300AT/CT – User Manual
Index 83/86
Responsibilities .......................................... 6 Target group of this manual ............................ 5
Seal component ...................................... 35, 36 Tariff control .................................................. 13
Sealing .................................................... 33, 49 Tariff faceplate .............................................. 37
Sealing with padlock ..................................... 35 Telemetering ................................................... 8
Seals ............................................................. 33 Terminal cover ........................................ 33, 34
Self-tests ................................................. 57, 68 Terminal cover detection ............................... 32
Series designation ........................................ 10 Test mode ......................................... 75, 76, 77
Service .......................................................... 68 Test voltage................................................... 77
Service and repair centre .............................. 74 Testing meter ................................................ 75
Service menu ................................................ 61 Time device access error .............................. 71
Set date and time .......................................... 67 Time-base errors ........................................... 69
Set identification numbers............................. 67 Total active energy ........................................ 19
Set mode................................................. 62, 67 Total apparent energy ................................... 20
Set operating time of battery ......................... 67 Total harmonic distortions ............................. 23
Severity of errors........................................... 68 Total reactive energy..................................... 19
Signal processing.......................................... 12 Transmission contact ...................................... 8
Signal processor ..................................... 15, 16 Type designation ........................................... 10
Signal utilisation ............................................ 12 Type of measurement SMA300xT ................ 14
SMA300AT/CT ................................................ 8 Types of display ............................................ 57
Software tools ............................................... 30 Types of error ................................................ 69
Software version ........................................... 10 Uninstallation................................................. 51
Spring-loaded terminals ................................ 38 Units field ...................................................... 56
Standard data ............................................... 58 Utility seal ................................................ 33, 34
Starting test ................................................... 77 Value display ........................................... 59, 61
Status indication arrows ................................ 36 Value field ..................................................... 56
Stored value profile ....................................... 25 Verification seal ....................................... 33, 34
Stored values checksum error ...................... 73 Viewing window............................................. 34
Structure of error messages ......................... 69 Voltage divider .............................................. 14
Substitute meter ................................ 52, 74, 75 Wrong EEPROM/Flash ................................. 74
Summation channels .................................... 24 Wrong extension board ................................. 74
Suspension eyelet ......................................... 44 Zero passage .......................................... 16, 22
Suspension triangle ...................................... 44
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84/86 Appendix 1 OBIS code
Appendix 1 OBIS code
Object Identification System
The OBIS code (Object Identification System) is structured as follows:
A B C D E F Value group
M- KK: GG. AA. T W According to VDEW
A: Medium Defines the medium used. If only one medium is used it does not have to
[1 … 9] be specified. The Values represent the following objects:
1 Electricity
2, 3 not used
4 Heating costs
5 Cooling system
6 Heating system
7 Gas
8 Cold water
9 Hot water
B: Channel Defines the channel number, i.e. the number of the input of a metering
[1 … 64] equipment with several inputs for the measurement of energy of the same
or different types (e.g. in data concentrators, registration units). This
enables data from different sources to be identified. If only one channel
(only one meter) is used, it does not have to be specified.
C: Measured quantity Defines the abstract or physical data items related to the information
[1 … 99] source concerned, e.g. active power, reactive power, apparent power,
cos, current or voltage.
General data 0
Active energy + (import) ∑Li 1 L1 21 L2 41 L3 61
– (export) 2 22 42 62
Reactive energy + 3 23 43 63
– 4 24 44 64
QI (quadrant I) 5 25 45 65
QII 6 26 46 66
QIII 7 27 47 67
QIV 8 28 48 68
Apparent energy + (import) 9 29 49 69
– (export) 10 30 50 70
Current 11 31 51 71
Voltage 12 32 52 72
Power factor 13 33 53 73
Frequency 14
Service data C
Error message F
Profile data P
© Landis+Gyr D000045597 en c – S650 Series 3 – SMA300AT/CT – User Manual
Appendix 1 OBIS code 85/86
D: Measuring type Defines types, or the result of the processing of physical quantities
[1 ... 73, F, P] according to various specific algorithms. The algorithms can deliver energy
and demand quantities as well as other physical quantities.
The following list is an excerpt.
Capture period 1 2 3
Cumulated minimum 1 11 21
Cumulated maximum 2 12 22
Minimum 3 13 23
Running average 4 14 24
Last average 5 15 25
Maximum 6 16 26
Instantaneous value 7
Time integral 1 (energy status) 8
Time integral 2 (energy consumption) 9
Time integral 3 (excess consumption) 10
...
Test average 55
Test time integral 4 58
...
Error message F
Load profile 01
E: Tariff Defines the further processing of measurement results to tariff registers,
[1 ... 9] according to the tariffs in use. Total values are marked with ‘0’. For abstract
data or for measurement results for which tariffs are not relevant, this value
group can be used for further classification.
F: Stored value Defines the storage of data according to different billing periods. Where this
[01 ... 99] is not relevant, this value group can be used for further classification.
Display code To simplify the reading of the display code, individual parts of the OBIS
code can be omitted. The abstract or physical data C and type of data D
must be shown.
Examples
1.8.0 1 = all-phase active power in positive direction
8 = cumulative value (meter reading)
0 = total energy (no tariffs)
0.9.1 Local time
D000045597 en c – S650 Series 3 – SMA300AT/CT – User Manual © Landis+Gyr
Contact:
Landis+Gyr AG
Theilerstrasse 1
CH-6301 Zug
Switzerland
Phone: +41 41 935 6000
www.landisgyr.com
Hans Sokk
Saatja: Priit Poschlin
Saatmisaeg: 16. jaanuar 2017. a. 8:39
Adressaat: Hans Sokk
Teema: FW: Type approval application Landis+Gyr E650/S650
Manused: type_approval_certificate_application_01_LG_E650_S650_20170113.pdf;
Certification_tax_payment_confirmation.pdf; E650
_ZMD300xT_UserManual_D000030108_m_EN.pdf; E650
_ZxD400xT_UserManual_D000030110_g_EN.pdf; S650
_SMA300xT_UserManual_D000045597_c_EN.pdf; S650
_SxA400xT_UserManual_D000045599_c_EN.pdf; T10033R12.pdf
Tõsta manused GPsse. Ja tuleb ilmselt sama vastus, mis trafodelegi.
From: Toomas Tamm
Sent: Monday, January 16, 2017 8:29 AM
To: Priit Poschlin <
[email protected]>
Cc: Hans Sokk <
[email protected]>
Subject: FW: Type approval application Landis+Gyr E650/S650
Hommik
Tuli otse minu meili, sest eelmine kord tegelesin mingi tüübikinnitusega neile.
Toomas
From: Komppa, Jarmo [mailto:
[email protected]]
Sent: Friday, January 13, 2017 5:11 PM
To: Toomas Tamm <
[email protected]>
Subject: Type approval application Landis+Gyr E650/S650
Hello Toomas,
the type approval certificate (TJA 4.5-8/09.04.08) for the meter family E650/S650 will expire soon. We have received
new revision for NMi certificate T10033, revision 12, for the meter family.
Please find attached our type approval application for the extension of the existing TJA certificate.
With any questions or notices, just contact me.
Kind regards,
Jarmo
______________________________________________________________________________________________________
Jarmo Komppa | Landis+Gyr Oy | Sales Manager, Baltics
Phone: +358 40 715 9689 |Switchboard: +358 14 660 100
Email:
[email protected] | Site: www.landisgyr.com/europe | Address: Salvesenintie 6, 40420 Jyskä, Finland
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Electricity Meters IEC/MID
Industrial and Commercial
SMA400AT/CT, SFA400AT/CT
S650 Series 3
User Manual
Date: 22.04.2016
File name: D000045599 S650 SxA400xT Series 3 User Manual en c.docx
© Landis+Gyr D000045599 en c
2/94 Revision history
Revision history
Version Date Comments
a 26.09.2012 First edition
b 29.10.2013 Synchronised document version indicators across all languages.
Updated disclaimer.
Reformatted warnings, cautions and notes.
Corrected minor terminology, spelling and punctuation errors.
Added extension board 047x to section 2.3 “Type designation”.
Added information on 3-phase, 3-wire (no neutral) connections to section 3.4
“Connection diagrams (examples)”.
Added extension board 0470 to section 3.4 “Connection diagrams (examples)”.
c 22.04.2016 Updated to firmware version B33:
Updated section 2.5.3 “Measured quantities” (TTHD and losses)
Updated section 2.5.4 “Formation of measured quantities” (TTHD and losses).
Updated section 2.6.3 “Event log”.
Updated section 5.1 “Operation with auxiliary power supply”.
Although the information contained within this document are presented in good faith and believed to be correct, Landis+Gyr (including its
affiliates, agents and employees) disclaim any and all liability for any errors, inaccuracies or incompleteness relating to the product.
Landis+Gyr makes no warranty, representation or guarantee regarding the performance, quality, durability or suitability of the products for
any particular purpose. To the fullest extent permitted by law Landis+Gyr disclaims (1) any and all liability arising out of the use of the
product, (2) any and all liability, including, but without limitation to, special, consequential and indirect damages and losses, and (3) any and
all implied warranties, including, but without limitation to, fitness for purpose and merchantability.
The information contained in this document is strictly confidential and is intended for the addressee only. The unauthorised use, disclosure,
copying, alteration or distribution of this document or the contents thereof is strictly prohibited and may be unlawful.
All product information are subject to change without notice.
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Table of contents 3/94
Table of contents
Revision history...................................................................................................................................... 2
Table of contents ................................................................................................................................... 3
About this document .............................................................................................................................. 5
1 Safety ............................................................................................................................................. 6
1.1 Safety information ..................................................................................................................... 6
1.2 Responsibilities ......................................................................................................................... 6
1.3 Safety regulations ..................................................................................................................... 7
1.4 Radio Interference .................................................................................................................... 7
2 Device description........................................................................................................................ 8
2.1 Field of application .................................................................................................................... 8
2.2 Characteristics .......................................................................................................................... 8
2.3 Type designation..................................................................................................................... 11
2.4 Block schematic diagram ........................................................................................................ 12
2.5 Measuring system ................................................................................................................... 15
2.5.1 Input signals ...................................................................................................................... 15
2.5.2 Signal processor ................................................................................................................ 16
2.5.3 Measured quantities .......................................................................................................... 18
2.5.4 Formation of measured quantities ..................................................................................... 20
2.5.5 Summation channels ......................................................................................................... 25
2.6 Data profile.............................................................................................................................. 26
2.6.1 Stored value profile ........................................................................................................... 26
2.6.2 Load profile 1 and load profile 2 (option) ........................................................................... 26
2.6.3 Event log ........................................................................................................................... 26
2.7 Communication ....................................................................................................................... 30
2.7.1 Optical interface ................................................................................................................ 30
2.7.2 Communication units ......................................................................................................... 30
2.8 MAP software tools ................................................................................................................. 32
2.9 Anti-tampering features ........................................................................................................... 32
2.9.1 DC magnet detection ......................................................................................................... 33
2.9.2 Terminal cover detection ................................................................................................... 33
3 Mechanical construction ........................................................................................................... 34
3.1 Housing ................................................................................................................................... 34
3.2 Faceplates .............................................................................................................................. 37
3.3 Connections ............................................................................................................................ 38
3.4 Connection diagrams (examples) ........................................................................................... 40
3.5 Dimensions ............................................................................................................................. 45
4 Installation and uninstallation ................................................................................................... 46
4.1 Basic information for connecting the meter ............................................................................. 46
4.1.1 Connection to low voltage with current transformers......................................................... 46
4.1.2 Connection to medium and high voltage (Aron circuit) ...................................................... 47
4.1.3 Connection to medium and high voltage (three-phase four-wire circuit) ........................... 48
4.2 Mounting the meter ................................................................................................................. 49
4.3 Connecting the meter .............................................................................................................. 51
4.3.1 Connecting the RS485 interface........................................................................................ 54
4.4 Check of connections .............................................................................................................. 55
4.5 Commissioning, functional check and sealing ........................................................................ 55
4.6 Installation of terminal cover detection .................................................................................... 57
4.7 Uninstallation .......................................................................................................................... 58
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5 Operation .....................................................................................................................................60
5.1 Operation with auxiliary power supply .....................................................................................60
5.2 Control elements .....................................................................................................................60
5.2.1 Display buttons ..................................................................................................................60
5.2.2 Control of display via optical interface................................................................................61
5.2.3 Reset button .......................................................................................................................61
5.3 Display .....................................................................................................................................62
5.3.1 Introduction ........................................................................................................................62
5.3.2 Basic layout ........................................................................................................................62
5.3.3 Index system ......................................................................................................................63
5.4 Types of display .......................................................................................................................64
5.4.1 Operating display ...............................................................................................................64
5.4.2 Display menu .....................................................................................................................65
5.4.3 Service menu .....................................................................................................................68
5.5 Alert LED .................................................................................................................................69
5.6 Optical test output ....................................................................................................................69
5.7 Data readout ............................................................................................................................70
5.7.1 Readout to IEC 62056-21 ..................................................................................................71
5.7.2 Readout to DLMS...............................................................................................................72
5.8 Input of formatted commands ..................................................................................................73
5.9 Set time and date, ID numbers, battery time ...........................................................................74
6 Service .........................................................................................................................................76
6.1 Operating faults .......................................................................................................................76
6.2 Error messages .......................................................................................................................76
6.2.1 Structure of an error message ...........................................................................................77
6.2.2 Error groups .......................................................................................................................77
6.3 Repairing meters .....................................................................................................................82
7 Maintenance ................................................................................................................................83
7.1 Meter testing ............................................................................................................................83
7.1.1 Test mode ..........................................................................................................................83
7.1.2 Measuring times .................................................................................................................83
7.1.3 Optical test output ..............................................................................................................84
7.1.4 No-load test ........................................................................................................................85
7.1.5 Starting test active part ......................................................................................................85
7.1.6 Starting test reactive part ...................................................................................................86
7.2 Changing the battery ...............................................................................................................86
8 Disposal .......................................................................................................................................88
9 Index .............................................................................................................................................89
Appendix 1 OBIS code ..................................................................................................................92
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About this document 5/94
About this document
Range of validity The present user manual applies to the meters specified on the title page.
Purpose The user manual contains all the information required for metering
applications for the intended purpose. This includes:
Provision of knowledge concerning the characteristics, construction
and function of the meters
Information about potential dangers, their consequences and
measures to prevent any danger
Details about the performance of all activities throughout the service
life of the meters (parameterisation, installation, commissioning,
operation, maintenance, decommissioning and disposal)
Target group The content of this user manual is intended for technically qualified
personnel of utilities (energy supply companies), responsible for system
planning, installation and commissioning, operation, maintenance,
decommissioning and disposal of meters.
Reference documents The following documents provide further information related to the subject
of this document:
D000045762 "S650 SxA400xT Series 3 Technical Data"
D000030112 "E650 ZxD/S650 SxA Series 3 Functional Description"
Conventions The structure and significance of meter type designations are described in
section 2.3 "Type designation". The following conventions are employed in
this user manual for representing type designations:
The lower case letter "x" can be used as an unknown to indicate
different versions (e.g. SxA400 for the SMA400 and SFA400 meters or
SMA410xT for the SMA410AT and SMA410CT meters).
The digit pair "00" can be used to indicate accuracy data (e.g. SxA400
for the SxA405 and SxA410 meters).
The abbreviated type designation SMA or SFA meters can be used
when all three-phase four-wire meters or three-phase three-wire
meters are meant.
The following collective terms are also sometimes used instead of the
type designation:
– "Active energy meters" for the SxA400AT meters
– "Combi-meters" for the SxA400CT meters
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1 Safety
This section describes the safety information used in this manual, outlines
the responsibilities and lists the safety regulations to be observed.
1.1 Safety information
The following symbols are used to draw your attention to the relevant
danger level, i.e. the severity and probability of any danger, in the individual
sections of this document.
Warning
Used to indicate a dangerous situation that could cause bodily injury or
death.
Caution
Used to indicate a situation/ action that could result in material damage or
loss of data.
Note
Used to indicate general guidelines and other useful information.
In addition to the danger level, safety information also describes the type
and source of the danger, its possible consequences and measures for
avoiding the danger.
1.2 Responsibilities
The owner of the meters – usually the utility company – is responsible for
ensuring that all persons working with meters:
Have read and understood the relevant sections of the user manual.
Are appropriately qualified for the work to be performed.
Strictly observe the safety regulations (laid down in section 1.3) and
the operating instructions as specified in the individual sections.
In particular, the owner of the meters bears responsibility for the protection
of persons, prevention of material damage and the training of personnel.
For this purpose, Landis+Gyr provides training on a variety of products and
solutions. Contact your local Landis+Gyr representative if interested.
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1.3 Safety regulations
The following safety regulations must be observed at all times:
The meter connections must be disconnected from all voltage sources
during installation or when opening.
Contact with live parts can be fatal. The relevant supply fuses should,
therefore, be removed and kept in a safe place until the work is
completed so that other persons cannot replace them unnoticed.
Local safety regulations must be observed. Only technically qualified
and appropriately trained personnel are authorised to install the
meters.
Only appropriate tools shall be used for the job. This means, e.g. that
the screwdriver must be of the correct size for the screws, and the
handle of the screwdriver must be insulated.
Secondary circuits of current transformers must be short-circuited (at
the test terminal block) without fail before opening. The high voltage
produced by an interrupted current transformer circuit is dangerous to
life and destroys the transformer.
Transformers in medium or high voltage systems must be earthed on
one side or at the neutral point on the secondary side. Otherwise they
can be statically charged to a voltage which exceeds the insulation
strength of the meter and is also dangerous to life.
The meters must be held securely during installation. They can cause
injuries if dropped.
Meters that have been dropped must not be installed, even if no
damage is apparent, but must be returned to the service and repair
department (or the manufacturer) for testing. Internal damage may
result in malfunctions or short-circuits.
The meters must never be cleaned under running water or with
compressed air. Water ingress can cause short-circuits.
1.4 Radio Interference
Possible radio interference in residential environments
This meter is normally a class B product. In combination with some
communication modules it can become a Class A product. In a domestic
environment, this may then cause radio interference, in which case the user
may be required to take adequate measures.
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2 Device description
This section provides you with a brief overview of the design and function of
the S650 SxA400AT/CT meters (smart grid terminals).
2.1 Field of application
SxA400xT meters can be used for transformer connection at all three
voltage levels, namely on low, medium and high voltage. They are primarily
used by medium and large consumers and in the field of energy generation
and exchange.
The SMA400xT meter is especially suitable for applications at the low
voltage level, while the SFA400xT meter is generally used more at the
medium and high voltage levels.
SxA400xR meters are well suited for street light applications with
embedded astronomical clock and combinations of control saving signals
coming from light sensors, measurements or other digital inputs.
SxA400xT meters have a comprehensive tariff structure. This extends from
seasonal tariffs to multiple energy and demand tariff rates.
The SMA400xT and SFA400xT meters are designed for connection to
current transformers with 5 A or 1 A rated current or as a special version for
both applications (5//1).
The SMA400CT and SFA400CT combi-meters record active and reactive
energy consumption, the SMA400AT and SFA400AT active energy meters
only the active energy in three-phase four-wire or three-phase three-wire
networks (low, medium and high voltage) and from this determine the
required electrical measured quantities. For this purpose they are
connected to the measuring point via current transformers and possibly
also voltage transformers:
Low voltage: SMA400xT with current transformers
Medium voltage: SFA400xT (sometimes also SMA400xT) with current
and voltage transformers
High voltage: SMA400xT (sometimes also SFA400xT) with current
and voltage transformers
The data determined are displayed (LCD) and are also available at the
optical interface for data acquisition, with an appropriate communication
unit also as required via CS, RS232, RS485, modem, etc.
When equipped with transmitting contacts, the meters can also be used as
transmitting meters for telemetering. The tariff rates can be controlled
internally or externally.
With a communication unit, the meters can also be used for recording
counter pulses for other physical media (e.g. water or gas volumes).
2.2 Characteristics
SxA400xT meters have the following basic characteristics:
Recording of active, reactive and apparent energy in all four quadrants
(SxA400CT) or recording of imported and exported active energy
(SxA 400AT)
Tariff system with energy and demand tariff rates, stored values, load
profiles, etc.
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Astronomical clock generating 2 energy saving signals to control 2
relays outputs, if option selected
Extended functions such as monitoring functions, sliding maximum
demand, etc. (for SxA400CT additionally power factor and
displacement power factor), Voltage/current unbalance
Tariff control
– External
- via control inputs (SxA400xT21 and SxA400xT41)
- via communication interfaces using formatted commands
– Internal
- by integral time switch (SxA400xT24 and SxA400xT44)
- by event signals based on monitored values, such as voltage,
current and demand.
Display of data on a liquid crystal display (LCD)
Active and reactive power per phase and true RMS values of voltages
and currents by means of digital signal processing (DSP) chips
Accuracy: Compliance with IEC class 1 or 0.5 S and with MID
accuracy class B or C for active energy consumption (SxA400xT) and
IEC class 1 for reactive energy (SxA400CT).
Exception: SxA402CT – IEC class 0.2S for active energy and IEC
class 0.5 for reactive energy.
Flexible measuring system through parameterisation (definition of
different variables by software)
Correct measurement even with failure of individual phases or when
used in two- or single-phase networks
Wide range of measurement from starting current to maximum current
Optical interface according to IEC 62056-21 and DLMS
– For direct readout of meter data
– For service functions of the meter, extension board and
communication unit (e.g. parameterisation)
Inputs for recording fixed valency pulses (communication unit)
Output contacts (solid-state relays) for fixed valency pulses, control
signals and status messages
Output contacts (relays) for control signals and status messages
Input contact for alarm monitoring and sending advanced SMS
messages, if suitable optional communication unit selected
Installation aids
– Indication of phase voltages, phase angles, rotating field and
direction of energy
Storage of event information, e.g. voltage failures, exceeding of
thresholds or error messages. Event information can be read out via
the available interfaces. Important events can be communicated to the
energy supply company as operational messages (sending of
advanced SMS messages, control of an arrow in the display, drive for
an output contact, etc.).
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Interfaces such as CS, RS232, RS485, modem, etc. for remote
transmission of data (communication unit)
Auxiliary power supply for communication with the meter if no
measuring voltage is present
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2.3 Type designation
SMA 4 10 C T 44 4207 S3
Network type
SFA 3-phase, 3-wire network (F-circuit)
SMA 3-phase, 4-wire network (M-circuit)
Connection type
4 Transformer operated
Accuracy class
10 Active energy class 1 (IEC), B (MID)
05 Active energy class 0.5 (IEC), C (MID)
02 Active energy class 0.2 (IEC)
Measured quantities
C Active and reactive energy
A Active energy
Construction
T With exchangeable communication units
Tariffication
21 Energy rates, external rate control via control inputs
24 Energy rates, internal rate control via time switch
(additionally possible via control inputs)
41 Energy and demand rates, external rate control via control inputs
44 Energy and demand rates, internal rate control via time switch
(additionally possible via control inputs)
All versions with 3 control inputs and 2 output contacts
Additional functions
000x No extension board
060x 6 outputs
240x 2 control inputs, 4 outputs
326x 3 control inputs. 2 relays outputs, auxiliary power supply 12–24 VDC
420x 4 control inputs, 2 outputs
045x 4 outputs, auxiliary power supply 100–240 VAC/VDC
046x 4 outputs, auxiliary power supply 12–24 VDC
047x 4 outputs, auxiliary power supply 12–60 VDC
008x Supercapacitor board
xxx0 No additional functions
xxx2 DC magnet detection
xxx7 Load profile
xxx9 DC magnet detection and load profile (integrated terminal cover switch option only available
in this configuration)
Series 3
As the communication unit is a device on its own, it is not part of the meter’s
type designation. The customer can exchange it at any time without opening
the certification seal. Each communication unit has its own user manual.
Series designation S3 (Series 3) represents the newest hardware generation.
Firmware version The firmware version and firmware checksum stored in the meter can be
shown on the display or read out as IEC readout list, if parameterised
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accordingly (see section 5.7 "Data readout"). Specific meter characteristics
are present or not depending on the firmware version.
Class 0.2 Some executions of SMA400CT/CR meters are available with accuracy
class 0.2S. These meters fulfil the IEC accuracy class 0.2S for active
energy and class 0.5 for reactive energy. For details, see the corresponding
datasheet.
2.4 Block schematic diagram
This section provides an overview of the function of SxA400xT meters
based on a block schematic diagram.
Figure 1. Block schematic diagram SMA400xT
The SxA400AT active energy meters record the imported and exported
active energy consumption, while the SxA400CT combi-meters record the
active and reactive energy consumption in all four quadrants.
The SxA400xT meters can be fitted with modular communication interfaces
in a communication unit, which can be exchanged or used in the field as
required.
Inputs The main meter inputs are:
Connections of phase voltages (U1, U2, U3), phase currents (I1, I2, I3)
and neutral conductor N
– For processing in the measuring system
– For the three-phase power supply to the meter and voltage monitor
Control inputs Ut (3 fixed, plus up to 4 others on extension board) for:
– Changeover of energy and demand tariff rates
– Resetting
– Demand inhibition
– Synchronising
Optocouplers protect the internal circuitry from interference, which
could otherwise enter via the control inputs.
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Buttons
– For display control (display buttons, optical interface)
– For resetting or service functions (reset button)
Pulse inputs for connection of external pulse transmitters (only for
meters equipped with a communication unit)
Outputs The meter has the following outputs:
LCD display with display buttons for local reading of billing data (single
8-digit display with additional information, such as energy direction,
type of energy, presence of phase voltages and identification number)
Optical test outputs (red, 1 in active energy meters, 2 in combi-meters)
Optional alert LED (red) to indicate alerts on the front face of the meter
Static relay with freely parameterised signal assignment (2 fixed, plus
up to 6 others on the extension board)
Relay outputs with limited parameterised signal assignment due to
limited life expectancy (up to 2 on the extension board)
Optical interface for automatic local data acquisition by a suitable
acquisition unit (handheld terminal)
Communication interfaces of various kinds in the communication unit
(also see section 0 " * Firmware version B33 or higher.
Communication")
Measuring system The input circuits (voltage dividers and current transformers) record voltage
and current in the individual phases. Analogue-digital converters digitise
these values and feed them as instantaneous digital values via calibration
stages to a signal processor.
Signal processing The signal processor determines the following measured quantities from
the instantaneous digital values of voltage and current for each phase and
forms their mean value over one second:
Active power per phase
Reactive power per phase (combi-meters SxA400CT only)
Phase voltages
Phase currents
Network (mains) frequency
Phase angles
Signal utilisation For signal utilisation in the various registers, the microprocessor scans the
measured quantities every second to determine the following values:
Active energy (sum and individual phases, separated according to
energy direction, if required in the combi-meters SxA400CT also
assigned to the 4 quadrants)
Reactive energy (only for combi-meters SxA400CT, sum and individual
phases, separated according to energy direction, assigned to the 4
quadrants)
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Apparent energy (only for combi-meters SxA400CT, sum and
individual phases, separated according to energy direction)
Power factor and displacement power factor cosφ (only for combi-
meters SxA400CT, individual phases and mean value)
Phase voltages
Phase currents and neutral current
Voltage and current unbalance
Active and reactive power
Direction of rotating field
Total harmonic distortions of active energy, voltage and current
Energy losses (line losses and transformer losses)
Rate control Rate control is performed:
Externally via control inputs (3 fixed, plus up to 4 others on the
extension board)
Externally via communication interfaces using formatted commands
Internally by time switch and calendar clock
By event signals based on threshold values of the monitoring functions
Data preparation for The following registers are available for evaluation of the individual
billing measured values:
32 for energy rates
27 for total energy
10 for running mean demand values
24 for demand rates
2 for power factors (combi-meters SxA400CT only)
Up to 41 diagnostic registers
Others for values of voltage and current, network frequency and phase
angles
Memory A non-volatile flash memory serves to record data profiles and also
contains the configuration and parameterisation data of the meter and
secures the billing data against loss due to voltage failures.
Power supply The supply voltages for the meter electronics are obtained from the three-
phase network, whereby the phase voltage can vary over the entire voltage
range without the supply voltage having to be adjusted. A voltage monitor
ensures correct operation and reliable data recovery in the event of a
power failure and correct restarting when the voltage is restored.
Auxiliary power For medium or high-voltage applications in particular, the measuring
supply voltage can be switched off. Since the meter normally obtains its supply
from the measuring voltage, it is also switched off and cannot be read. The
auxiliary power supply connected in parallel with the normal power supply
ensures operation of the meter free from interruption, so that it can be read
at any time. The auxiliary power supply is situated on an extension board.
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Extension board The extension board is fitted inside the meter and is secured by the
certification seals. It cannot be exchanged. It can have the following
components:
Up to 4 control inputs in combination with
Up to 6 output contacts (solid-state relays)
Up to 2 relays outputs
An auxiliary power supply
A supercapacitor board
Communication unit The communication unit for fitting only in the SxA400xT meters is a
complete unit in its own case. If present, it is situated behind the front door,
and is therefore secured by a utility seal and can be exchanged or inserted
in the field if necessary. It contains:
Communication interfaces as required for remote readout of the meter
(e.g. CS, RS232, RS485, modem)
Two signal inputs (S0 interfaces) for processing external pulse
transmitters
2.5 Measuring system
Figure 2. Block schematic diagram of measuring system
2.5.1 Input signals
The meter has the analogue current values I1, I2 and I3 and analogue
voltage values U1, U2 and U3 available as input signals.
SMA400xT
Figure 3. Type of measurement SMA400xT
Since the SMA400xT measures the individual phases mutually
independently with one measuring element each, it can record the sum of
the three phases, the individual phases themselves, the phase angle
between voltage and current as well as the angle between voltages U1–U2
and U1–U3.
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SFA400xT
Figure 4. Type of measurement SFA400xT
The SFA400xT with Aron circuit records the phase currents I1 or I3,
together with the corresponding voltage U12 or U32, with its two measuring
elements. It cannot therefore construct any actual single-phase values. In
addition, the phase angles between voltage and current always have an
additional angle of 30° and are therefore not representative.
Voltage input High resistance voltage dividers reduce the voltages U1, U2 and U3 (58 to
240 V) applied to the meter to a proportionate amount of a few mV (UU) for
further processing.
Current input Internal current transformers reduce the input currents I1, I2 and I3 to the
meter (0 to 10 A) for further processing. The secondary currents of these
current transformers develop voltages proportional to the input currents
across resistors, also of a few mV (UI).
2.5.2 Signal processor
Figure 5. Principle of signal processor
SxA400AT active energy meters do not measure reactive energy.
Digitizing The analogue signals Ux and Ix are digitised in Sigma-Delta converters
(analogue-digital converters with highest resolution) with a sample rate of
1.6 kHz and then filtered. A following calibration stage compensates for the
natural errors of the voltage divider or current transformer, so that no
further adjustment is necessary in the subsequent processing.
Calibrated digital instantaneous values of voltage (u) and current (i) for all
three phases are then available as intermediate values for the formation of
the required values in the signal processor.
Calculation of active The instantaneous value of active power p is produced by multiplying the
power instantaneous values of voltage u and current i (the active component
corresponds to the product of voltage component with the current
component parallel to the voltage). Thereby the harmonics up to 1 kHz are
measured correctly.
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IQ I
Calculation per phase of
P = U . I . cos
IP U
Figure 6. Active power calculation
Instantaneous power If the meter is parameterised to calculate instantaneous power as signed
with sign values, the following values of power are available:
Active P: + in QI and QIV, - in QII and QIII
Reactive P: + in QI and QII, - in QIII and QIV
Calculation of reactive There are two possibilities to calculate the instantaneous value of reactive
power power (SxA400Cx combi-meters only):
Measured:
For the instantaneous value of reactive power q the instantaneous value of
voltage u must be rotated by 90° before multiplication (the reactive
component is the product of the voltage component with the current
component vertical to the voltage). Thereby no harmonics are measured
since only the fundamental wave is rotated through 90°.
IQ I
Calculation per phase of
Q = U . I . sin
IP U
Figure 7. Reactive power calculation (method: measured)
Calculated vectorial (not recommended):
The instantaneous value of reactive power is calculated using the values of
active power and apparent power.
The reactive power is the square root of the square value of apparent
power minus the square value of active power. This method includes the
harmonics.
URMS, IRMS calculation The square values of voltage and current are obtained by multiplying the
instantaneous values of voltage and current by themselves. From these
values the signal processor forms the corresponding single-phase RMS
values URMS and IRMS.
Time measurement The network frequency can be calculated from the time measured between
two zero passages (change from negative to positive value of voltage U1).
The times between zero passage of the phase voltage U1 and those of the
other phase voltages U2 and U3 serves to determine the phase angle
between the voltages and of the rotating field.
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U1 U2 U3 Time measurement
for rotating field,
frequency, phase angle
1 : T U1-U2
2 : T U1-U3
1
2
3 : TU1-U1 (fn)
3
Figure 8. Time measurement
The phase angle between voltage and current is determined by the times
between zero passage of the phase voltage U1 and those of the phase
currents I1, I2 and I3.
Mean value formation For further processing of the individual signal the signal processor
generates mean values over one second, which the following
microprocessor scans at intervals of one second.
2.5.3 Measured quantities
Measured quantity SMA400 SFA400
Active energy in quadrant I A (QI) Sum / Phases Sum
Active energy in quadrant II A (QII) Sum / Phases Sum
Active energy in quadrant III A (QIII) Sum / Phases Sum
Active energy in quadrant IV A (QIV) Sum / Phases Sum
Active energy import +A (QI+QIV) Sum / Phases Sum
Active energy export –A (QII+QIII) Sum / Phases Sum
Active energy, absolute value +A+-A Sum / Phases Sum
Active energy, absolute value +A--A Sum / Phases Sum
Active energy import summation Σ +A Sum Sum
Active energy export summation Σ -A Sum Sum
Active energy by single quantity Σ ALx Sum Sum
Reactive energy in quadrant I R (QI) Sum / Phases Sum
Reactive energy in quadrant II R (QII) Sum / Phases Sum
Reactive energy in quadrant III R (QIII) Sum / Phases Sum
Reactive energy in quadrant IV R (QIV) Sum / Phases Sum
Reactive energy import +R (QI+QII) Sum / Phases Sum
Reactive energy export –R (QIII+QIV) Sum / Phases Sum
Reactive energy import +R (QI+QIV) Sum / Phases Sum
Reactive energy export –R (QII+QIII) Sum / Phases Sum
Reactive energy, combined R (QI+QIII) Sum / Phases Sum
Reactive energy, combined R (QII+QIV) Sum / Phases Sum
Reactive energy, absolute value +R+-R Sum / Phases Sum
Reactive energy, absolute value +R--R Sum / Phases Sum
Reactive energy import summation Σ +R Sum Sum
Reactive energy export summation Σ -R Sum Sum
Apparent energy import +S (QI+QIV) Sum / Phases Sum
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Measured quantity SMA400 SFA400
Apparent energy export -S (QII+QIII) Sum / Phases Sum
Phase voltages (RMS) U1, U2, U3 U12, U32
Phase voltages (RMS) U12, U23, U31 U12, U32
Phase currents (RMS) I1, I2, I3 I1, I3
Neutral current I0 yes no
Network frequency fn yes yes
Active power ±P Sum / Phases Sum
Reactive power ±Q Sum / Phases Sum
Phase angle between voltages U U1-U2 / U1-U3* no
Phase angle between voltage and U-I U1-I1, U1-I2, no
current U1-I3 * or
U1-I1, U2-I2,
U3-I3
Power factor PF Sum / Phases Sum
Displacement power factor cosφ Sum / Phases no
Voltage unbalance ∆U yes no
Current unbalance ∆I yes no
Direction of rotating field yes yes
THD of active energy import +THDA Sum Sum
THD of active energy export -THDA Sum Sum
THD of active energy (percent) THDA [%] Sum Sum
THD of phase voltages (absolute) THDU Phase 1, 2, 3 Phase 1, 3
THD of voltage (percent) THDU [%] Sum Sum
THD of phase currents (absolute) THDI Phase 1, 2, 3 Phase 1, 3
THD of current (percent) THDI [%] Sum Sum
TTHD of active power TTHDA [0;1] Sum Sum
TTHD of phase current TTHDV [0:1] Phase 1, 2, 3 Phase 1, 3
TTHD of phase voltage TTHDI [0:1] Phase 1, 2, 3 Phase 1, 3
TTHD of voltage TTHDV [0:1] Sum Sum
TTHD of current TTHDI [0:1] Sum Sum
Line (copper) losses of active OLA Sum no
energy
Transformer (iron) losses of active NLA Sum no
energy
Signed line (copper) losses of ±OLA Sum no
active energy **
Signed transformer (iron) losses of ±NLA Sum no
active energy **
Voltage square hours U2h Sum Sum
Ampere square hours I2h Sum Sum
* Only if U1 is present.
** Firmware version B33 or higher. OLA/NLA not accessible, if
±OLA/±NLA selected.
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2.5.4 Formation of measured quantities
By scanning the mean values of active power P, and in combi-meters also
reactive power Q every second, energy components are produced (Ws or
vars) at fixed intervals (every second) and with varying energy magnitudes
or demand. These energy components are scaled by the microprocessor
corresponding to the meter constant and are then available as measured
quantities for selection of the measured values. The measured values are
fed directly to the following registers to record the energy and the maximum
demand (in combi-meters also of minimum power factor).
Active energy The active energy in the individual phases ±A1, ±A2 and ±A3 are formed
directly from the mean values of active power P1, P2 and P3.
By summating the mean values of active energy A1, A2 and A3 the
microprocessor calculates the total active energy import +A or the total
active energy export -A.
Mean values
per second Measured quantities
± A1
+A (Import)
±A 2 -A (Export)
±A3
Figure 9. Total active energy
Reactive energy The reactive energy values of the individual phases ±R1, ±R2 and ±R3 are
obtained in the combi-meters directly from the mean values of reactive
power Q1, Q2 and Q3. The reactive energy can therefore also be
calculated vectorially (see 1.5.2).By summating the mean values of reactive
energy R1, R2 and R3, the microprocessor calculates the total positive
reactive energy +R or the total negative reactive energy -R.
Mean values
per second Measured quantities
± R1
+R
±R2 -R
±R3
Figure 10. Total reactive energy
The microprocessor can allocate the reactive energy to the 4 quadrants in
the combi-meters from the signs of R and A:
Reactive energy in 1st quadrant: +Ri
Reactive energy in 2nd quadrant: +Rc
Reactive energy in 3rd quadrant: –Ri
Reactive energy in 4th quadrant: –Rc
In the same way, it can allocate the reactive energy of the individual phases
to the 4 quadrants.
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+R
+ kvarh + kvarh
+Rc +Ri
Quadrant II Quadrant I
Export -A +A Import
- kWh Quadrant III Quadrant IV + kWh
- kvarh
-Ri -Rc - kvarh
-R
Figure 11. 4-quadrant measurement
The quadrants are numbered from top right as 1st quadrant (+A/+Ri) anti-
clockwise to the 4th quadrant (+A/–Rc) at bottom right.
Apparent energy The apparent energy is calculated in the combi-meters in two ways:
By vectorial addition of the active and reactive energy of the individual
phases
By multiplying the rms values of voltage and current of the individual
phases
The method of calculation can be parameterised (only one possible in each
case).
Calculation method 1 From the mean values A1, A2 and A3 and R1, R2 and R3, the
(vectorial addition) microprocessor calculates the apparent energy of the individual phases
±S1, ±S2 and ±S3 as well as the total apparent energy ±S.
Mean values
per second
±A1
±A2 Measured quantities
±A3
2 2 +S (Import)
(A1 + A2 + A3) + (R1 + R2 + R3)
±R1 -S (Export)
±R2
±R3
Figure 12. Total apparent energy according to calculation method 1
Only fundamental wave considered for reactive energy
Only the fundamental wave is considered for the calculation of the reactive
energy share; possible harmonics are not taken into account.
Calculation method 2 From the mean values U1rms, U2rms, U3rms and I1rms, I2rms, I3rms, the
(from rms values) microprocessor calculates by multiplication the apparent power of the
individual phases ±VA1, ±VA2 and ±VA3 and summates these for the total
apparent power ±VA.
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Mean values
per second
I1rm s
U1rm s
I1rm s U1 rm s
å Measured quantities
I2rm s +S (Import)
U2rm s
I2rm s U2 rm s
å -S (Export)
I3rm s
U3rm s
I3rm s U3 rm s
å
Figure 13. Total apparent power according to calculation method 2 (SxA400Cx
combi-meters only)
Harmonics considered for reactive energy
As RMS values are used for the calculation of the apparent energy with
calculation method 2, not only the fundamental wave but also the
harmonics are taken into account. Therefore, if harmonics are present, the
measured values are greater than those of calculation method 1.
Summation channels The values of two measurement quantities (incl. pulse inputs EX1 and EX2)
can be added.
Power factor The power factor (PF) is calculated in combi-meters as follows:
The meter uses the method of calculation employed for calculating the
apparent power.
The PF calculation includes harmonics versus the displacement power
factor cosφ.
In case of high harmonic perturbations, the difference between PF and
cosφ can be significant.
For instance, THD I ~50% involves PF 10% lower than cosφ.
Displacement The displacement power factor (dPF) cosφ is calculated in combi-meters as
power factor cosφ follows:
It takes into account only the fundamental wave versus PF that includes
rms values.
Phase voltages The rms values of the voltages U1rms, U2rms and U3rms are obtained from
the mean values of the squares of the voltages by extracting the root and
directly from these the phase voltages U1, U2 and U3.
U12, U23 and U31 voltages are computed from U1, U2 and U3.
Voltage unbalance The voltage unbalance is computed according to the ratio of the maximum
difference between phase voltage maximum and averaged 3 phase
voltage.
| – |
∗ 100
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3
Phase currents The rms values of the currents I1rms, I2rms and I3rms are obtained from the
mean values of the squares of the currents by extracting the root and
directly from these the phase currents I1, I2 and I3.
Current unbalance The current unbalance is computed according to the maximum difference
between maximum phase current and averaged 3 phase current.
| – |
∗ 100
3
Neutral current The signal processor calculates the instantaneous neutral current i0 by
adding the instantaneous phase currents i1, i2 and i3.
i2
i0 = i1 + i2 + i3
i1 (vectorial addition)
i3
i0
Figure 14. Neutral current I0
Network frequency The signal processor calculates the network frequency fn by forming the
reciprocal from the time tU1-U1 between two zero passages of voltage U1.
Phase angles The signal processor calculates the phase angles between voltages U1-U2
and U1-U3 from the times tU1-U1, tU1-U2 and tU1-U3 between zero passages of
the various voltages.
The signal processor calculates the phase angle between voltage U1 and
current per phase from the times tU1-I1, tU1-I2 and tU1-I3 between zero
passages of the voltage U1 and the phase currents.
Two forms of representation are available for displaying the phase angle.
These can be selected by parameterisation.
Case 1: All voltage and current angles are displayed clockwise with
reference to the voltage in phase 1. The values of the angles are always
positive and can be from 0 to 360°.
Figure 15. Phase angle case 1
Case 2: The voltage angles are displayed as in case 1. The angles of the
currents are displayed, however, with reference to the associated phase
voltage and can have values between -180° and +180°.
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Figure 16. Phase angle case 2
Direction of rotating The direction of the rotating field is calculated by the microprocessor based
field on the phase angle of the 3 voltages. If the direction of rotation
corresponds to that specified by the parameterisation, the phase voltage
indications L1, L2 and L3 are continuously lit. Otherwise they flash every
second.
Total harmonic The measuring system produces information about the total harmonic
distortion distortion of the active energy.
For that purpose, the voltages are fed through notch filters, which remove
the fundamental wave.
+A +THDA
+THDA = +A - (+A fundamental)
-A -THD A
-THDA = -A - (-A fundamental )
Figure 17. Calculation of total harmonic distortion
In addition, the following absolute and relative THD values available:
THD of active energy (relative to the nominal active energy)
THD of phase voltages (absolute)
THD of voltage (relative to the nominal voltage)
THD of phase currents (absolute)
THD of phase current (relative to the nominal current)
True total harmonic The TTHD information is calculated based on a comparison of the values of
distortion the harmonic contents and the value of the fundamental (in firmware
version B33 or higher).
TTHD of active power
TTHD of phase voltage
TTHD of phase current
TTHD of voltage
TTHD of current
Losses Depending on the metering point in the network, the meter does not only
measure the net energy that is transferred from the power station to the
user but also the line losses (caused by the copper resistance RCu) and the
transformer losses (caused by the iron resistance RFe).
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Metering point A Metering point B Metering point C
RFe
RCu
Generator Load
Transmission
Production Meter A Meter B Customer
Figure 18. Calculation of Losses
Line losses are caused by the copper resistance RCu of the transmitting
line. The copper resistance is only effective if there is a load and therefore
current is actually flowing.
On Load Active OLA for line losses of active energy
The transformer losses represent all losses of the transformer. They are
mainly caused by the iron core of the transformer. Transformer losses
(equivalent resistance RFe) are present whenever the transformer is
connected to the network.
No Load Active NLA for transformer losses of active energy
Based on the IRMS and URMS values, the microprocessor generates the
following measured quantities:
OLA On load active. Line (copper) losses of active energy.
OLA = I2h x RCu. The value of RCu can be set by parameterisation.
NLA No load active. Transformer (iron) losses of active energy.
NLA = U2h / RFe. The value of RFe can be set by parameterisation.
I2h (Cu) Ampere square hours (with RCu = 1)
2
U h (Fe) Voltage square hours (with RFe 1 M)
From firmware version B33 onwards, it is possible to track signed losses
(±NLA/OLA). If this option is chosen, NLA and OLA losses are not available
any more as these registers are used for signed losses.
2.5.5 Summation channels
The values of two measurement quantities (incl. pulse inputs EX1 and EX2)
can be added.
Energy registers which contain the summation of two measured quantities
(summation channels) cannot be used for tariffication.
ME1
EX1
EX2
MExx
+ Total energy register
Figure 19. Summation channels
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2.6 Data profile
A non-volatile memory (FLASH memory) contains the data of:
The stored value profile
The load profile 1
The load profile 2 (optional)
The event log
The three groups of dedicated event logs
The flash memory stores data without data loss in case of voltage failures.
No battery is required for this purpose.
The total size of the available memory for the stored billing value profile, the
load profile(s), the event log and the dedicated event logs is 1.8 MB.
2.6.1 Stored value profile
At the end of the billing period, the meter stores the current value of the
registers to the stored value profile. Which energy registers and/or demand
registers are stored to the stored billing value profile can be selected by
parameterisation.
Memory organisation The stored value profile is organised as a circular buffer, i.e. the oldest
entry will be overwritten by the most recent entry. The memory capacity
which is available for the stored value profile depends on parameterisation.
2.6.2 Load profile 1 and load profile 2 (option)
The load profiles are used to save the values of various registers at regular
intervals. The measured values that are captured in the load profile can be
selected by parameterisation.
Load profile 2 is optional
The second load profile is optional.
Consult your sales representative for further details.
Profile 1 The first load profile is generally used for billing purposes. Its capture
period has a range of 1...60 min. This load profile may also contain
instantaneous values and detailed status information for data processing in
central stations.
Profile 2 The second load profile can be used to store instantaneous values over a
period which differs from the period of the first load profile. Apart from the
differing capture period, the second load profile is identical with the first
load profile.
Memory organisation The load profile is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry. The memory capacity which is
available for the load profile(s) depends on parameterisation. If both load
profiles are activated, they share the memory capacity which is allocated to
the load profile(s).
2.6.3 Event log
Events that occur sporadically are stored in the event log. The user may
select which events trigger an entry in the event log. The event log is used
to analyse the behaviour of the network as well as to supervise the correct
function of the meter.
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Memory organisation In the event log, a maximum of 500 event entries can be stored. The
individual entries consist of the time stamp and the event number.
Additional information such as the error register or energy total registers
can also be stored with every event.
The event log is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry.
Dedicated event log Network quality events, can be stored in the dedicated event log. The
dedicated event log consists of three groups of logs.
Overvoltage events
Undervoltage events
Missing voltage events
In the dedicated event logs, important information can be stored per entry
such as:
Duration of the events
Extreme values of the events (not for missing voltage).
Instantaneous values
Maximum three energy registers
Additional information can be read from the header of the event logs, such
as the longest entry, the shortest entry, the total number of occurrence and
the total duration of the event.
Memory organisation The dedicated event logs are organised as circular buffers, i.e. the oldest
entry will be overwritten by the most recent entry.
List of events The table below lists all events which can be captured in the event log.
Depending on the parameterisation, some events may never occur.
Events which can be stored in the dedicated event log are marked in the
corresponding column.
Number Event Entry in dedicated
event log possible
2 All energy registers cleared
3 Stored values and/or load profile cleared
4 Event log profile cleared
5 Battery voltage low
7 Battery ok
8 Billing period reset
9 Daylight saving time enabled or disabled
10 Clock adjusted (old time/date)
11 Clock adjusted (new time/date)
17 Undervoltage L1 (below threshold 1*) x*
18 Undervoltage L2 (below threshold 1*) x*
19 Undervoltage L3 (below threshold 1*) x*
20 Overvoltage L1 (above threshold 1*) x*
21 Overvoltage L2 (above threshold 1*) x*
22 Overvoltage L3 (above threshold 1*) x*
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Number Event Entry in dedicated
event log possible
23 Power down
24 Power up
25 Overcurrent L1
26 Overcurrent L2
27 Overcurrent L3
28 Overcurrent neutral
31 Power factor monitor 1
32 Power factor monitor 2
33-40 Demand monitors 1-8
45 Error register cleared
49 Missing voltage L1 x
50 Missing voltage L2 x
51 Missing voltage L3 x
55 Current without voltage L1
56 Current without voltage L2
57 Current without voltage L3
58 Missing additional power supply
59 All registers and profiles cleared
63 Wrong phase sequence
64 Correct phase sequence
66 Invalid clock
74 Backup memory access error
75 Measuring system access error
76 Time device access error
77 Load profile memory access error
79 Communication unit access error
80 Display board access error
81 Program checksum error
82 Backup data checksum error
83 Parameter checksum error
84 Load profile checksum error
85 Stored values checksum error
86 Event log checksum error
87 Calibration data checksum error
88 Load profile 2 checksum error
89 Invalid start-up sequence
93 Expired watchdog (general system error)
94 Communication locked
96 Wrong extension board identification
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Number Event Entry in dedicated
event log possible
104 Count registers cleared
105 SMS delivery to GSM failed
106 Alert occurred
124 Compensation values changed
128 Energy total and rate register cleared
133 Terminal cover removed
134 DC Field detected ON
179 Undervoltage L1 above threshold 1*
180 Undervoltage L2 above threshold 1*
181 Undervoltage L3 above threshold 1*
182 Overvoltage L1 below threshold 1*
183 Overvoltage L2 below threshold 1*
184 Overvoltage L3 below threshold 1*
187 Terminal cover mounted
188 DC Field detected OFF
193 Load profile 2 cleared
201 Undervoltage L12 x
202 Undervoltage L23 x
203 Undervoltage L31 x
204 Overvoltage L12 x
205 Overvoltage L23 x
206 Overvoltage L31 x
207 Voltage unbalance
208 Voltage unbalance disappeared
209 Current unbalance
210 Current unbalance disappeared
211 Control input 1 set
212 Control input 1 reset
213 Control input 2 set
214 Control input 2 reset
215 Control input 3 set
216 Control input 3 reset
217 Control input 4 set
218 Control input 4 reset
219 Control input 5 set
220 Control input 5 reset
221 Control input 6 set
222 Control input 6 reset
223 Control input 7 set
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Number Event Entry in dedicated
event log possible
224 Control input 7 reset
225 Undervoltage L1 below threshold 2*
226 Undervoltage L2 below threshold 2*
227 Undervoltage L3 below threshold 2*
228 Undervoltage L1 above threshold 2*
229 Undervoltage L2 above threshold 2*
230 Undervoltage L2 above threshold 2*
231 Undervoltage L1 below threshold 3*
232 Undervoltage L2 below threshold 3*
233 Undervoltage L3 below threshold 3*
234 Undervoltage L1 above threshold 3*
235 Undervoltage L2 above threshold 3*
236 Undervoltage L2 above threshold 3*
* Firmware version B33 or higher.
2.7 Communication
The SMA400xT meters have an optical interface for local communication
via a readout head and a wide range of communication interfaces, which
can be inserted in the meter.
2.7.1 Optical interface
The optical interface to IEC 62056-21 is a serial, bi-directional interface. It
is situated at top right on the main faceplate (also see section 3
"Mechanical construction") and serves:
For automatic local data recording by means of a suitable acquisition
unit (hand-held terminal) (see section 5.7 "Data readout")
For performing service functions, e.g. to input formatted commands
(see section 5.8 "Input of formatted commands")
As "optical button", i.e. as receiver of a light signal, e.g. generated by a
flashlight acting like the "down" display button (also see section 5.2.2
"Control of display via optical interface")
For communication with a Landis+Gyr .MAP110 service tool or a
Landis+Gyr MAP120 parameterisation tool.
2.7.2 Communication units
The communication units which can be inserted in the meter can be used:
For remote reading and for remote tariff control of meters (RS232,
RS485, CS, M-Bus, PSTN modem, GSM modem, GPRS modem,
Ethernet, etc.) or
For recording metering pulses for other physical media, such as
water, gas or heat (S0 interface).*
Access via the communication interfaces is protected for specific access
levels using the meter security system by means of passwords. If the
monitoring is activated by corresponding parameterisation, communication
is inhibited for a selected time (max. 24 h) after a selected number of
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password attempts with an incorrect password (max. 15). Monitoring takes
place independent of all access levels with password protection and for the
IEC W5 password.
The communication devices are accommodated in an easily exchanged
communication unit, which is plugged in behind the front door of the meter
and secured by a utility seal (also see section 3 "Mechanical construction").
It can be fitted and removed at any time in the field without touching the
certification seal. Landis+Gyr recommend exchanging communication units
only if the meter is separated from the network and switched off.
An initial fitting as well as retrofitting without re-parameterisation of the
meters is possible with any version of communication unit. For fitting and
removal of the already parameterised communication units, the installation
personnel do not require any special knowledge of communications.
Modern plug connections ensure a rapid and faultless connection of the
communication units.
* As well for the recording and the summation of metering pulses for other
electricity devices.
Figure 20. Simple fitting of the communication unit
Versions of Communication units (CU) are available in various versions. The document
communication units "Overview of Communication Applications", D000011226 contains a list of
all currently available CU-interfaces with explanations.
Further information More detailed information about Landis+Gyr Dialog communication
sources solutions can be found in the following documents.
Technical data for the various communication units
User manuals for the various communication units
Detailed application notes for numerous reference applications with
various communication units for different transmission media:
– Point-to-point Connection with internal PSTN Modem Mx
(D000011505)
– Point-to-point Connection with internal GSM Modem Gx
(D000011506)
– Etc.
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All these documents as well as advisory services are available from
authorised Landis+Gyr representatives.
2.8 MAP software tools
There are two software tools available for parameterisation of the S650
meter and for communication with the meter: .MAP110 and MAP120
Areas of application
Figure 21. Application of MAP software tools
.MAP110 The .MAP110 Service Tool covers the following applications normally
required for meter installation and in the service sector:
Billing data readout
Readout and export of profiles (load profile(s), stored values and event
log, dedicated event logs)
TOU (Time of Use) readout and modification
Billing period reset
Register and profile resets
Setting of certain parameter ranges, such as primary data, time switch,
communication parameters, etc.
Communication input settings
Communication settings for Landis+Gyr communication units readout
and modification
GSM installation aid for Landis+Gyr communication units (field
strength indicators, telephone number information, PIN code handling)
Test SMS message transmission
Analysis and diagnostic functions
MAP120 The Landis+Gyr MAP120 software is used to parameterise the meter and
the communication unit, i.e. it is possible to read out and modify all device
parameters.
In contrast to communication devices from other manufacturers, no
additional software and training costs are incurred by the use of Landis+Gyr
communication units, since the MAP software tools support both meters
and communication units.
2.9 Anti-tampering features
The following anti-tampering features are available for SMA400xT meters:
DC magnet detection for the detection of strong magnetic fields close
to the meter. This feature is installed during the manufacturing
process.
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Terminal cover detection for the detection of situations when the
terminal cover has been opened. This feature can be a retrofit or an
integrated version. The integrated version is available if the DC
magnet detection option is selected and must be integrated during
manufacturing process.
Example of integrated terminal cover switch available from mid-2012.
2.9.1 DC magnet detection
The meters SxA410xT, SxA405xT and SxA402CT can be ordered with a
feature which detects strong DC magnetic fields. When a magnetic field is
present, event 134 is set; when the magnetic field disappears, event 188 is
set. These events can e.g. be entered into the event log with date and time.
The meter’s type description informs you whether this feature has been
implemented (see page 11).
With the DC magnet detection, it is possible to order the integrated terminal
cover detection option.
2.9.2 Terminal cover detection
Installed SMA400 meters can be equipped with a terminal cover detection
unit. For this, they need to be parameterised and the unit – consisting of a
switch which detects the removal of the terminal cover – has to be installed.
Whenever the retrofit terminal cover is removed, it detects the switch status
change via control input 1 and enters event 211 in the event log with date
and time. When the terminal cover is mounted again, event 212 is entered
in the event log with date and time.
Order terminal cover detection units – part number 74 766 0163 0
(minimum order quantity 10) – from:
Landis+Gyr AG
Service & Repair
Theilerstrasse 1
CH-6301 Zug
Switzerland
For installation of the unit, see section 4.6 "Installation of terminal cover
detection".
In case of the integrated terminal cover switch used, the event 133 is set
when the terminal cover is removed and event 187 when the terminal cover
is mounted.
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3 Mechanical construction
This section describes the mechanical construction of the SxA400xT meter
and shows the most common connection diagrams.
3.1 Housing
The internal construction of the meters is not described here, since they are
protected following calibration and official certification on delivery by a
manufacturer and certification seal. It is not permitted to open the meters
after delivery. The front door is only secured with a utility seal and can be
opened to operate the reset button, to change the battery, to exchange the
tariff faceplate with connection diagram or to fit or remove a communication
unit (see figure 23 and separate user manuals for the communication units
available).
The following drawing shows the meter components visible from outside.
Figure 22. Meter SxA400xT
1 Combined suspension hanger 10 Display button "down"
(open or concealed)
2 Screw with manufacturer seal 11 Front door tariff faceplate
3 Optical test output reactive 12 Upper part of case
energy consumption (red),
SxA400CT only
4 Optical test output active energy 13 Lower part of case
consumption (red)
5 Liquid crystal display (LCD) 14 Utility seal for front door
6 Optical interface 15 Terminal cover
7 Screw with certification seal 16 Terminal cover screws with utility
seals
8 Front section with main faceplate 17 Alert LED (optional)
9 Display button "up"
Case The meter case is made of antistatic plastic (polycarbonate). The upper
part of the case is provided with two transparent plastic viewing windows,
affording a view of the main faceplate (top) and the tariff faceplate (bottom).
The lower part of the case is additionally glass-fibre reinforced.
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Viewing window The upper viewing window with the main faceplate is secured on the upper
right side with a certification seal, while the upper part of the case is
secured on the upper left side with a manufacturer seal (warranty) or a
second certification seal.
The lower viewing window is in the form of a hinged front door, secured
with a utility seal. The tariff faceplate with the connection diagram on the
rear side, the battery compartment, the reset button and (if present) the
communication unit are situated behind this front door.
Terminal cover The terminal cover is available in various lengths in order to ensure the
required free space for the connections.
Front door The front door must be opened to give access to the battery compartment,
reset button and tariff faceplate. To fit or remove the communication unit
the terminal cover must also be removed.
Figure 23. Meter with front door open
1 Battery compartment
2 Reset button R
3 Communication unit or dummy
Figure 24. Meter with communication unit withdrawn
If the meter has no communication unit, this is replaced by a dummy case.
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Seal component An additional component, which is easy to install, allows the use of a
standard padlock instead of a utility seal.
Figure 25. Front door sealing using a padlock
The seal component is stowed away in a holder under the front door when
not in use.
Figure 26. Stowage of seal component when not in use
The seal component is installed as follows:
Slide the seal component into the vertical slot at an angle, as shown,
(position 1) until it contacts the rear wall.
Now turn the seal component until it is horizontal and slide it down into
position 2 as illustrated. The two bulges firmly fix the seal component
into the lateral grooves.
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Figure 27. Seal component for use with padlock
3.2 Faceplates
All relevant data for the meter are provided on the faceplates inscribed
according to customer specifications.
Main faceplate The main faceplate is situated behind the plastic viewing window, which is
secured by a certification seal. Recesses permit operation of the display
buttons "down" and "up" for control of the liquid crystal display.
1 2 3
Landis+Gyr S650
Readout
imp imp
13 Cl. 1
kvarh
1000
kWh
Cl. 1 4
Three-phase four-wire meter
12 SMA410CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 5(10) A 50 Hz 5
20XX
6
11 7
10 8
9 T1 T2 T3 SET Test
Figure 28. Main faceplate (example SMA410CT)
1 Optical test output reactive energy
(with accuracy class – SxA400CT only)
2 Meter constant R1 (referred to primary values) or R2
3 Optical test output active energy (with accuracy class)
4 Optical interface
5 Approval symbol
6 Type of connection
7 Display button "up"/Display button "down"
8 Symbol for double protective insulation
9 Status indication
10 Arrows for present status indication
11 Liquid crystal display (LCD)
12 Meter data (type designation, serial number, rated values, year of
construction)
13 Alert LED (optional)
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The operating elements and displays are described more detailed in
section 5 "Operation".
Tariff faceplate The tariff faceplate is placed in the front door, which can be swung out
sideways to the left and is secured by a utility seal. The connection diagram
of the meter is shown on the back of the faceplate and is therefore visible
with the front door open.
Figure 29. Tariff faceplate (example SxA400CT)
1 General data appearing in the display
2 Measured quantities
3 Pulse input data
4 Output contact data
5 Ownership designation
6 Transformer data and readout factor
7 Communication unit data (if present)
3.3 Connections
Figure 30. Meter with terminal cover removed
The terminal block with all meter connections is situated behind the
terminal cover. Two utility seals in the fixing screws of the terminal cover
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prevent unauthorised access to the phase connections and therefore also
prevent unrecorded energy consumption.
Terminal layout The top row of terminals (level 1) consists of spring-loaded terminals and
(example SMA400xT) comprises
Extension board terminals on the left
Depending on the version, up to 4 control inputs or 6 output contacts, 3
digital inputs and 2 relays outputs or a combination of these with
maximum 6 inputs and outputs, or voltage connections for a separate
supply.
Communication unit terminals on the right
The centre row of terminals (level 0) likewise consists of spring-loaded
terminals and comprises:
Voltage outputs U1, U2, U3 and N, tapped from the relevant phase input
3 fixed control inputs with a common return line G (electrically isolated)
2 output contacts for transferring fixed valency pulses or control
signals (electrically isolated)
The lower row of terminals comprises the phase connections with input and
output of the circuit for each phase with the voltage connection in between
and neutral conductor.
Figure 31. Terminal layout SMA400xT according to DIN
Apart from the common terminal layout according to DIN the SMA400
meters are also available optionally with symmetrical terminal layout.
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Figure 32. Symmetrical terminal layout SMA400xT
3.4 Connection diagrams (examples)
Binding connection diagrams
The following connection diagrams should be considered examples. The
connection diagrams provided at the rear of the front door and visible when
the door is open are always binding for the installation.
SFA400xT
for three-phase
three-wire networks
Figure 33. Connection diagram of measuring unit SFA400xT with current
transformer
Figure 34. Connection diagram of measuring unit SFA400xT with current and
voltage transformers
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Symmetrical terminal layout
The version with symmetrical terminal layout (option) is available only for
SMA400 meters for three-phase four-wire networks.
Artificial star point
* With the three-wire circuit, the artificial star point (terminal 11) must not be
externally wired.
SMA400xT
for three-phase
four-wire networks
Figure 35. Connection diagram of measuring unit SMA400xT with current
transformer (terminal layout according to DIN)
Figure 36. Connection diagram of measuring unit SMA400xT with current
transformer (symmetrical terminal layout)
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Figure 37. Connection diagram of measuring unit SMA400xT with current and
voltage transformers (terminal layout according to DIN)
In case the SxA400 is used in a 3-wire network without neutral:
For a 3-phase, 3-wire connection, the measurement of phase-to-neutral
voltage as well as the measurement of single-phase energy have no
meaning, as no neutral voltage is supplied to the meter.
Control inputs / Basic version:
output contacts 3 control inputs
2 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 38. Connection diagram fixed control inputs/output contacts
Extension board Extension board 4200:
4200 4 control inputs
2 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 39. Connection diagram extension board with 4 control inputs and 2 output
contacts
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Extension board Extension board 2400:
2400 2 control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 40. Connection diagram extension board with 2 control inputs and 4 output
contacts
Extension board Extension board 0600:
0600 no control inputs
6 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 41. Connection diagram extension board with 6 output contacts
Extension board Extension board 0450:
0450 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 42. Connection diagram extension board with auxiliary power supply and 4
output contacts
Extension board Extension board 0460:
0460 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 43. Connection diagram extension board with auxiliary power supply and 4
output contacts
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Extension board Extension board 0470:
0470 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 44. Connection diagram extension board with auxiliary power supply and 4
output contacts
Extension board Extension board 3260:
3260 with auxiliary power supply
3 control inputs
2 relay outputs (8 A)
G + - Signal allocation and numbering of
terminals for free parameterisation
50 51 52 53 15 16 17 18 61 64
Figure 45. Connection diagram extension board with auxiliary power supply,
3 control inputs and 2 relay outputs
Extension board No terminal accessible Extension board 0080:
0080 Supercapacitor energy back-up to
send an SMS in case of power
failure
Ground terminal connection
Note that the Ground terminal (G) of the control inputs on the extension
boards is NOT internally connected to the Ground terminal on the base. If
the Ground level is the same, then an external wire must be connected
between the two Ground terminals.
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3.5 Dimensions
6.2 75
extended hook: 230
extended hook: 305.5
standard hook: 206
standard hook: 281.5
190
26
40
150
177 75
Figure 46. Meter dimensions (Standard terminal cover)
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4 Installation and uninstallation
This section describes the installation and connection of meters for
transformer connection. In addition, the necessary steps for checking the
connections, commissioning of the meter and the final functional check are
described as well as the uninstallation.
Dangerous voltage
Dangers can arise from live electrical installations to which the meters are
connected. Touching live parts is dangerous to life. All safety information
should therefore be strictly observed without fail.
4.1 Basic information for connecting the meter
It is recommended to use the following circuits whenever possible for
connecting the meter to the various voltage levels.
Terminal layout
In the following illustrations the terminal layout is shown according to DIN.
For the version with symmetrical terminal layout, which is optionally
available for SMA400 meters for three-phase four-wire networks, the
different terminal numbers according to the connection diagram must be
observed.
4.1.1 Connection to low voltage with current transformers
Figure 47. Connection to low voltage with current transformers
Test terminal block The secondary circuit of a current transformer must always be closed when
current is flowing in the primary. Opening of the secondary circuit can
destroy the transformer. The test terminal block shown in figure 47 allows
the secondary circuits to be short-circuited and the voltage circuits to be
opened in order to exchange the meter without interrupting operation.
Preliminary fuses The preliminary (supply) fuses in the voltage circuit (max. 10 A) protect
against short-circuits in the measuring circuit. The voltage circuits are
connected directly to the primary and would only be protected by the main
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fuses of 100 A or more if the preliminary fuses were not fitted. A short-
circuit would certainly destroy the measuring device and cause fire and
other damage.
4.1.2 Connection to medium and high voltage (Aron circuit)
This circuit is used above all in the medium voltage range (3 to 30 kV) and
rarely with high voltage (from 30 kV).
It is also recommended here to insert a test terminal block between
transformer and measuring device (meters and others). This permits simple
exchange without interrupting operation. On the other hand, no preliminary
supply fuses are necessary in the voltage circuits, since the voltage
transformers cannot produce a high short-circuit capacity on the secondary
side.
Grounding On medium and high voltage the secondary side of all voltage transformers
should be grounded for safety reasons. Otherwise potentials could develop,
which could result in dangerous contact voltages.
Grounding
All following drawings can be used without potential transformers but in any
cases fuses must protect the voltage lines (see section 4.1.1). Then
grounding neutral meter point is not required except in some S650
applications with voltage phase-ground monitoring requirements.
Three-phase
three-wire meter
Figure 48. Connection to medium and high voltage (Aron circuit)
Instead of the three-phase three-wire meter SFA400 the power supply
company can also use a three-phase four-wire meter SMA400. The
following two connections are then possible:
With 2 voltage transformers and open star point at the meter
With 3 voltage transformers and star point connected at the meter
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Three-phase four-wire
meter (with open star
point at meter)
Figure 49. Connection to medium and high voltage
four-wire meter with open star point
Three-phase four-wire
meter (with star point
connected at meter)
Figure 50. Connection to medium and high voltage
four-wire meter with star point connected
4.1.3 Connection to medium and high voltage (three-phase four-wire circuit)
This circuit is mainly used with high voltage (from 30 kV). The same
conditions then apply as for the Aron circuit.
Figure 51. Connection to medium and high voltage (three-phase four-wire circuit)
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4.2 Mounting the meter
Dangerous voltage on conductors
The connecting conductors at the point of installation must be voltage-free
for installation of the meter. Contact with live components is dangerous to
life. The relevant supply fuses should therefore be removed and kept in a
safe place until finishing work, so that they cannot be re-inserted by other
persons unnoticed.
The jumpers in the voltage connections must also be opened at the test
terminal block (e.g. TVS14). For this purpose, release the screw of the
relevant jumper with an insulated screwdriver, move the jumper away from
the terminal on the meter side and then re-tighten the screw.
If no test terminal block is available, the primary voltage must be
interrupted, i.e. the system switched off.
Dangerous voltage on current transformers
The current transformer secondary circuits must not be opened when
current is flowing in the primary. This would produce a dangerous voltage
at the terminals of several thousand volts and the insulation of the
transformer would be destroyed.
To install the meter, short-circuit the secondary of the current transformer at
the test terminal block (e.g. TVS14). For this purpose, release the screw of
the relevant short-circuiting jumper with an insulated screwdriver, move the
jumper away over the terminals on the meter side and then re-tighten the
screw. The circuit on the meter side can then be opened without danger.
If no test terminal block is available, the primary voltage must be
interrupted, i.e. the system switched off.
When you have identified the correct meter position for mounting the meter,
it should be mounted as follows on the meter board or similar device
provided for this purpose:
1. Determine the desired form of fixing (open/covered meter mounting or
extended suspension hook for 230 mm suspension triangle height). If
holes for a suspension triangle height of 230 mm are already present,
use the optional extended suspension hook depicted below. This
hook can be ordered with the part number 74 109 0072 0 (minimum
order quantity 50) from:
Landis+Gyr AG
Service & Repair
Theilerstrasse 1
CH-6301 Zug
Switzerland
Figure 52. Extended suspension hook
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2. Either set the meter suspension hook in the relevant position as shown
below or replace the suspension hook with the extended hook by lifting
the latch slightly and pulling out the shorter hook. Insert the extended
hook into the grooves in the same way the shorter hook was inserted
(bent towards rear) and push it down until it clicks into place.
Figure 53. Positioning of meter suspension eyelet
3. Check with a phase tester or universal measuring instrument whether
the connecting wires are live. If so, remove the corresponding supply
fuses and keep them in a safe place until installation is completed, so
that they cannot be replaced by anyone unnoticed. Open the voltage
connections at the test terminal block with an insulated screwdriver
and check whether the short-circuit jumpers of the circuit are closed.
4. In case there are no holes provided, e.g. as in the case with the
230 mm suspension triangle: Mark the three fixing points (suspension
triangle as in following illustration) on the mounting surface provided:
– horizontal base of suspension triangle = 150 mm
– height of suspension triangle for open mounting = 206 mm
– height of suspension triangle for covered mounting = 190 mm
206 or 190 mm respectively
75 mm
150 mm
Figure 54. Drilling plan
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5. Drill the three holes for the fixing screws.
6. Unscrew the meter terminal cover.
7. Fit the meter with the three fixing screws on the mounting surface
provided.
4.3 Connecting the meter
Dangerous voltage on conductors
The connecting conductors at the point of installation must be voltage-free
for installation of the meter. Contact with live components is dangerous to
life. The relevant supply fuses should therefore be removed and kept in a
safe place until finishing work, so that they cannot be re-inserted by other
persons unnoticed.
The jumpers in the voltage connections must also be opened at the test
terminal block (e.g. TVS14). For this purpose release the screw of the
relevant jumper with an insulated screwdriver, move the jumper away from
the terminal on the meter side and then re-tighten the screw.
If no test terminal block is available, the primary voltage must be
interrupted, i.e. the system switched off.
Dangerous voltage on current transformers
The current transformer secondary circuits must not be opened when
current is flowing in the primary. This would produce a dangerous voltage
at the terminals of several thousand volts and the insulation of the
transformer would be destroyed.
To install the meter, short-circuit the secondary of the current transformer to
the test terminal block (e.g. TVS14). For this purpose release the screw of
the relevant short-circuiting jumper with an insulated screwdriver, move the
jumper away over the terminals on the meter side and then re-tighten the
screw. The circuit on the meter side can then be opened without danger.
If no test terminal block is available, the primary voltage must be
interrupted, i.e. the system switched off.
Preliminary work It is assumed that the transformers and test terminal blocks have already
been correctly fitted, the current transformers are short-circuited and the
voltage connections opened.
Grounding
When using voltage transformers, the secondary star-point (or centre point
in Aron circuit) of the transformer is grounded. The secondary circuits of the
current transformers are also earthed one side (connection k).
Preliminary supply fuses must be used with direct voltage connection. The
current transformers must not be earthed on the secondary side in this
case, see connection diagram.
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Figure 55. Test terminal block status before installing the meter (terminal layout
according to DIN)
Connecting The electrical connections to the meter should be made as follows
according to the connection diagram:
1. Check whether the preliminary work described above has been
performed. If not, complete this work (test terminal blocks should only
be touched with an insulated screwdriver).
2. Check with a phase tester or universal measuring instrument whether
the connecting wires are live. If so, remove the corresponding supply
fuses and keep them in a safe place until installation is completed, so
that they cannot be replaced by anyone unnoticed.
Connecting the phase connection lines
1. Shorten the phase connecting wires to the required length and then
strip them.
2. Insert the phase connecting wires in the relevant terminals (the
terminals are numbered as shown in the connection diagram) and
tighten the terminal screws firmly (torque 1.7 Nm).
It is recommended to identify the beginning and end of the relevant
conductors with a suitable test unit (e.g. buzzer) to ensure that the
right consumer is connected to the meter output.
Figure 56. Meter connections (example SMA400xT, terminal layout according to DIN)
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Artificial star point
With the three-wire circuit the artificial star point (terminal 11) must not be
externally wired.
Connecting the signal inputs and outputs
Maximum current at auxiliary terminals
The circuits connected to the auxiliary terminals must be built in such a way
that the maximum current is never exceeded, as this might damage the
meter.
Maximum current of the voltage outputs: 1 A.
Maximum current of the output contacts: 100 mA.
Use fuses or protective relays between external and internal circuits to
avoid defects and a possible exchange of the meter.
1. Shorten the connecting wires of the signal inputs and outputs to the
required length and strip them for approx. 4 mm (wires and strands up
to 2.5 mm² can be connected).
Use ferrules with stranded wires
If stranded wire is used, provide it with ferrules for connection.
2. Connect the connecting wires of the signal inputs and outputs as
follows to the screwless spring-loaded terminals (the terminals are
numbered as shown on the connection diagram):
– Insert a size 1 screwdriver in the upper opening and insert it turning
slightly upwards (figure 57 A).
– Now place the stripped connecting wire in the lower opening and
hold it there securely (figure 57 B).
– Withdraw the screwdriver. The connecting wire is then firmly fixed
(figure 57 C).
Figure 57. Connection in screwless spring-loaded terminals
Bare end of connecting wire must not be too long
The insulation of the connecting line must extend as far as the terminal
indentation, i.e. there must be no further bare part of the connecting line
visible above the terminal edge (as shown in figure 57 C). Touching live
parts is dangerous to life. The stripped part of the connecting wire should
be shortened if necessary.
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Only one wire or ferrule per terminal
Only one wire or ferrule with strand(s) may be connected in screwless
spring-loaded terminals. The terminal could otherwise be damaged or the
contact not properly made.
If a connecting wire must be disconnected again for any reason, this is
performed in the reverse sequence:
Figure 58. Releasing connection from spring-loaded terminal
Damage to terminals
Never withdraw connecting wires with the terminal closed, since this could
damage the terminal.
4.3.1 Connecting the RS485 interface
If you connect the RS485 interface you must not strip back the shielded
cables, e.g. to connect the individual wires to an external terminal block
(see figure below), as this considerably increases the likelihood of
interference.
Electrical cabinet Electrical cabinet
Removal of cable
shield for connection
to terminals can lead
to pickup of stray
fields.
Ext. terminal block Ext. terminal block
RS485 Bus
Electrical cabinet Electrical cabinet
RS485 Bus
Figure 59. How to connect RS485 correctly
It is also possible to use RS485 distributors instead of connecting the
RS485 cables directly to the meter.
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4.4 Check of connections
Effects of connection errors
Only a properly connected meter measures correctly!
Every connection error results in a financial loss for the power company!
Before putting into operation, check again whether all meter connections
are connected correctly according to the connection diagram.
4.5 Commissioning, functional check and sealing
Dangerous voltage on conductors
The supply fuses must be re-inserted or the jumpers of the voltage circuits
in the test terminal block re-closed before commissioning and functional
check of the meter.
If the terminal cover is not screwed tight, there is a danger of contact with
the connection terminals. Contact with live components is dangerous to life.
The relevant supply fuses should therefore be removed before making any
modifications to the installation and these kept in a safe place until
completing the work to prevent anyone re-inserting them unnoticed. The
jumpers in the test terminal block of the voltage circuits should again be
opened and secured.
Dangerous voltage on current transformers
The current transformer circuits must be closed before commissioning and
functional check of the meter. Opening the jumpers short-circuiting the
secondary sides of the transformers permit the transformer current to flow
through the meter. Opening of the short-circuit jumper must never interrupt
the circuit.
Prerequisites for commissioning and functional check
The functional check requires voltage to be applied and load applied to all
phases. If export is possible, determine first the energy direction present.
If no network voltage is present, commissioning and functional check must
be performed at a later date.
Via the test terminal blocks you can also supply the meter from suitable
auxiliary sources on the secondary side with the system switched off.
Repeat the functional check later with the system switched on.
The installed meter should be put into service and checked as follows:
1. Close the jumpers of the voltage paths in the test terminal block with
an insulated screwdriver and re-insert the supply fuses.
2. Check on the display whether all three phases L1, L2 and L3 are
indicated and show the right phase sequence.
– If one phase is not present or less than 20 V, then the relevant
symbol is absent.
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– With the normal phase sequence L1-L2-L3 the symbols are
displayed continuously.
– If, however, the meter is connected with reversed phase sequence
(e.g. L2-L1-L3) the symbols flash. The direction of field rotation
(clockwise or anticlockwise) is determined by the parameterisation.
This has no influence, however, on the measuring behaviour of the
meter.
Figure 60. Phase sequence indication
3. Open the short-circuit jumper of phase 1 in the test terminal block with
an insulated screwdriver.
4. Check the display of the energy direction: +P to right, +Q up with
inductive load.
5. Close the short-circuit jumper of phase 1 in the test terminal block
again with an insulated screwdriver.
6. Repeat the same test for the other phases as in points 3 to 5.
7. Then open the short-circuit jumpers of all phases in the test terminal
block with an insulated screwdriver.
Figure 61. Test terminal blocks status after commissioning (terminal layout
according to DIN)
8. Check whether the operating display appears correctly (no error
message).
9. Further values can be checked in the service list obtained via the
service menu if parameterised: phase voltages, angles, currents, etc.
10. Check the tariff displays and switch the control voltages to the tariff
inputs on and off. The arrow symbols of the tariff display must change.
11. If the meter is connected to a meter readout system via the electrical
interface, a check should be made of correct functioning of the data
transmission.
12. If a GSM modem is connected to the meter, the SMS transmission
function should be checked by sending a test SMS message, e.g. to
your own mobile telephone.
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13. Mount the terminal cover if the meter is operating correctly. Otherwise
first locate and eliminate the error.
14. Seal the terminal cover with two utility seals.
15. Set the current date and time with the relevant formatted command
(see section 5.8 "Input of formatted commands") or in the set mode
(see section 5.9 "Set time and date, ID numbers, battery time).
16. Close the front door.
17. Re-seal the front door.
4.6 Installation of terminal cover detection
1. Ensure that control input 1 has been parameterised for this function.
2. Connect cables 1 and 2 to terminal according to the figure below.
1
3 2
Figure 62. Connection of cables of cover detection unit
3. Fix terminal cover detection unit to meter. See figure below.
Figure 63. Fixing of cover detection unit to meter
4. Connect cable 3 as shown above.
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4.7 Uninstallation
Dangerous voltage on conductors
The connecting conductors must be free from voltage when the meter is
removed. It is dangerous to life to touch live parts. Remove the
corresponding supply fuses and ensure that they cannot be re-inserted by
anyone unnoticed before completing the work.
If the meter is connected via voltage transformers, it must be possible to
open the test terminal (e.g. TVS14). For this purpose release the screw of
the relevant jumper with an insulated screwdriver, push the jumper away
from the terminal and then re-tighten the screw.
If there is no test terminal block, the primary voltage must be interrupted,
i.e. the system switched off.
Dangerous voltage on current transformers
The secondary sides of the current transformer circuits must not be opened
if a current is flowing in the primary. This would produce an extremely high
voltage of several thousand volts dangerous to life at the terminals and the
insulation would be destroyed.
Short-circuit the current transformer at the test terminal block (e.g. TVS14)
to remove the meter. For this purpose release the screw of the relevant
short-circuit jumper with an insulated screwdriver, push the short-circuit
jumper over the terminals on the current transformer side and then
retighten the screw. The circuit on the meter side can then be opened
without danger.
If there is no test terminal block, the primary voltage must be interrupted,
i.e. the system switched off.
The meter should be removed as follows:
1. Short-circuit the current transformer with the short-circuit jumpers in
the test terminal block using an insulated screwdriver and interrupt the
voltage connections with the jumpers in the test terminal block.
2. Remove the two utility seals at the screws of the terminal cover.
3. Release the two screws of the terminal cover and remove it.
4. Check that the connecting wires are not live using a phase tester or
universal measuring instrument. If not, check the condition of the test
terminals again according to figure 64. Remove the relevant supply
fuses if necessary and ensure that they cannot be re-inserted by
anyone unnoticed before completing the installation.
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Figure 64. Condition of test terminal block before removing meter (terminal
layout according to DIN)
5. Remove the connecting wires of the signal inputs and outputs from the
screwless spring-loaded terminals as follows:
– Place a size 1 screwdriver in the upper opening and insert it turning
slightly upwards (figure 65 A).
– Then draw the wire from the lower opening (figure 65 B).
– Withdraw the screwdriver (figure 65 C).
Figure 65. Removing connections in screwless spring-loaded terminals
Damage to terminals
Never withdraw connecting wires from closed terminals. The terminals
could be damaged.
6. Release the terminal screws 1 to 11 of the phase connecting wires
with a suitable screwdriver and withdraw the phase connecting wires
from the terminals.
7. Fit a substitute meter as described in section 4.3 "Connecting the
meter" and the following sections.
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5 Operation
This section describes the appearance, layout and function of all operating
elements and displays of the SxA400xT meters as well as operating
sequences.
Illustrations
The illustrations of the faceplate and display in this section always show the
SxA400CT combi-meter (with additional optical test output for reactive
energy, together with direction of reactive power and quadrant display).
5.1 Operation with auxiliary power supply
Meters equipped with an auxiliary power supply which is supplied with
electricity (see section 3.4 "Connection diagrams (examples)") are
completely functional even in case of a power cut. Despite missing voltage
at the terminals they can be read out via display, remote readout, etc. and
parameterised, if desired.
Connect the auxiliary power supply as follows:
1 2 3 4
Figure 66. Auxiliary power supply connections
Type 045x: 1 and 2: 100–240 V AC/DC
Type 046x: 1: + (12–24 V DC)
Type 046x: 2: – (12–24 V DC)
Type 047x: 1: + (12–60 V DC)
Type 047x: 2: – (12–60 V DC)
Type 326x: 3: + (12–24 V DC)
Type 326x: 4: – (12–24 V DC)
5.2 Control elements
S650 meters have the two display buttons "down" and "up" and a reset
button as conventional operating elements. The display can also be
controlled with the aid of a light source via the optical interface.
5.2.1 Display buttons
The two display buttons "down" and "up" are placed on the main faceplate
(top) on the right of the liquid crystal display.
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Landis+Gyr S650
Readout
imp imp Cl. 1
Cl. 1 kvarh
1000 kWh
Three-phase four-wire meter
SMA410CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 5(10) A 50 Hz
20XX
Display key
"up"
Display key
"down"
T1 T2 T3 SET Test
Figure 67. Display buttons
By pressing the lower display button "down", the display changes to the
next value in the list. By pressing the upper display button "up", the display
changes to the previous value (also see section 5.4.2 "Display menu").
5.2.2 Control of display via optical interface
All S650 meters have an "optical button" in addition to the "up" and "down"
display buttons. The optical interface serves to receive a light signal, e.g.
generated by a torch (works only with warm light, i.e. LED torches cannot
be used for this). The light signal acts like the "down" display button and
controls the display in one direction from one value to the next. This type of
display control only functions when voltage is supplied to the meter.
The reader can also control the display at a distance from the meter
depending on the light intensity from the source, e.g. through a protective
glass in front of the meter.
5.2.3 Reset button
The reset button is situated to the right of the battery compartment behind
the front door. To permit operation of the reset button the front door must
be opened and therefore the utility seal be removed.
The reset button can be used to perform a manual reset. If the display
check is displayed (after operation of a display button), however, pressing
of the reset button produces the service menu (also see section 5.4.3
"Service menu").
Figure 68. Reset button behind front door
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5.3 Display
5.3.1 Introduction
S650 meters are provided with a liquid crystal display (LCD).
The display can be provided with background lighting for easier reading
(optional). This is switched on by pressing one of the display buttons and is
extinguished automatically after a short time if no further button is pressed.
5.3.2 Basic layout
The basic layout shows all the indication possibilities of the display.
Figure 69. Basic layout of the liquid crystal display (LCD)
1 Active power direction (+P: import, -P: export)
2 Reactive power direction (not used with SMA400AT)
3 Phase voltages (flash if rotating field reversed)
4 Battery status (charge voltage)
5 Units field
6 Index field (8 digits)
7 Value field (8 digits)
8 12 arrow symbols for status information (e.g. tariffs)
Active power direction Shows always the sum of the three phases:
positive active energy direction (imported from power
company)
negative active energy direction (exported to power
company)
negative active energy direction of individual phases
(second arrow flashes).
Reactive power Indicates for combi-meters SMA400CT always the sum of the three phases (not
direction used for active energy meters SMA400AT).
positive reactive energy direction
negative reactive energy direction
Quadrant display Indicates for combi-meters SMA400CT in which quadrants the present
measurement is made (not used for active energy meters SMA400AT):
1st quadrant
2nd quadrant
3rd quadrant
4th quadrant
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Phase voltages Indication of presence of phase voltages.
If the rotating field corresponds to the parameterised,
symbols L1, L2 and L3 are continuously lit. Otherwise
they flash every second.
Battery condition The symbol appears if the charge voltage of the battery
fitted is too low (provided the meter is parameterised as
"fitted with battery").
Units field The following units are shown:
W, var, VA, k..., M..., ...h, V, A, h, Hz, m³
(var and VA only for combi-meters)
Index field Up to 8-digit indices are displayed, which define
the value in the value field.
Value field Up to 8-digit values are displayed.
Arrow symbols An arrow symbol is an additional status indication for tariff
rates, reset block, test mode, etc. The arrow points to a
status description on the faceplate.
5.3.3 Index system
The information concerning which data are shown in the display is made
with an index system and is supported by the unit over the value field.
The 8-digit index field permits all currently known index systems, such as
DIN, LG, VEOe, OBIS, etc.
The B:C.D.E.F structure applies to OBIS (Object Identification System):
B Defines the channel number, i.e. the number of the input of a metering
device having several inputs for the measurement of energy of the
same or different types (e.g. in data concentrators, registration units).
This enables data from different sources to be identified.
C Defines the abstract or physical data items related to the information
source concerned, e.g. active power, reactive power, apparent power,
cosφ, current or voltage.
D Defines types, or the result of the processing of physical quantities
according to various specific algorithms. The algorithms can deliver
energy and demand quantities as well as other physical quantities.
E Defines the further processing of measurement results to tariff
registers, according to the tariff rates in use. For abstract data or for
measurement results for which tariffs are not relevant, this value group
can be used for further classification.
F Defines the storage of data according to different billing periods. Where
this is not relevant, this value group can be used for further classification.
To simplify reading of the index field, individual parts of the OBIS code can
be omitted. The abstract or physical data C and type of data D must be
shown.
For further details about OBIS code, see Appendix 1.
Examples 1.8.0: 1 = Active energy import (all phases); 8 = Status; 0 = Total
0.9.1: Local time
Reference is made for examples to the following display list and the
readout log (see section 5.7 "Data readout").
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5.4 Types of display
The SxA400xT has the following three types of display:
Operating display The values specified by the parameterisation are shown as a rolling display
in the operating display. The display is always in operating mode when the
display buttons are not operated. The meter returns automatically from the
display list to the operating display after a defined time. This display can
consist of one or more values.
Display menu By pressing the display button, the display check is activated, and from
there the user reaches the display menu by pressing the display button
again. From the display menu, values of the display list, the load profile(s),
the event log, etc. can be accessed. The values of the display list and also
the sequence can be parameterised. The display buttons permit scrolling
up and down in the list.
Service menu The user reaches the service menu by pressing the reset button starting
from the display check. From the service menu, values of the service list,
the set mode, etc. can be accessed. The service list, for example, is an
extended display list with additional values.
5.4.1 Operating display
The values always displayed are considered the operating display. This can
be parameterised as a fixed display (only one value present, e.g. the
present tariff rate) or as a rolling display (several values alternate at a fixed
rate, e.g. every 15 seconds).
running average demand
with status of integrating
period
Figure 70. Example of a fixed display
Error message The meter can generate an error message on the basis of self-tests.
According to parameterisation, this can be permanently included in the
operating display. In the event of a serious error (fatal or critical error), it
replaces the normal operating display. After a fatal error, the meter no
longer operates and must be replaced. In case of a critical error, the error
message can be acknowledged with the display button.
Figure 71. Example of an error message (insufficient battery voltage)
In case of an error message, the procedure described in section 6.2 "Data
readout" should be followed.
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5.4.2 Display menu
Figure 72. Display menu overview
Display check Brief operation (< 2s) of the display button "down" or "up" causes a change
of the operating display, e.g.:
to the display check:
All segments of the display are active here. The index and value fields
should be checked each time for missing segments. This can prevent
incorrect readings.
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Display menu Pressing the display button "down" or "up" again briefly, changes to the
display menu or directly to the display list. The first menu item appears, e.g.
"Display list" (standard data):
The menu item only appears when several menu items exist. Otherwise
direct entry is made to the display list.
The next menu item appears for every further brief operation of the "down"
display button, e.g. "Data profile", "Event log", etc. The first menu item
appears again after the last item.
The preceding menu item is displayed again by briefly pressing the "up"
display button.
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from any display menu.
Value display The first value of the list associated with the present menu is displayed by
pressing the display button "down" or "up" for longer (at least 2 seconds),
and is normally the error message:
The next list value appears for every further brief operation of the "down"
display button. Brief operation of the "up" button again displays the
preceding value. The sequence of values in the list is determined by the
parameterisation.
A rapid run is started by holding down the display button "down" or "up" for
longer (at least 2 seconds). The main values of the list are then displayed
while the button remains pressed, but no stored values.
Examples of values in a display list:
Reset counter
Date of resetting
stored value 03 (March)
Cumulated maximum
demand
active power
rate 1
Active energy
present status
rate 1
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Reactive energy
present status
rate 1
Battery hours counter
Status of signals at
control terminals
Number of total voltage
failures
To return to the menu level from the list at the end of the display list press
the display button "down" or "up" for longer (at least 2 seconds).
Load profile 1 The load profile 1 menu item for selection in the display menu (denoted
P.01) is shown as follows:
The first value of the load profile 1 is displayed by pressing the display
button "down" or "up" for longer (at least 2 seconds).
Load profile 2 The load profile 2 menu item for selection in the display menu (denoted
P.02) is shown as follows:
The first value of the load profile 2 is displayed by pressing the display
button "down" or "up" for longer (at least 2 seconds).
Event log The event log menu item for selection in the display menu (denoted P.98)
is shown as follows:
The first entry in the event log is displayed by pressing the display button
"down" or "up" for longer (at least 2 seconds).
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Losses The losses menu item for selection in the display menu is shown as
follows:
The first losses value is displayed by pressing the display button "down" or
"up" for longer (at least 2 seconds).
5.4.3 Service menu
Figure 73. Service menu overview
Service menu Pressing the reset button during the display check changes the display to
the service menu or directly to the service list. The first menu item appears,
e.g. the service list:
The menu item only appears if there are several items present. Otherwise
pressing the reset button directly leads to the values of the service list.
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The next menu item appears for every further brief operation of the "down"
display button, e.g. "Set mode", "Test mode on/off", etc. The first item
appears again following the last menu item "End".
The preceding menu item appears again by pressing the "up" button
briefly.
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from the service menu.
Value display The first value of the list associated with the present menu is displayed by
pressing the display button "down" or "up" for longer (at least 2 seconds).
The next list value appears for every further brief operation of the "down"
display button. Brief operation of the "up" button again displays the
preceding value. The sequence of values in the list is determined by the
parameterisation.
A rapid run is started by holding down the display button "down" or "up" (at
least 2 seconds). The main values of the list are then displayed while the
button remains pressed, but no stored values.
To return to the menu level from the list at the end of the display list press
the display button "down" or "up" for longer (at least 2 seconds).
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from the list.
Set mode Values can be changed in the set mode with the aid of the reset button and
display buttons (for setting time and date, identification numbers, battery
hours counter, etc.). The procedure is described in section 5.9 "Set time
and date, ID numbers, battery time".
5.5 Alert LED
The red alert LED (optional) on the main faceplate indicates that certain
event(s) have occurred. Which event(s) trigger the alert LED can be set by
parameterisation.
Landis+Gyr S650
Readout
imp imp
Alert LED Cl. 1
kvarh
1000
kWh
Cl. 1
Three-phase four-wire meter
SMA410CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 5(10) A 50 Hz
20XX
T1 T2 T3 SET Test
Figure 74. Alert LED
5.6 Optical test output
The optical test outputs – one for active energy in all meters and a second
for reactive energy in combi-meters – are fitted in the main faceplate above
the liquid crystal display.
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Optical
test output
Landis+Gyr S650
Readout reactive energy
Cl. 1
imp
kvarh
1000
imp
kWh
Cl. 1 (combimeters
Three-phase four-wire meter only)
SMA410CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 5(10) A 50 Hz
20XX
Optical
test output
active energy
T1 T2 T3 SET Test
Figure 75. Optical test outputs
The optical test outputs are used for testing the meter (also see section 7.1
"Meter testing"). They transmit visible red pulses corresponding to the
current measured values (active and reactive energy).
5.7 Data readout
The energy supply company can record the data stored locally in the meter
at any time in two ways:
Reading the liquid crystal display of the meter. The displayed data is
defined by parameterisation.
Automatic data readout via the optical interface with a readout device
(e.g. laptop).
Readout data
For readout to IEC 62056-21, all data determined by the parameterisation
are read out in the specified sequence.
For readout according to DLMS (Device Language Message Specification),
the data requested by the readout unit are read out.
If the meter is fitted with the appropriate communication unit (see
associated separate operating instruction), remote readout of the meter
data is also possible.
Procedure for data readout via optical interface
1. Start the readout device (according to the details in the associated
operating instructions).
2. Connect the cable of the reading head to the readout device.
3. Place the reading head in the "Readout" indentation on the plastic
viewing window of the meter. The reading head cable must point to-
wards the terminal cover (when mounted vertically downwards). The
reading head is held magnetically.
4. Start the data readout on the readout device (according to the details
in the associated operating instructions).
5. Remove the reading head from the meter again after completing the
readout.
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5.7.1 Readout to IEC 62056-21
The data read out according to IEC 62056-21 are recorded in the form of
the example shown below. The quantity and sequence of values in the log
is determined by parameterisation.
Log example Significance
/LGZ4\2SMA4104100 Designation of meter
(reply on transmit request)
F.F (00000000) Error message
0.0.1 (417242) 1st identification number
0.1.0 (28) Number of resets
0.1.2.04 (98-05-01 00:00) Time of last reset
1.2.1 (26068.7*kW) Pmax cumulated Rate 1
1.2.2 (15534.8*kW) Pmax cumulated Rate 2
1.6.1 (192.4*kW)(00-05-06 10:45) Pmax present Rate 1
1)
1.6.1*04 (202.4)(00-04-22 09:30) with April stored value Rate 1
1.6.2 (086.7*kW)(00-05-04 22:30) Pmax present Rate 2
1)
1.6.2*04 (100.9)(00-04-14 23:00) with April stored value Rate 2
1.8.1 (0244948*kWh) Active energy (import) Rate 1
1)
1.8.1*04 (0234520) with April stored value Rate 1
1.8.2 (0082520*kWh) Active energy (import) Rate 2
1)
1.8.2*04 (0078197) with April stored value Rate 2
5.8.1 (0106103*kvarh) Reactive energy (inductive) Rate 1
1)
5.8.1*04 (0100734) with April stored value Rate 1
5.8.2 (0039591*kvarh) Reactive energy (inductive) Rate 2
1)
5.8.2*04 (0036152) with April stored value Rate 2
1.8.0 (0327468*kWh) Total active energy
5.8.0 (0145694*kvarh) Total reactive energy (inductive)
8.8.0 (0001452*kvarh) Total reactive energy (capacitive)
0.9.1 (14:18:06) Time-of-day of readout
0.9.2 (00-05-20) Date of readout
C.7.0 (00087) No. of voltage failures of all phases
C.72.0 (00157) Number of under-voltages
C.73.0 (00000) Number of over-voltages
C.74.0 (00306) Number of over-loads (over-current)
C.3.0 (500) Active pulse constant
C.3.1 (500) Reactive pulse constant
C.2.1 (00-03-26) Date of last parameterisation
! End of log
1)
If the sequence is parameterised as month.
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Notes By parameterisation, the energy supply company can select between a
standard identification and its own identification. The standard identification
has the following structure:
/LGZ... Manufacturer (Landis+Gyr)
/LGZ 4... Transmission rate 4 = 4800 bps
/LGZ4 \2... Extended communication possibility
2 = DLMS-compatible meter
/LGZ4\2 SMA410... Meter Type of measuring unit
/LGZ4\2SMA410 41... Basic version tariff section
/LGZ4\2SMA41041 00... Additional functions
(auxiliary power supply)
/LGZ4\2SMA4104100 .B32 Firmware version
Stored values The hyphen following the identification
number and the rate (1.6.1) denotes the
type of resetting:
e.g. 1.6.1*04 *04 Resetting made internally or
remote controlled
e.g. 1.6.1&04 &04 Resetting performed manually
The identification by the energy supply company itself uses an identification
number. ID1.1 (designation of ownership by the energy supply company),
ID1.2 (any desired number) or ID2.1 (serial number) are available. The
identification is comprised as follows in this case:
/LGZ... Manufacturer (Landis+Gyr)
/LGZ 4... Transmission rate 4 = 4800 bps
/LGZ4 \2... Extended communication possibility
2 = DLMS-compatible meter
/LGZ4\2 \B32... Meter Firmware version
/LGZ4\2\B32 12345678 Identification number specified
by parameterisation (maximum 8
characters)
5.7.2 Readout to DLMS
While the readout according to IEC 62056-21 uses a predefined protocol,
readout to DLMS enables the power supply company to read out values
individually. The company therefore has systematic access to specific
values without being influenced by other values that are not required.
DLMS specification Various meter manufacturers – including Landis+Gyr – together with
related organisations, have compiled the language specification DLMS
(Device Language Message Specification).
Objective The objective of DLMS is to use a common language for data exchange in
energy measurement and other sectors. In addition to end units such as
meters, tariff units, etc. DLMS also defines the interfaces, transmission
channels and system software.
Principle DLMS delivery oriented protocol can be compared to sending a letter: the
sender writes the address of the recipient on the letter and hands it to the
post office for transport. The way in which the postal department transports
the letter is of no consequence to the sender and receiver. The only
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important thing is that the address of the recipient is clearly shown and that
the letter is received, read and it can be seen from whom the letter
originates.
Units with DLMS operate in a similar way. They provide the values –
termed objects – required by the receiver (e.g. control centre) and pass
them via interface to the transport medium (channel). How the values reach
the recipient is again immaterial for both parties.
DLMS items DLMS is an object-oriented language. The DLMS objects
Have an unique name in the form of the EDIS identification number
Contain the value in an exactly defined form and
Are configured in a similarly exactly defined format.
Examples are number of resets with date and time, cumulative maxima,
rolling mean values, maxima, energy status, associated stored values, etc.
The sender feeds these objects to a transport medium, e.g. the telephone
network. This transmits them to the receiver, so that the objects are
received in the same form as supplied by the sender.
5.8 Input of formatted commands
The following operating data or meter characteristics can be modified by
the input of formatted commands. The user of formatted commands,
however, must have the necessary access authorisation according to the
security system.
The following commands can be used both according to IEC 62056-21 and
also with DLMS:
Set time/date
Set identification numbers for the energy supply company and for the
manufacturer (by line).
Reset
Neutralise reset inputs KA/KB
Set/reset counter
Control tariff rates via interface
Set/reset energy registers
Set/reset total energy registers
Set/reset demand maximum registers
Set/reset power factor registers
Reset stored values
Reset battery hours counter
Reset voltage failures registers
Switch on/off increased resolution (test mode)
Define by additional parameters whether the optical test output for
active energy in test mode supplies active or reactive energy pulses
Delete error messages
Change passwords P1,P2 and W5
Reset load profile 1 / load profile 2
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Reset event log
Reset dedicated event log groups
The following commands can only be executed with DLMS:
Reset event register
– Under- and overvoltages
– Demand messages
– Current messages
– Power factor messages
Set thresholds for messages
Formatted commands are transferred to the meter with a suitable device
via the optical interface or via an interface circuit of the communication unit.
5.9 Set time and date, ID numbers, battery time
The following values can be changed at any time from the service menu
(set mode):
Date and time
Identification numbers
Operating time of battery
Below is an example on how to set the date and time.
Operating
display
1. All segments of the Display check
display are lit
2. Enter service menu Set mode
R
3. Enter set mode Identification
number
4. Select required Date, old
setting value
5. Select digit to be Digit flashes
R changed
6. Change digit value Digit flashes
7. Select digit to be Next digit
R changed flashes
8. Repeat steps 5 – 7 for all digits to be changed. All digits flash
9. Confirm new Date, new
R setting value
10. Repeat steps 4 – 9 for all settings to be changed.
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11. Advance display End of set
until End mode
12. Back to service Service menu
menu
13. Advance display End of service
until End menu
14. Back to operating Operating
display display
15. Close and re-seal the front door.
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6 Service
This section describes the necessary servicing work after the appearance
of operating faults or error messages.
6.1 Operating faults
If the liquid crystal display is illegible or the data readout does not function,
the following points should first be checked:
1. Is the network voltage present (supply fuses intact and test terminals
closed)?
2. Is the maximum permissible ambient temperature exceeded?
3. Is the plastic viewing window over the faceplate clean (not scratched,
painted over, misted over or soiled in any way)?
Danger of short-circuits
Never clean soiled meters under running water or with high pressure
devices. Water penetration can cause short-circuits. If the meter is heavily
soiled, it should be uninstalled, if necessary and sent to an authorised
service centre, so that a new plastic viewing window can be fitted.
If none of the points listed is the cause of the fault, the meter should be
disconnected, removed and sent to the responsible service and repair
centre (according to section 6.3 "Repairing meters").
6.2 Error messages
The meters regularly perform an internal self-test. This checks the correct
function of all important parts.
In case of a serious error detected (fatal or critical error according to
classification in the following degrees of severity), the meters displays an
error code. This error code appears as an eight-digit number together with
"F.F" or "FF" in the display (error code F.F 00000000 = no error).
Classification of The degree of severity of an error occurring is assessed as follows:
degree of severity
A fatal error indicates a severe problem, which prevents the meter
maintaining measuring operation, e.g. a defective hardware component.
The meter stops its operation and the error code is displayed permanently.
The meter must be exchanged.
A critical error indicates a severe problem, but with which the meter
continues to function and measurement is still possible. The data are stored
in the memory and suitably marked in case of doubt. After a critical error,
the error code is displayed until acknowledged with the display button or
until the error register is reset, e.g. via the electrical interface. Depending
on the type of the error this can cyclically occur again, since with the
acknowledgement the error cause is usually not repaired. The meter must
in this case be exchanged as soon as possible.
Non-critical errors can influence the meter functions (temporarily or
permanently). These errors are recorded in the error register. The meter
remains serviceable and normally needs not to be exchanged.
Deleting error If nothing else is specified in the following description of the error groups,
messages the error messages can only be deleted with formatted commands (see
section 5.8 "Input of formatted commands"). If the error occurs again, the
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meter should be removed and sent to the responsible service and repair
centre (according to section 6.3 "Repairing meters").
6.2.1 Structure of an error message
An error message has the following form:
Figure 76. Error message on S650 meters
All S650 meters use the same format for error messages. It consists of four
groups of 2 digits each, whereby the groups have the following significance:
Figure 77. Significance of error message
Each group has two digits written in hexadecimal notation and can
therefore have the values 0 to 9 and letters A to F. Both digits each form
the sum of the individual values of 4 possible types of error as shown in the
following diagrams.
6.2.2 Error groups
Time-base errors
(clock) Group 1 of error messages
of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Low battery
Invalid clock
*
*
* * not used
*
*
*
Figure 78. Group 1 of error messages
The first digit in the first group has no significance, since no error messages
are assigned to it.
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The second digit can have values between 0 (no error message) and 3
(both error messages set). Significance:
F.F 01 00 00 00 Low battery (non-critical error)
The battery is missing or discharged. If there is no mains voltage at the
meter and the internal supercapacitor is discharged (after about 3 weeks)
then the calendar clock will stop.
The error is deleted automatically when the battery voltage has again
reached a sufficient value (e.g. after inserting a new battery as described in
section 7.2 "Changing the battery").
This error message only appears if the meter is parameterised as "fitted
with battery". Otherwise there is no check of the battery condition.
The same applies to messages where the bit is set:
F.F 03 .. .. ..
F.F 02 00 00 00 Invalid clock (non-critical error)
The meter has found that the calendar clock has stopped at some time,
e.g. due to insufficient power reserve (battery low). The clock is running,
but shows the wrong time and/or date.
The error is deleted automatically when the time and date have been set
correctly by the relevant formatted command or manually in the set mode
(see section 5.8 "Input of formatted commands"). or section 5.9 "Set time
and date, ID numbers, battery time"). If necessary, replace the battery.
The same applies to messages where the bit is set:
F.F 03 .. .. ..
Errors for write/read
access Group 2 of error message
of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Main memory access error
Backup memory access error
Measuring system access error
Time device access error
Load profile memory access error
not used
Communication unit access error
not used
Figure 79. Group 2 of error messages
In the second group both digits can have values between 0 (no error
message) and F (all four error messages set). Significance:
F.F 00 x1 00 00 Main memory access error (fatal error)
This error message appears if the main memory could not be accessed
several times during the start-up of the meter.
The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. x3/x5/x7/x9/xB/xD/xF .. ..
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F.F 00 x2 00 00 Backup memory access error (non-critical error)
This error message appears if the backup memory could not be accessed
several times.
The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. x3/x6/x7/xA/xB/xE/xF .. ..
F.F 00 x4 00 00 Measuring system access error (non-critical error)
This error message appears in case of repeated failures when accessing
the measuring system, possibly because of a completely discharged
supercapacitor, which causes an incorrect start-up behaviour.
Power-up meter and wait for a short time, then clear error via
communication. If the error does not reoccur, it is recommended to equip
the meter with a battery. If the error reoccurs, replace the meter.
The same applies to messages where the bit is set:
F.F .. x5/x6/x7/xC/xD/xE/xF .. ..
F.F 00 x8 00 00 Time device access error (non-critical error)
The meter sets this message in the event of repeated failures when
accessing the time device. The calendar clock may display an invalid time
or date.
The error can be reset via communication. If it occurs repeatedly, the
meter must be exchanged.
The same applies to messages where the bit is set:
F.F .. x9/xA/xB/xC/xD/xE/xF .. ..
F.F 00 1x 00 00 Load profile memory access error (critical error)
This error message appears in case of repeated failures when accessing
the load profile memory.
Load profile data will be marked in the status code (bit 2 "corrupted
measurement" and bit 0 "critical error" set).
It may not be possible to access the load profile memory. The memory may
contain incorrect data. The meter must be exchanged.
The same applies to messages where the bit is set: F.F .. 5x .. ..
F.F 00 4x 00 00 Communication unit access error (non-critical error)
The meter sets this message in the event of repeated failures to access the
communication unit. Communication fails or is slow.
The error can be reset via communication. If it reoccurs, replace first the
communication unit, check the function again. If the error still occurs, the
meter must be exchanged.
The same applies to messages where the bit is set: F.F .. 5x .. ..
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Checksum errors
Group 3 of error messages
of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Program checksum error
Backup data checksum error
Parameter checksum error
Load profile 1 checksum error
Stored values checksum error
Event log checksum error
Calibration data checksum error
Load profile 2 checksum error
Figure 80. Group 3 of error messages
The first digit in the third group can have the value 0 (no error message) or
1 (error message set).
The second digit can have values between 0 (no error message) and F
(all four error messages set). Significance:
F.F 00 00 x1 00 Program checksum error (fatal error)
The meter does not operate and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x3/x5/x7/x9/xB/xD/xF ..
F.F 00 00 x2 00 Backup data checksum error (critical error)
This error message appears when the backup data checksum test fails.
Load profile data will be marked in the status code (bit 2 "corrupted
measurement" and bit 0 "critical error" set). The meter may contain
incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x3/x6/x7/xA/xB/xE/xF ..
F.F 00 00 x4 00 Parameter checksum error (critical error)
This error message appears when the parameter checksum test fails.
Load profile data will be marked in the status code (""bit 0 "critical error"
set). The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x5/x6/x7/xC/xD/xE/xF ..
F.F 00 00 x8 00 Load profile 1 checksum error (non-critical error)
Load profile 1 data of the defective memory area will be marked in the
status code (bit 2 "corrupted measurement" set).
The error can be reset via communication. Reset the load profile first
and then the error. If it occurs repeatedly, the meter must be replaced as
soon as possible.
The same applies to messages where the bit is set:
F.F .. .. x9/xA/xB/xC/xD/xE/xF ..
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F.F 00 00 1x 00 Stored values checksum error (critical error)
Data in the defective memory area will be marked in the status code (bit 0
"critical error" set).
The error can be reset via communication. If it occurs repeatedly, the
meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 3x/5x/7x/9x/Bx/Dx/Fx ..
F.F 00 00 2x 00 Event log checksum error (non-critical error)
Data in the defective memory area will be marked in the status code (bit 0
set).
The error can be reset via communication. If it occurs repeatedly, the
meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 3x/6x/7x/Ax/Bx/Ex/Fx ..
F.F 00 00 4x 00 Calibration data checksum error (critical error)
Data in the defective memory area will be marked in the status code (bit 0
"critical error" set).
The meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 5x/6x/7x/Cx/Dx/Ex/Fx ..
F.F 00 00 8x 00 Load profile 2 checksum error (non-critical error)
Load profile 2 data of the defective memory area will be marked in the
status code.
The error can be reset via communication. Reset the load profile first
and then the error. If it occurs repeatedly, the meter must be replaced as
soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 9x/Ax/Bx/Cx/Dx/Ex/Fx ..
Other errors
Group 4 of error messages
of E650 meters
Sum of values
Value in hexadecimal code
Invalid power down
*
* * not used
*
Expired watchdog
Communication locked
Wrong EEPROM/Flash identifier
Wrong extension board
Figure 81. Group 4 of error messages
The first digit in the fourth group can have the values 0 to F.
The second digit can have values between 0 (no error message) and 1
(Invalid power down). Significance:
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F.F 00 00 00 x1 Invalid power down (non-critical error)
The meter has detected that the last data storage was not performed
correctly. The meter may contain incorrect data or may have lost data since
the last storage, i.e. for 24 hours maximum.
The error can be reset via communication. If it occurs repeatedly,
contact Landis+Gyr Customer Services.
F.F 00 00 00 1x Expired watchdog (non-critical error)
The microprocessor was restarted due to a disturbance (e.g. lightning). The
meter may lose all data recorded since the last storage, i.e. for 24 hours
maximum.
The error can be reset via communication. If it occurs repeatedly,
contact Landis+Gyr Customer Services.
The same applies to messages where the bit is set:
F.F .. .. .. 3x/5x/7x/9x/Bx/Dx/Fx
F.F 00 00 00 2x Communication locked (non-critical error)
This error indicates access attempts via the communication interface with
wrong passwords.
The error is automatically deleted after the inhibition time or at midnight.
The same applies to messages where the bit is set:
F.F .. .. .. 3x/6x/7x/Ax/Bx/Ex/Fx
F.F 00 00 00 4x Wrong EEPROM/Flash (fatal error)
Incorrect EEPROM/ Flash memory is installed in meter.
The meter does not operate and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. .. 5x/6x/7x/Cx/Dx/Ex/Fx
F.F 00 00 00 8x Wrong extension board (non-critical error)
Identification of extension board differs from that parameterised in the
meter.
The meter might not have the required functions such as data profile,
control inputs or output signals. The meter has to be exchanged.
The same applies to messages where the bit is set:
F.F .. .. .. 9x/Ax/Bx/Cx/Dx/Ex/Fx
6.3 Repairing meters
Meters must only be repaired by an authorised service and repair centre
(or manufacturer).
The following procedure should be adopted if a meter repair is necessary:
1. If the meter is installed, remove the meter as described in section 4.7
"Uninstallation" and fit a substitute meter.
2. Describe the error found as exactly as possible and state the name
and telephone number of the person responsible in case of inquiries.
3. Pack the meter to ensure it can suffer no further damage during
transport. Preferably use the original packing if available. Do not
enclose any loose components.
4. Send the meter to the responsible service and repair centre.
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7 Maintenance
This section describes the necessary maintenance work.
7.1 Meter testing
Meter tests should be performed at periodic intervals according to the valid
national regulations (either on all meters or on specific random samples). In
principle, the meters should be uninstalled for this purpose according to the
instructions in section 4.7 "Uninstallation" and replaced by a substitute
meter. The meter test can also be performed on the spot in certain
circumstances.
7.1.1 Test mode
The test mode permits increasing the resolution of the energy registers by 1
to 5 digits. This allows the energy supply company to carry out the so called
measuring unit test in a reasonably short time.
In test mode, the same registers shown as a rolling list in the operating
display are always displayed, but with high resolution and not rolling.
The energy registers comprise a total of 12 digits. A maximum of 8 digits,
however, is shown on the display. The effective number of digits shown and
the number of decimal places are determined by the parameterisation. For
the test mode more decimal places are normally parameterised (maximum
5) to permit a quicker test of the transmission to the energy registers.
Figure 82. Display changeover normal mode – test mode
Changeover from normal to test mode and back is made by formatted
commands (see section 5.8 "Input of formatted commands") or manually in
the service menu.
In test mode, the optical test output for active energy can also provide
reactive energy pulses depending on the parameterisation. Reactive
energy pulses are supplied to this test output if the register shown on the
display represents a reactive energy register. Active energy pulses are
supplied for all other measured values shown as in normal operating mode.
Formatted commands can also be used to define whether the optical test
output for active energy in test mode should supply active or reactive
energy pulses, independent of the type of register shown on the display.
This permits changeover without manual intervention.
7.1.2 Measuring times
For technical reasons, greater measuring deviations can occur during
short-term measurements. It is therefore recommended to use sufficiently
long measuring times in order to achieve the required accuracy.
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Table of measuring times required at the optical test output:
SMA400xT Measuring uncertainty Measuring uncertainty
SFA400xT 0.1% 0.05%
Un = 58 to 230 V Current 3P 1P 3P 3P 1P 3P
In = 1 A, 5 A % In cos=1 1 0.5 cos=1 1 0.5
1 40 s 40 s 90 s 80 s 80 s 160 s
2 20 s 20 s 40 s 40 s 40 s 80 s
5 10 s 10 s 15 s 16 s 16 s 32 s
10 8s 8s 10 s 14 s 14 s 18 s
20 6s 6s 8s 12 s 12 s 14 s
50 6s 6s 6s 12 s 12 s 12 s
100 6s 6s 6s 12 s 12 s 12 s
200 6s 6s 6s 12 s 12 s 12 s
3 P = universal
1 P = single-phase
7.1.3 Optical test output
The red optical test outputs on the meter above the LCD should be used for
meter testing. These supply pulses at a frequency dependent on the meter
constant R, whereby the rising edge is always decisive for the test.
Note that the digital signal processing provides a delay of 2 seconds
between the instantaneous power at the meter and the appearance of the
pulses at the optical test outputs. No pulses are lost.
The number of pulses per second for the desired power is obtained by
multiplying the meter constant R by the power in kW divided by 3600.
Example: Meter constant R = 1000
Power P = 35 kW
f-test output = R x P / 3600 = 1000 x 35 / 3600 = 10 imp/s
Test mode Depending on the parameter setting of the behaviour of the pulse LED, the
test mode enables you to select which measuring value (active, reactive, I²,
U²) is shown on the optical test output.
In the display, values for active, reactive and apparent energy are available.
Depending on parameter setting, the resolution of the display register can
be increased for faster testing. In the test mode, the resolution is increased
by one decimal point compared with the normal mode. A maximum of 5
decimal points is possible.
Operating
display
1. All segments of the Display check
display are lit
2. Enter service menu Set mode
R
3. Select test mode Test mode
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4. Enter test mode First value
5. Select required Value x
value
6. Repeat step 3 for all values to be tested
7. Exit test mode Operating
display
Examples
First value and value x are examples. The real values are defined in the
parameter settings and are the same as the operating display.
The measured values are displayed at the optical test outputs as shown in
the following table:
Test output Test output
Mode Register on display
reactive active
Normal mode Any register |R| |A|
2
Losses Ih U2h
Test mode Active energy A |R| |A|
Reactive energy R |A| |R|
2
Losses (NLA) Ih U2h
Losses (OLA) U2h I2h
Any other registers not |R| |A|
mentioned
7.1.4 No-load test
A test voltage Up of 1.15 Un is used for the no-load test (creep test) to IEC
62053-21 (e.g. Up = 265 V with Un = 230 V).
Procedure:
1. Disconnect the meter from the network for at least 10 seconds.
2. Then switch on the test voltage Up and wait approx. 10 seconds. After
this time the energy direction arrows must disappear. The red optical
test outputs are permanently "lit".
3. Switch on test mode (high resolution).
4. The meter must not deliver more than one pulse during the no-load
test. Check the energy levels for changes in test mode. They must not
increase by more than the value of one pulse (see faceplate).
7.1.5 Starting test active part
Procedure:
1. Apply a load current of 0.02% of the nominal current In (IEC-meters) or
0.02% of the reference current Iref (MID-meters) – e.g. 1 mA with In=
Iref= 5 A – and the voltage Un (three-phase in each case) and cosφ =
1. The meter must remain in no-load.
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2. For SxA410: Increase the load current to 0.2% In (IEC-meters) or
0.2% Iref (MID-meters) – e.g. 10 mA with In=Iref= 5 A.
For SxA405, SxA402: Increase load current to 0.1% In (=0.1 Iref). The
energy direction arrow "P" must appear within 10 seconds. The optical
test output for active energy consumption is no longer permanently "lit".
7.1.6 Starting test reactive part
Procedure:
1. Apply a load current of 0.02% of the nominal current In (e.g. 1 mA with
In = 5 A) and the voltage Un (three-phase in each case) and sinφ = 1.
The meter must remain in no-load.
2. Increase the load current to 0.2% In (i.e. 10 mA with In = 5 A).
The energy direction arrow "Q" must appear within 10 seconds. The
optical test output for reactive energy consumption is no longer
permanently "lit".
7.2 Changing the battery
If the meter is provided with a battery, this must be changed if one of the
following events occurs:
The symbol appears on the display.
The battery has been in the meter for more than 10 years (preventive
servicing). It is recommended to note the date of insertion on the
battery. The 10 years depend on the product and on the age of the
battery when inserting it into the meter.
The battery operating hours counter indicates over 80,000 hours (can
be read under code C.6.0 in service mode).
The battery charge indicates less than 4.8 V (can be read under code
C.6.1 in service mode).
Meters with or without battery
Only meters parameterised as "fitted with battery" have the
and the battery operating hours counter.
symbol
Dangerous voltage on contacts in the battery compartment
The contacts in the battery compartment may have mains voltage applied
(F circuit). Therefore only remove the battery with the existing battery
holder and insert the new battery only with the battery holder. Ensure that
the contacts are never touched.
Replacement battery
As a replacement, use only a lithium battery with a rated voltage of 6 V and
the same construction as the original battery.
Procedure:
1. Remove the front door seal.
2. Open the front door.
The battery compartment is on the left below the liquid crystal display.
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Figure 83. Battery compartment
3. Press on the latch of the plastic battery holder until it releases and then
withdraw the battery holder with the old battery.
Figure 84. Removing the battery
4. Mark the current date on the new battery.
5. Withdraw the old battery from the holder and insert the new battery.
6. Push the battery holder with battery into the battery compartment until
the latch engages.
7. Reset the battery hours counter to zero with the relevant formatted
command (see section 5.8 "Input of formatted commands") or in the
set mode (see section 5.9 "Set time and date, ID numbers, battery
time").
8. Close the front door.
9. Re-seal the front door.
10. Dispose of old batteries as hazardous waste in accordance with local
regulations.
Checking time-of-day and date
After inserting the battery, check the time-of-day and date without power
applied and set these values again, if necessary.
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8 Disposal
Electronic waste treatment
This product must not be disposed of in regular waste. Use a professional
electronic waste treatment process.
The components used to manufacture the device can, in the main, be
broken down into constituent parts and sent to an appropriate recycling or
disposal facility. When the product is removed from use, the whole product
must be sent to a professional electronic waste treatment process. The
waste treatment and disposal plants must be approved by local regulatory
authorities.
The end processing of the product and recycling of its components must
always be carried out in accordance with the rules and regulations of the
country where the end processing and recycling are done.
On request, Landis+Gyr will provide more information about the
environmental impact of the product.
Disposal and environmental protection regulations
The following are general guidelines and should NOT take priority over
local disposal and environmental policies which should be adhered to
without compromise.
Components Disposal
Printed circuit boards, Delivered to recycling plants
LEDs, LCD display
Metal components Sorted and delivered to metal recycling plants
Plastic components Sorted and delivered to re-granulation if at all
possible
Batteries Removed from meter and delivered to
specialised recycling plants
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9 Index
.MAP110 ....................................................... 32 Connections .................................................. 38
Accuracy class 0.2S...................................... 12 Contact voltages ........................................... 47
Active component ......................................... 16 Control elements ........................................... 60
Active energy ................................................ 20 Control inputs ................................................ 12
Active power ........................................... 16, 20 Control of display via optical interface ........... 61
Active power calculation ............................... 16 Creep test...................................................... 85
Active power direction ................................... 62 Critical error................................................... 76
Additional control inputs ................................ 15 CS ................................................................. 15
Additional output contacts ............................. 15 Current transformer ....................................... 46
Alert LED....................................................... 69 Data preparation for billing ............................ 14
Anti-tampering features ................................. 32 Data readout ................................................. 70
Apparent energy ........................................... 21 Date and time
Apparent energy calculation ......................... 21 Set ...................................................... 74, 84
Aron circuit .............................................. 16, 47 DC magnet detection .................................... 33
Arrow symbols .............................................. 63 Decommissioning .......................................... 88
Arrows for status indication ........................... 37 Dedicated event log ...................................... 27
Automatic data readout ................................. 70 Device description ........................................... 8
Auxiliary power supply .................................. 14 Device Language Message Specification ..... 70
Background lighting ...................................... 62 Digital intermediate values ............................ 16
Backup data checksum error ........................ 80 Direction of rotating field ............................... 24
Backup memory access error ....................... 79 Display .................................................... 37, 62
Basic layout of LCD ...................................... 62 Display buttons.................................. 34, 37, 60
Battery charge status .................................... 86 Display changeover normal mode – test mode
Battery compartment ............................... 35, 87 ................................................................. 83
Battery condition ........................................... 63 Display check ................................................ 65
Battery exchange .......................................... 86 Display list examples..................................... 66
Battery operating hours counter.................... 86 Display menu .......................................... 65, 66
Billing data .................................................... 14 Disposal ........................................................ 88
Block schematic diagram .............................. 12 Disposal regulations ...................................... 88
Buttons .......................................................... 13 DLMS items................................................... 73
Calculation of apparent energy ..................... 21 DLMS specification ....................................... 72
Calibration data checksum error ................... 81 Electronic waste treatment ............................ 88
Calibration stage ........................................... 16 Energy components ...................................... 20
Changing values in set mode ........................ 74 Energy magnitude ......................................... 20
Characteristics of meters ................................ 9 Entering formatted commands ...................... 30
Check of connections.................................... 55 Environmental protection regulations ............ 88
Checksum errors........................................... 80 Error code ..................................................... 76
Combi-meters ................................................. 8 Error message............................................... 64
Commissioning ............................................. 55 Error message structure................................ 77
Communication ............................................. 30 Error messages ............................................. 76
Communication locked.................................. 82 Error severity ................................................. 76
Communication unit .......................... 15, 35, 74 Errors for write/read access .......................... 78
Communication unit access error ................. 79 Event log ................................................. 26, 67
Communication unit dummy ......................... 35 Expired watchdog.......................................... 82
Communication units .................................... 30 Extended suspension hook ........................... 49
Condition of test terminal block before Extension board ............................................ 14
removing meter ........................................ 59 Extension boards .............................. 42, 43, 44
Connecting the meter .............................. 51, 52 Faceplate ...................................................... 37
Connecting the phase connection lines ........ 52 Fatal error...................................................... 76
Connection check ......................................... 55 Field of application .......................................... 8
Connection diagrams (examples) ................. 40 Firmware version........................................... 11
Connection diagrams extension board ......... 42 Fixed display ................................................. 64
Connection of cables of cover detection unit 57 Fixing of cover detection unit to meter .......... 57
Connection of RS485 interface ..................... 54 Form of fixing ................................................ 49
Connection to low voltage ............................. 46 Formation of measured quantities................. 20
Connection to medium and high voltage . 47, 48 formatted commands .................................... 30
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Formatted commands ..............................73, 83 Meter constant .............................................. 84
Four-quadrant measurement .........................21 Meter mounting ............................................. 49
Front door sealing with padlock .....................36 Meter testing ........................................... 70, 83
Functional check ............................................55 Modem .......................................................... 15
Grounding ......................................................47 Mounting the meter ....................................... 49
Harmonics .....................................................16 Natural error compensation .......................... 16
High voltage ...............................................8, 48 Neutral current .............................................. 23
High voltage range ........................................47 No-load test .................................................. 85
Identification numbers ...................................74 Non-critical errors ......................................... 76
IEC 62056-21 ..........................................70, 73 Normal mode ................................................ 83
Index field ......................................................63 Numbering of quadrants ............................... 21
Index system ...........................................63, 92 OBIS ....................................................... 63, 92
Information for connecting the meter .............46 Objective for DLMS....................................... 72
Input of formatted commands ........................73 Operating data modifications ........................ 73
Input signals ..................................................15 Operating display .......................................... 64
Inputs .............................................................12 Operating faults ............................................ 76
Installation .....................................................46 Optical button................................................ 61
Intermediate values .......................................16 Optical interface .......................... 30, 34, 37, 74
Internal current transformers .........................16 Optical test output ....................... 34, 37, 69, 84
Invalid clock ...................................................78 Output contact data ...................................... 38
Invalid power down ........................................82 Outputs ......................................................... 13
Keys ...............................................................13 Ownership designation ................................. 38
Laptop............................................................70 Packing meter ............................................... 82
LCD .........................................................37, 62 Parameter checksum error ........................... 80
Liquid crystal display ...............................37, 62 Phase angles ................................................ 23
Lithium battery ...............................................86 Phase connections ................................. 12, 39
Load profile 1 .................................................26 Phase current ............................................... 23
Load profile 2 (option) ....................................26 Phase voltage ............................................... 22
Load profile 2 checksum error .......................81 Phase voltages ............................................. 63
Load profile checksum error ..........................80 Power factor.................................................. 22
Load profile memory access error .................79 Power supply ................................................ 14
Log example ..................................................71 Preliminary fuses .......................................... 46
Losses .....................................................24, 68 Preliminary work ........................................... 51
Low battery ....................................................78 Profile 2......................................................... 26
Low voltage .....................................................8 Program checksum error .............................. 80
Lower part of case .........................................34 Pulse input data ............................................ 38
Magnet detection ...........................................33 Pulse inputs .................................................. 13
Main faceplate ...............................................37 Purpose of this manual ................................... 5
Main memory access error ............................78 Quadrant display........................................... 62
Mains frequency ......................................17, 23 Quadrants ..................................................... 20
Maintenance ..................................................83 Rapid run ...................................................... 66
Manufacturer seal ..........................................34 Reactive component ..................................... 17
MAP120 .........................................................32 Reactive energy ............................................ 20
Mean value formation ....................................18 Reactive power ............................................. 17
Measured quantities ..........................13, 18, 38 Reactive power calculation ........................... 17
Measuring deviations .....................................83 Reactive power direction .............................. 62
Measuring device ..........................................47 Reading head ............................................... 70
Measuring system ...................................13, 15 Readout device ............................................. 70
Measuring system access error .....................79 Readout factor .............................................. 38
Measuring times for meter tests ....................83 Readout log .................................................. 71
Measuring uncertainty ...................................84 Readout to DLMS ......................................... 72
Medium voltage ...............................................8 Readout to IEC 62056-21 ............................. 71
Medium voltage range ...................................47 Readout via optical interface ........................ 70
Memory ..........................................................14 Recording counting pulses of other media ..... 8
Meter board ...................................................49 Reference documents..................................... 5
Meter case .....................................................34 Remote reading ............................................ 15
Meter characteristics .......................................9 Repairing meters .......................................... 82
Meter characteristics modification .................73 Replacement battery..................................... 86
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Reset button............................................ 35, 61 Tariff faceplate .............................................. 38
Rolling display ............................................... 64 Terminal cover .............................................. 34
Rotating field ................................................. 17 Terminal cover detection ............................... 33
RS232 ........................................................... 15 Terminal layout.............................................. 39
RS485 ........................................................... 15 Test mode ......................................... 83, 84, 85
Safety Test terminal block ........................................ 46
Information ................................................. 6 Test terminal block status before installation 52
Regulations ................................................ 7 Test terminal blocks status after
Responsibilities .......................................... 6 commissioning .......................................... 56
Seal component ............................................ 36 Test voltage................................................... 85
Sealing .................................................... 34, 55 Time device access error .............................. 79
Secondary circuit .......................................... 46 Time measurement ....................................... 17
Self-tests ................................................. 64, 76 Time-base errors ........................................... 77
Series designation ........................................ 11 Total active energy ........................................ 20
Service .......................................................... 76 Total apparent energy ................................... 21
Service and repair centre .............................. 82 Total harmonic distortions ............................. 24
Service menu ................................................ 68 Total reactive energy..................................... 20
Set date and time .......................................... 74 Transformer connection .................................. 8
Set identification numbers............................. 74 Transformer data........................................... 38
Set mode................................................. 69, 74 Transmission contact meters .......................... 8
Set operating time of battery ......................... 74 Transmission contacts .................................... 8
Severity of errors........................................... 76 Type designation ........................................... 11
SFA400AT/CT................................................. 8 Type of measurement SFA400xT ................. 16
Signal conversion and processing ................ 16 Type of measurement SMA400xT ................ 15
Signal processing.......................................... 13 Types of display ............................................ 64
Signal processor ..................................... 16, 18 Types of error ................................................ 77
Signal utilisation ............................................ 13 Uninstallation................................................. 58
SMA400AT/CT ................................................ 8 Units field ...................................................... 63
Spring-loaded terminals ................................ 39 Upper part of case......................................... 34
Starting test ................................................... 85 Utility seal ...................................................... 34
Status indication arrows ................................ 37 Value display ................................................. 66
Stored value profile ....................................... 26 Value field ..................................................... 63
Stored values checksum error ...................... 81 Verification seal ............................................. 34
Structure of error message ........................... 77 Versions of communication units .................. 31
Substitute meter ................................ 59, 82, 83 Voltage circuit ................................................ 46
Summation channels .................................... 25 Voltage divider .............................................. 16
Suspension triangle ...................................... 50 Voltage transformer....................................... 47
Symmetrical terminal layout .......................... 40 Wrong EEPROM/Flash ................................. 82
Target group of this manual ............................ 5 Wrong extension board ................................. 82
Tariff control .................................................. 14 Zero passage .......................................... 17, 23
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92/94 Appendix 1 OBIS code
Appendix 1 OBIS code
Object Identification System
The OBIS code (Object Identification System) is structured as follows:
A B C D E F Value group
M- KK: GG. AA. T W According to VDEW
A: Medium Defines the medium used. If only one medium is used it does not have to
[1 … 9] be specified. The Values represent the following objects:
1 Electricity
2, 3 Not used
4 Heating costs
5 Cooling system
6 Heating system
7 Gas
8 Cold water
9 Hot water
B: Channel Defines the channel number, i.e. the number of the input of a metering
[1 … 64] equipment with several inputs for the measurement of energy of the same
or different types (e.g. in data concentrators, registration units). This
enables data from different sources to be identified. If only one channel
(only one meter) is used, it does not have to be specified.
C: Measured quantity Defines the abstract or physical data items related to the information
[1 … 99] source concerned, e.g. active power, reactive power, apparent power,
cos, current or voltage.
General data 0
Active energy + (import) ∑Li 1 L1 21 L2 41 L3 61
– (export) 2 22 42 62
Reactive energy + 3 23 43 63
– 4 24 44 64
QI (quadrant I) 5 25 45 65
QII 6 26 46 66
QIII 7 27 47 67
QIV 8 28 48 68
Apparent energy + (import) 9 29 49 69
– (export) 10 30 50 70
Current 11 31 51 71
Voltage 12 32 52 72
Power factor 13 33 53 73
Frequency 14
Service data C
Error message F
Profile data P
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Appendix 1 OBIS code 93/94
D: Measuring type Defines types, or the result of the processing of physical quantities
[1 ... 73, F, P] according to various specific algorithms. The algorithms can deliver energy
and demand quantities as well as other physical quantities.
The following list is an excerpt.
Capture period 1 2 3
Cumulated minimum 1 11 21
Cumulated maximum 2 12 22
Minimum 3 13 23
Running average 4 14 24
Last average 5 15 25
Maximum 6 16 26
Instantaneous value 7
Time integral 1 (energy status) 8
Time integral 2 (energy consumption) 9
Time integral 3 (excess consumption) 10
...
Test average 55
Test time integral 4 58
...
Error message F
Load profile 01
E: Tariff Defines the further processing of measurement results to tariff registers,
[1 ... 9] according to the tariffs in use. Total values are marked with ‘0’. For abstract
data or for measurement results for which tariffs are not relevant, this value
group can be used for further classification.
F: Stored value Defines the storage of data according to different billing periods. Where this
[01 ... 99] is not relevant, this value group can be used for further classification.
Display code To simplify the reading of the display code, individual parts of the OBIS
code can be omitted. The abstract or physical data C and type of data D
must be shown.
Examples
1.8.0 1 = all-phase active power in positive direction
8 = cumulative value (meter reading)
0 = total energy (no tariffs)
0.9.1 Local time
D000045599 en c – S650 Series 3 – SMA400AT/CT, SFA400AT/CT – User Manual © Landis+Gyr
Contact:
Landis+Gyr AG
Theilerstrasse 1
CH-6301 Zug
Switzerland
Phone: +41 41 935 6000
www.landisgyr.com
Electricity Meters IEC/MID
Industrial and Commercial
ZMD300AT/CT
E650 Series 3
User Manual
Date: 29.10.2013
File name: D000030108 E650 ZMD300xT Series 3 User Manual en m.docx
© Landis+Gyr D000030108 en m
2/84 Revision history
Revision history
Version Date Comments
a 01.07.2009 First edition
b 15.10.2009 Corrections to type designation table in section 1.3
Incorrect note on ZMD/ZFD meters removed from section 1.4
Fig. 4.11 replaced
Referenced documents corrected in section 1.8
Error code F.F 00 00 2x 00 added in section 6.2.2 Error Groups
Various grammatical and language errors corrected throughout the document
c 12.11.2009 Minor formatting and typing errors corrected
d 03.12.2009 Minor formatting and typing errors corrected
e 01.06.2010 Update for firmware version B31
f 08.11.2010 Information concerning losses removed
g 27.01.2011 Updated document template and section 1.3 table entry "045x 4 outputs, additional
power supply 100-240 VAC/VDC"
Optional red LED added to outputs in section 1.4
ZFD400 column removed from the table in section 1.5.3
Footnote added after table in section 1.5.3
Reactive energy section modified in section 1.5.4
Summation channels section modified in section 1.5.4
Section 3.1 retitled "Housing"
h 05.10.2011 Updated document template. Comment regarding grounding inserted in section
4.1.2. Section 5.3.3 "Index System" simplified and new section 11 "Appendix OBIS
Code" inserted.
k 26.09.2012 Update for firmware version B32. New extension board 326x. New measured
quantities. New events. New integrated terminal cover switch. Updated document
template. Section "Safety" becomes first section. OBIS explanation expanded. New
representation of value change procedure in set mode. Minor text improvements
and corrections of formatting and typing errors.
m 29.10.2013 Synchronised document version indicators across all languages.
Updated disclaimer.
Reformatted warnings, cautions and notes.
Corrected minor terminology, spelling and punctuation errors.
Added extension board 047x to section 2.3 “Type designation”.
Added information on 3-phase, 3-wire (no neutral) connections to section 3.4
“Connection diagrams (examples)”.
Added extension board 0470 to section 3.4 “Connection diagrams (examples)”.
Although the information contained within this document are presented in good faith and believed to be correct, Landis+Gyr (including its
affiliates, agents and employees) disclaim any and all liability for any errors, inaccuracies or incompleteness relating to the product.
Landis+Gyr makes no warranty, representation or guarantee regarding the performance, quality, durability or suitability of the products for
any particular purpose. To the fullest extent permitted by law Landis+Gyr disclaims (1) any and all liability arising out of the use of the
product, (2) any and all liability, including, but without limitation to, special, consequential and indirect damages and losses, and (3) any and
all implied warranties, including, but without limitation to, fitness for purpose and merchantability.
The information contained in this document is strictly confidential and is intended for the addressee only. The unauthorised use, disclosure,
copying, alteration or distribution of this document or the contents thereof is strictly prohibited and may be unlawful.
All product information are subject to change without notice.
© Landis+Gyr D000030108 en m – E650 Series 3 – ZMD300AT/CT – User Manual
Table of contents 3/84
Table of contents
Revision history...................................................................................................................................... 2
Table of contents ................................................................................................................................... 3
About this document .............................................................................................................................. 5
1 Safety ............................................................................................................................................. 6
1.1 Safety information ..................................................................................................................... 6
1.2 Responsibilities ......................................................................................................................... 6
1.3 Safety regulations ..................................................................................................................... 7
1.4 Radio Interference .................................................................................................................... 7
2 Device description........................................................................................................................ 8
2.1 Field of application .................................................................................................................... 8
2.2 Characteristics .......................................................................................................................... 8
2.3 Type designation..................................................................................................................... 10
2.4 Block schematic diagram ........................................................................................................ 11
2.5 Measuring system ................................................................................................................... 14
2.5.1 Input signals ...................................................................................................................... 14
2.5.2 Signal processor ................................................................................................................ 15
2.5.3 Measured quantities .......................................................................................................... 17
2.5.4 Formation of measured quantities ..................................................................................... 18
2.5.5 Summation channels ......................................................................................................... 22
2.6 Data profile.............................................................................................................................. 22
2.6.1 Stored value profile ........................................................................................................... 23
2.6.2 Load profile 1 and load profile 2 (option) ........................................................................... 23
2.6.3 Event log ........................................................................................................................... 23
2.7 Communication ....................................................................................................................... 26
2.7.1 Optical interface ................................................................................................................ 26
2.7.2 Communication units ......................................................................................................... 26
2.8 MAP software tools ................................................................................................................. 27
2.9 Anti-tampering features ........................................................................................................... 28
2.9.1 DC magnet detection ......................................................................................................... 29
2.9.2 Terminal cover detection ................................................................................................... 29
3 Mechanical construction ........................................................................................................... 30
3.1 Housing ................................................................................................................................... 30
3.2 Faceplates .............................................................................................................................. 33
3.3 Connections ............................................................................................................................ 34
3.4 Connection diagrams (examples) ........................................................................................... 35
3.5 Dimensions ............................................................................................................................. 39
4 Installation and uninstallation ................................................................................................... 40
4.1 Basic information for connecting meter ................................................................................... 40
4.1.1 Connection with 3 phases and neutral .............................................................................. 40
4.1.2 Connection with 3 phases without neutral (Aron circuit).................................................... 40
4.2 Mounting the meter ................................................................................................................. 40
4.3 Connecting meter .................................................................................................................... 42
4.3.1 Connecting the RS485 interface........................................................................................ 45
4.4 Check of connections .............................................................................................................. 46
4.5 Commissioning, functional check and sealing ........................................................................ 46
4.6 Installation of terminal cover detection .................................................................................... 47
4.7 Uninstallation .......................................................................................................................... 48
5 Operation..................................................................................................................................... 50
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5.1 Operation with auxiliary power supply .....................................................................................50
5.2 Control elements .....................................................................................................................50
5.2.1 Display buttons ..................................................................................................................50
5.2.2 Control of display via optical interface................................................................................51
5.2.3 Reset button .......................................................................................................................51
5.3 Display .....................................................................................................................................52
5.3.1 Introduction ........................................................................................................................52
5.3.2 Basic layout ........................................................................................................................52
5.3.3 Index system ......................................................................................................................53
5.4 Types of display .......................................................................................................................54
5.4.1 Operating display ...............................................................................................................54
5.4.2 Display menu .....................................................................................................................55
5.4.3 Service menu .....................................................................................................................58
5.5 Alert LED .................................................................................................................................59
5.6 Optical test output ....................................................................................................................59
5.7 Data readout ............................................................................................................................60
5.7.1 Readout to IEC 62056-21 ..................................................................................................60
5.7.2 Readout to DLMS...............................................................................................................62
5.8 Input of formatted commands ..................................................................................................63
5.9 Set time and date, ID numbers, battery time ...........................................................................64
6 Service .........................................................................................................................................65
6.1 Operating faults .......................................................................................................................65
6.2 Error messages .......................................................................................................................65
6.2.1 Structure of an error message ...........................................................................................66
6.2.2 Error groups .......................................................................................................................66
6.3 Repairing meters .....................................................................................................................71
7 Maintenance ................................................................................................................................72
7.1 Meter testing ............................................................................................................................72
7.1.1 Test mode ..........................................................................................................................72
7.1.2 Measuring times .................................................................................................................72
7.1.3 Optical test output ..............................................................................................................73
7.1.4 No-load test ........................................................................................................................74
7.1.5 Starting test active part ......................................................................................................74
7.1.6 Starting test reactive part ...................................................................................................75
7.2 Changing the battery ...............................................................................................................75
8 Disposal .......................................................................................................................................77
9 Index .............................................................................................................................................78
Appendix 1 OBIS code ..................................................................................................................81
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About this document 5/84
About this document
Range of validity The present user manual applies to the meters specified on the title page.
Purpose The user manual contains all the information required for metering
applications for the intended purpose. This includes:
Provision of knowledge concerning the characteristics, construction
and function of the meters
Information about potential dangers, their consequences and
measures to prevent any danger
Details about the performance of all activities throughout the service
life of the meters (parameterisation, installation, commissioning,
operation, maintenance, decommissioning and disposal)
Target group The content of this user manual is intended for technically qualified
personnel of utilities (energy supply companies), responsible for system
planning, installation and commissioning, operation, maintenance,
decommissioning and disposal of meters.
Reference documents The following documents provide further information related to the subject
of this document:
D000030104 "E650 ZMD300AT/CT Series 3 Technical Data"
D000030112 "E650 ZxD Series 3 Functional Description"
Conventions The structure and significance of meter type designations are described in
section 2.3 "Type designation". The following conventions are employed in
this user manual for representing type designations:
The lower case letter "x" can be used as an unknown to indicate
different versions (e.g. ZMD310xT for the ZMD310AT and ZMD310CT
meters).
The following collective terms are also sometimes used instead of the
type designation:
– "Active energy meters" for the ZMD300AT meters
– "Combi-meters" for the ZMD300CT meters
D000030108 en m – E650 Series 3 – ZMD300AT/CT – User Manual © Landis+Gyr
6/84 Safety
1 Safety
This section describes the safety information used in this manual, outlines
the responsibilities and lists the safety regulations to be observed.
1.1 Safety information
The following symbols are used to draw your attention to the relevant
danger level, i.e. the severity and probability of any danger, in the individual
sections of this document.
Warning
Used to indicate a dangerous situation that could cause bodily injury or
death.
Caution
Used to indicate a situation/ action that could result in material damage or
loss of data.
Note
Used to indicate general guidelines and other useful information.
In addition to the danger level, safety information also describes the type
and source of the danger, its possible consequences and measures for
avoiding the danger.
1.2 Responsibilities
The owner of the meters – usually the utility company – is responsible for
ensuring that all persons working with meters:
Have read and understood the relevant sections of the user manual.
Are appropriately qualified for the work to be performed.
Strictly observe the safety regulations (laid down in section 1.3) and
the operating instructions as specified in the individual sections.
In particular, the owner of the meters bears responsibility for the protection
of persons, prevention of material damage and the training of personnel.
For this purpose, Landis+Gyr provides training on a variety of products and
solutions. Please contact your local Landis+Gyr representative if interested.
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Safety 7/84
1.3 Safety regulations
The following safety regulations must be observed at all times:
The meter connections must be disconnected from all voltage sources
during installation or when opening.
Contact with live parts can be fatal. The relevant supply fuses should,
therefore, be removed and kept in a safe place until the work is
completed so that other persons cannot replace them unnoticed.
Local safety regulations must be observed. Only technically qualified
and appropriately trained personnel are authorised to install the
meters.
Only appropriate tools shall be used for the job. This means, e.g. that
the screwdriver must be of the correct size for the screws, and the
handle of the screwdriver must be insulated.
The meters must be held securely during installation. They can cause
injuries if dropped.
Meters that have been dropped must not be installed, even if no
damage is apparent, but must be returned to the service and repair
department (or the manufacturer) for testing. Internal damage may
result in malfunctions or short-circuits.
The meters must never be cleaned under running water or with
compressed air. Water ingress can cause short-circuits.
1.4 Radio Interference
Possible radio interference in residential environments
This meter is normally a class B product. In combination with some
communication modules it can become a Class A product. In a domestic
environment, this may then cause radio interference, in which case the user
may be required to take adequate measures.
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8/84 Device description
2 Device description
This section provides you with a brief overview of the design and function of
the E650 ZMD300AT/CT meters.
2.1 Field of application
ZMD300xT meters can be used for direct connection at the low voltage
level. They are primarily used by medium consumers.
ZMD300xT meters have a comprehensive tariff structure. This extends
from seasonal tariffs to multiple energy and demand tariff rates.
The ZMD300CT combi-meters record active and reactive energy
consumption, the ZMD300AT active energy meters only the active energy
in three-phase four-wire networks on low voltage, and from this determine
the required electrical measured quantities. They are connected directly to
the phase conductors at the measuring point.
The data determined are displayed (LCD) and are also available at the
optical interface for data acquisition, with an appropriate communication
unit also as required via CS, RS232, RS485, PSTN modem, GSM modem,
etc. When equipped with transmitting contacts, the meters can also be
used as transmitting meters for telemetering. The tariff rates can be
controlled internally or externally.
With a communication unit, the meters can also be used for recording
counter pulses for other physical media (e.g. water or gas volumes).
2.2 Characteristics
ZMD300xT meters have the following basic characteristics:
Recording of active, reactive and apparent energy in all four quadrants
(ZMD300CT) or recording of imported and exported active energy
(ZxD 300AT)
Tariff system with energy and demand tariff rates, stored values, load
profiles, etc.
Extended functions such as monitoring functions, sliding maximum
demand, etc. (for ZMD300CT additionally power factor cosφ)
Tariff control
– External
- via control inputs (ZMD300xT21 and ZMD300xT41)
- via communication interfaces using formatted commands
– Internal
- by integral time switch (ZMD300xT24 and ZMD300xT44)
- by event signals based on monitored values, such as voltage,
current demand, etc.
Display of data on a liquid crystal display (LCD)
Active and reactive power per phase and true RMS values of voltages
and currents by means of digital signal processing (DSP) chips
Accuracy: Compliance with IEC class 1 and with MID accuracy class B
for active energy consumption (ZMD310xT) and IEC class 1 for
reactive energy (ZMD310CT).
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Device description 9/84
Flexible measuring system through parameterisation (definition of
different variables by software)
Correct measurement even with failure of individual phases, or when
used in two- or single-phase networks
Wide range of measurement from starting current to maximum current
Optical interface according to IEC 62056-21 and DLMS
– For direct readout of meter data
– For service functions of the meter, extension board and
communication unit (e.g. parameterisation)
Inputs for recording fixed valency pulses (communication unit)
Output contacts (solid-state relays) for fixed valency pulses, control
signals and status messages
Output contacts (relays) for control and status messages
Installation aids
– Indication of phase voltages, phase angles, rotating field and
direction of energy
Storage of event information, e.g. voltage failures, exceeding of
thresholds or error messages. Event information can be read out via
the available interfaces. Important events can be communicated to the
energy supply company as operational messages (sending of SMS
messages, control of an arrow in the display, drive for an output
contact, etc.).
Interfaces such as CS, RS232, RS485, modem, etc. for remote trans-
mission of data (communication unit)
Auxiliary power supply for communication with the meter if no
measuring voltage is present
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2.3 Type designation
ZMD 3 10 C T 44 4207 S3
Network type
ZMD 3-phase, 4-wire network (M-circuit)
Connection type
3: Direct connection
Accuracy class
10: Active energy class 1 (IEC), B (MID)
Measured quantities
C: Active and reactive energy
A: Active energy
Construction
T: With exchangeable communication units
Tariffication
21: Energy rates, external rate control via control inputs
24: Energy rates, internal rate control via time switch
(additionally possible via control inputs)
41: Energy and demand rates, external rate control via control inputs
44: Energy and demand rates, internal rate control via time switch
(additionally possible via control inputs)
All versions with 3 control inputs and 2 output contacts
Additional functions
000x No extension board
060x 6 outputs
240x 2 control inputs, 4 outputs
326x 3 control inputs. 2 relays outputs, auxiliary power supply 12–24 VDC
420x 4 control inputs, 2 outputs
045x 4 outputs, auxiliary power supply 100–240 VAC/VDC
046x 4 outputs, auxiliary power supply 12–24 VDC
047x 4 outputs, auxiliary power supply 12–60 VDC
xxx0 No additional functions
xxx2 DC magnet detection
xxx7 Load profile
xxx9 DC magnet detection and load profile (integrated terminal cover switch option only available
in this configuration)
Series 3
The communication unit is not a part of this type designation, since it is a
complete unit in itself. Users can change it at any time without opening the
certification seal. Every communication unit has its own user manual.
Series designation The hardware version is distinguished by the series designation. The 1st
hardware generation (Series 1) has no series designation.
The 2nd hardware generation (Series 2) the series designation ‘S2’ is
printed on the nameplate directly after the type designation. With meters
which contain a measurement sensor with embedded coil, the series
designation ‘S2a’ is used for distinction. ‘S2s’ represents a Series 2 meter
with symmetrical terminal layout.
‘S3’ represents the newest hardware generation.
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Firmware version The firmware version and firmware checksum stored in the meter can be
shown on the display or read out as IEC readout list, if parameterised
accordingly (see section 5.7 "Data readout"). Specific meter characteristics
are present or not depending on the firmware version.
2.4 Block schematic diagram
This section provides an overview of the function of ZMD300xT meters
based on a block schematic diagram.
Figure 1. Block schematic diagram ZMD300xT
The ZMD300AT active energy meters record the imported and exported
active energy consumption, while the ZMD300CT combi-meters record the
active and reactive energy consumption in all four quadrants.
The ZMD300xT meters can be fitted with modular communication
interfaces in a communication unit, which can be exchanged or used in the
field as required.
Inputs The main meter inputs are:
Connections of phase voltages (U1, U2, U3), phase currents (I1, I2, I3)
and neutral conductor (N)
– For processing in the measuring system
– For the three-phase power supply to the meter and voltage monitor
Control inputs Ut (3 fixed, plus up to 4 others on extension board) for:
– Changeover of energy and demand tariff rates
– Resetting
– Demand inhibition
– Synchronising
Opto-couplers protect the internal circuitry from interference, which
could otherwise enter via the control inputs.
Buttons
– For display control (display buttons, optical interface)
– For resetting or service functions (reset button)
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Pulse inputs for connection of external pulse transmitters (only for
meters equipped with a communication unit)
Outputs The meter has the following outputs:
LCD display with buttons for local reading of billing data (single 8-digit
display with additional information, such as energy direction, energy
type, presence of phase voltages and identification number)
Optical test outputs (red, 1 in active energy meters, 2 in combi-meters)
Optional alert LED (red) to indicate alerts on the front face of the meter
Static relay with freely parameterised signal assignment (2 fixed, plus
up to 6 others on the extension board)
Relay outputs with limited parameterised signal assignment due to
limited life expectancy (up to 2 on the extension board)
Optical interface for automatic local data acquisition by a suitable
acquisition unit (handheld terminal)
Communication interfaces of various kinds in the communication unit
(also see section 2.7 "Communication" )
Measuring system The input circuits (voltage dividers and current shunts with voltage trans-
former) record voltage and current in the individual phases. Analogue-
digital converters digitise these values and feed them as instantaneous
digital values via calibration stages to a signal processor.
Signal processing The signal processor determines the following measured quantities from
the instantaneous digital values of voltage and current for each phase and
forms their mean value over one second:
Active power per phase
Reactive power per phase (combi-meters ZMD300CT only)
Phase voltages
Phase currents
Network (mains) frequency
Phase angles
Signal utilisation For signal utilisation in the various registers, the microprocessor scans the
measured quantities every second to determine the following values:
Active energy (sum and individual phases, separated according to
energy direction, if required in the combi-meters ZMD300CT also
assigned to the 4 quadrants)
Reactive energy (only for combi-meters ZMD300CT, sum and
individual phases, separated according to energy direction, assigned
to the 4 quadrants)
Apparent energy (only for combi-meters ZMD300CT, sum and
individual phases, separated according to energy direction)
Power factor cosφ (only for combi-meters ZMD300CT, individual
phases and mean value)
Phase voltages
Phase currents and neutral current
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Active and reactive power
Direction of rotating field
Total harmonic distortions of active energy, voltage and current
Tariff control Rate control is performed:
Externally via control inputs (3 fixed, plus up to 4 others on the
extension board)
Externally via communication interfaces using formatted commands
Internally by time switch and calendar clock
By event signals based on threshold values of the monitoring functions
Data preparation for The following registers are available for evaluation of the individual
billing measured values:
32 for energy rates
27 for total energy
10 for running mean demand values
24 for demand rates
2 for power factors cosφ (combi-meters ZMD300CT only)
Up to 41 diagnostic registers
Others for values of voltage and current, network frequency and phase
angles
Memory A non-volatile flash memory serves to record data profiles and also
contains the configuration and parameterisation data of the meter and
secures the billing data against loss due to voltage failures.
Power supply The supply voltages for the meter electronics are obtained from the three-
phase network, whereby the phase voltage can vary over the entire voltage
range without the supply voltage having to be adjusted. A voltage monitor
ensures correct operation and reliable data recovery in the event of a
power failure and correct restarting when the voltage is restored.
Auxiliary power For medium or high-voltage applications in particular, the measuring
supply voltage can be switched off. Since the meter normally obtains its supply
from the measuring voltage, it is also switched off and cannot be read. The
auxiliary power supply connected in parallel with the normal power supply
ensures operation of the meter free from interruption, so that it can be read
at any time. The auxiliary power supply is situated on an extension board.
Extension board The extension board is fitted inside the meter and is secured by the
certification seals. It cannot be exchanged. It can have the following
components:
Up to 4 control inputs in combination with
Up to 6 output contacts (solid-state relays)
Up to 2 relays outputs
An auxiliary power supply
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Communication unit The communication unit for fitting only in the ZMD300xT meters is a
complete unit in its own case. If present, it is situated behind the front door,
and is therefore secured by a utility seal and can be exchanged or inserted
in the field if necessary. It contains:
Communication interfaces as required for remote readout of the meter
(e.g. CS, RS232, RS485, modem)
Two signal inputs (S0 interfaces) for processing external pulse
transmitters
2.5 Measuring system
Figure 2. Block schematic diagram of measuring system
2.5.1 Input signals
The meter has the analogue current values I1, I2 and I3 and analogue
voltage values U1, U2 and U3 available as input signals.
ZMD300xT
Figure 3. Type of measurement ZMD300xT
Since the ZMD300xT measures the individual phases mutually
independently with one measuring element each, it can record the sum of
the three phases, the individual phases themselves, the phase angle
between voltage and current as well as the angle between voltages U1–U2
and U1–U3.
Voltage input High resistance voltage dividers reduce the voltages U1, U2 and U3 (58 to
240 V) applied to the meter to a proportionate amount of a few mV (UU) for
further processing.
Current input Internal current transformers reduce the input currents I1, I2 and I3 to the
meter (0 to 10 A) for further processing. The secondary currents of these
current transformers develop voltages proportional to the input currents
across resistors, also of a few mV (UI).
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2.5.2 Signal processor
Figure 4. Principle of signal processor
ZMD300AT active energy meters do not measure reactive energy.
Digitizing The analogue signals Ux and Ix are digitised in Sigma-Delta converters
(analogue-digital converters with highest resolution) with a sample rate of
1.6 kHz and then filtered. A following calibration stage compensates for the
natural errors of the voltage divider or current transformer, so that no
further adjustment is necessary in the subsequent processing.
Calibrated digital instantaneous values of voltage (u) and current (i) for all
three phases are then available as intermediate values for the formation of
the required values in the signal processor.
Calculation of active The instantaneous value of active power p is produced by multiplying the
power instantaneous values of voltage u and current i (the active component
corresponds to the product of voltage component with the current
component parallel to the voltage). Thereby the harmonics up to 1 kHz are
measured correctly.
IQ I
Calculation per phase of
P = U . I . cos
IP U
Figure 5. Active power calculation
Instantaneous power If the meter is parameterised to calculate instantaneous power as signed
with sign values, the following values of power are available:
Active P: + in QI and QIV, - in QII and QIII
Reactive P: + in QI and QII, - in QIII and QIV
Calculation of reactive There are two possibilities to calculate the instantaneous value of reactive
power power (ZxD300Cx combi-meters only):
Measured:
For the instantaneous value of reactive power q the instantaneous value of
voltage u must be rotated by 90° before multiplication (the reactive
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component is the product of the voltage component with the current
component vertical to the voltage). Thereby no harmonics are measured
since only the fundamental wave is rotated through 90°.
IQ I
Calculation per phase of
Q = U . I . sin
IP U
Figure 6. Reactive power calculation (method: measured)
Calculated vectorial (not recommended):
The instantaneous value of reactive power is calculated using the values of
active power and apparent power.
The reactive power is the square root of the square value of apparent
power minus the square value of active power. This method includes the
harmonics.
URMS, IRMS calculation The square values of voltage and current are obtained by multiplying the
instantaneous values of voltage and current by themselves. From these
values the signal processor forms the corresponding single-phase RMS
values URMS and IRMS.
Time measurement The network frequency can be calculated from the time measured between
two zero passages (change from negative to positive value of voltage U1).
The times between zero passage of the phase voltage U1 and those of the
other phase voltages U2 and U3 serves to determine the phase angle
between the voltages and of the rotating field.
U1 U2 U3 Time measurement
for rotating field,
frequency, phase angle
1 : T U1-U2
2 : T U1-U3
1
2
3 : TU1-U1 (fn)
3
Figure 7. Time measurement
The phase angle between voltage and current is determined by the times
between zero passage of the phase voltage U1 and those of the phase
currents I1, I2 and I3.
Mean value formation For further processing of the individual signal, the signal processor
generates mean values over one second, which the following
microprocessor scans at intervals of one second.
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2.5.3 Measured quantities
Measured quantity ZMD300
Active energy in quadrant I A (QI) Sum / Phases
Active energy in quadrant II A (QII) Sum / Phases
Active energy in quadrant III A (QIII) Sum / Phases
Active energy in quadrant IV A (QIV) Sum / Phases
Active energy import +A (QI+QIV) Sum / Phases
Active energy export –A (QII+QIII) Sum / Phases
Active energy, absolute value +A+-A Sum / Phases
Active energy, absolute value +A--A Sum / Phases
Active energy import summation Σ +A Sum
Active energy export summation Σ -A Sum
Active energy by single quantity Σ ALx Sum
Reactive energy in quadrant I R (QI) Sum / Phases
Reactive energy in quadrant II R (QII) Sum / Phases
Reactive energy in quadrant III R (QIII) Sum / Phases
Reactive energy in quadrant IV R (QIV) Sum / Phases
Reactive energy import +R (QI+QII) Sum / Phases
Reactive energy export –R (QIII+QIV) Sum / Phases
Reactive energy import +R (QI+QIV) Sum / Phases
Reactive energy export –R (QII+QIII) Sum / Phases
Reactive energy, combined R (QI+QIII) Sum / Phases
Reactive energy, combined R (QII+QIV) Sum / Phases
Reactive energy, absolute value +R+-R Sum / Phases
Reactive energy, absolute value +R--R Sum / Phases
Reactive energy import summation Σ +R Sum
Reactive energy export summation Σ -R Sum
Apparent energy import +S (QI+QIV) Sum / Phases
Apparent energy export -S (QII+QIII) Sum / Phases
Phase voltages (RMS) U1, U2, U3
Phase currents (RMS) I1, I2, I3
Neutral current I0 yes
Network frequency fn yes
Active power ±P Sum / Phases
Reactive power ±Q Sum / Phases
Phase angle between voltages U U1-U2 / U1-U3*
Phase angle between voltage and U-I U1-I1, U1-I2, U1-I3 *
current or
U1-I1, U2-I2, U3-I3
Power factor PF Sum / Phases
Direction of rotating field yes
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Measured quantity ZMD300
THD of active energy import +THDA Sum
THD of active energy export -THDA Sum
THD of active energy (percent) THDA [%] Sum
THD of phase voltages (absolute) THDU Phase 1, 2, 3
THD of voltage (percent) THDU [%] Sum
THD of phase currents (absolute) THDI Phase 1, 2, 3
THD of current (percent) THDI [%] Sum
* Only if U1 is present.
2.5.4 Formation of measured quantities
By scanning the mean values of active power P, and in combi-meters also
reactive power Q every second, energy components are produced (Ws or
vars) at fixed intervals (every second) and with varying energy magnitudes
or demand. These energy components are scaled by the microprocessor
corresponding to the meter constant and are then available as measured
quantities for selection of the measured values. The measured values are
fed directly to the following registers to record the energy and the maximum
demand (in combi-meters also of minimum power factor).
Active energy The active energy in the individual phases ±A1, ±A2 and ±A3 are formed
directly from the mean values of active power P1, P2 and P3.
By summating the mean values of active energy A1, A2 and A3 the
microprocessor calculates the total active energy import +A or the total
active energy export -A.
Mean values
per second Measured quantities
± A1
+A (Import)
±A 2 -A (Export)
±A3
Figure 8. Total active energy
Reactive energy The reactive energy values of the individual phases ±R1, ±R2 and ±R3 are
obtained in the combi-meters directly from the mean values of reactive
power Q1, Q2 and Q3. The reactive energy can therefore also be
calculated vectorially (see 1.5.2).
By summating the mean values of reactive energy R1, R2 and R3, the
microprocessor calculates the total positive reactive energy +R or the total
negative reactive energy -R.
Mean values
per second Measured quantities
± R1
+R
±R2 -R
±R3
Figure 9. Total reactive energy
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The microprocessor can allocate the reactive energy to the 4 quadrants in
the combi-meters from the signs of R and A:
Reactive energy in 1st quadrant: +Ri
Reactive energy in 2nd quadrant: +Rc
Reactive energy in 3rd quadrant: –Ri
Reactive energy in 4th quadrant: –Rc
In the same way, it can allocate the reactive energy of the individual phases
to the 4 quadrants.
+R
+ kvarh + kvarh
+Rc +Ri
Quadrant II Quadrant I
Export -A +A Import
- kWh Quadrant III Quadrant IV + kWh
- kvarh
-Ri -Rc - kvarh
-R
Figure 10. 4-quadrant measurement
The quadrants are numbered from top right as 1st quadrant (+A/+Ri) anti-
clockwise to the 4th quadrant (+A/–Rc) at bottom right.
Apparent energy The apparent energy is calculated in the combi-meters in two ways:
By vectorial addition of the active and reactive energy of the individual
phases
By multiplying the rms values of voltage and current of the individual
phases
The method of calculation can be parameterised (only one possible in each
case).
Calculation method 1 From the mean values A1, A2 and A3 and R1, R2 and R3 the
(vectorial addition) microprocessor calculates the apparent energy of the individual phases
±S1, ±S2 and ±S3 as well as the total apparent energy ±S.
Mean values
per second
±A1
Measured quantities
±A2
±A3
2 2 +S (Import)
(A1 + A2 + A3) + (R1 + R2 + R3)
±R1 -S (Export)
±R2
±R3
Figure 11. Total apparent energy according to calculation method 1
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Only fundamental wave considered for reactive energy
Only the fundamental wave is considered for the calculation of the reactive
energy share; possible harmonics are not taken into account.
Calculation method 2 From the mean values U1rms, U2rms, U3rms and I1rms, I2rms, I3rms the
(from rms values) microprocessor calculates by multiplication the apparent power of the
individual phases ±VA1, ±VA2 and ±VA3 and summates these for the total
apparent power ±VA.
Mean values
per second
I1rm s
U1rm s
I1rm s U1 rm s
å Measured quantities
I2rm s +S (Import)
U2rm s
I2rm s U2 rm s
å -S (Export)
I3rm s
U3rm s
I3rm s U3 rm s
å
Figure 12. Total apparent power according to calculation method 2 (ZxD300Cx
combi-meters only)
Harmonics considered for reactive energy
As RMS values are used for the calculation of the apparent energy with
calculation method 2, not only the fundamental wave but also the
harmonics are taken into account. Therefore, if harmonics are present, the
measured values are greater than those of calculation method 1.
Summation channels The values of two measurement quantities (incl. pulse inputs EX1 and EX2)
can be added.
Power factor cosφ The power factor cosφ is calculated in combi-meters as follows:
The meter uses the method of calculation employed for calculating the
apparent power.
Phase voltages The rms values of the voltages U1rms, U2rms and U3rms are obtained from
the mean values of the squares of the voltages by extracting the root and
directly from these the phase voltages U1, U2 and U3.
Phase currents The rms values of the currents I1rms, I2rms and I3rms are obtained from the
mean values of the squares of the currents by extracting the root and
directly from these the phase currents I1, I2 and I3.
Neutral current The signal processor calculates the instantaneous neutral current i0 by
adding the instantaneous phase currents i1, i2 and i3.
i2
i0 = i1 + i2 + i3
i1 (vectorial addition)
i3
i0
Figure 13. Neutral current I0
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Network frequency The signal processor calculates the network frequency fn by forming the
reciprocal from the time tU1-U1 between two zero passages of voltage U1.
Phase angles The signal processor calculates the phase angles between voltages U1-U2
and U1-U3 from the times tU1-U1, tU1-U2 and tU1-U3 between zero passages of
the various voltages.
The signal processor calculates the phase angle between voltage U1 and
current per phase from the times tU1-I1, tU1-I2 and tU1-I3 between zero
passages of the voltage U1 and the phase currents.
2 forms of representation are available for displaying the phase angle.
These can be selected by parameterisation.
Case 1: All voltage and current angles are displayed clockwise with
reference to the voltage in phase 1. The values of the angles are always
positive and can be from 0 to 360°.
Figure 14. Phase angle case 1
Case 2: The voltage angles are displayed as in case 1. The angles of the
currents are displayed, however, with reference to the associated phase
voltage and can have values between -180° and +180°.
Figure 15. Phase angle case 2
Direction of rotating The direction of the rotating field is calculated by the microprocessor based
field on the phase angle of the 3 voltages. If the direction of rotation
corresponds to that specified by the parameterisation, the phase voltage
indications L1, L2 and L3 are continuously lit. Otherwise they flash every
second.
Total harmonic The measuring system produces information about the total harmonic
distortion distortion of the active energy.
For that purpose, the voltages are fed through notch filters, which remove
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the fundamental wave.
+A +THDA
+THDA = +A - (+A fundamental)
-A -THDA
-THD A = -A - (-A fundamental )
Figure 16. Calculation of total harmonic distortion
In addition, the following absolute and relative THD values available:
THD of active energy (relative to the nominal active energy)
THD of phase voltages (absolute)
THD of voltage (relative to the nominal voltage)
THD of phase currents (absolute)
THD of phase current (relative to the nominal current)
2.5.5 Summation channels
The values of two measurement quantities (incl. pulse inputs EX1 and EX2)
can be added. The added quantities must be of the same energy type
(active, reactive or apparent). The sum is stored in a total energy register.
Energy registers which contain the summation of two measured quantities
(summation channels) cannot be used for tariffication.
ME1
EX1
EX2
MExx
+ Total energy register
Figure 17. Summation channels
2.6 Data profile
A non-volatile memory (FLASH memory) contains the data of:
The stored value profile
The load profile 1
The load profile 2 (optional)
The event log
The three groups of dedicated event logs
The flash memory stores data without data loss in case of voltage failures.
No battery is required for this purpose.
The total size of the available memory for the stored billing value profile, the
load profile(s), the event log and the dedicated event logs is 1.8 MB.
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2.6.1 Stored value profile
At the end of the billing period, the meter stores the current value of the
registers to the stored value profile. Which energy registers and/or demand
registers are stored to the stored billing value profile can be selected by
parameterisation.
Memory organisation The stored value profile is organised as a circular buffer, i.e. the oldest
entry will be overwritten by the most recent entry. The memory capacity
which is available for the stored value profile depends on parameterisation.
2.6.2 Load profile 1 and load profile 2 (option)
The load profiles are used to save the values of various registers at regular
intervals. The measured values that are captured in the load profile can be
selected by parameterisation.
Load profile 2 is optional
The second load profile is optional.
Please consult your sales representative for further details.
Profile 1 The first load profile is generally used for billing purposes. Its capture
period has a range of 1...60 min. This load profile may also contain
instantaneous values and detailed status information for data processing in
central stations.
Profile 2 The second load profile can be used to store instantaneous values over a
period which differs from the period of the first load profile. Apart from the
differing capture period, the second load profile is identical with the first
load profile.
Memory organisation The load profile is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry. The memory capacity which is
available for the load profile(s) depends on parameterisation. If both load
profiles are activated, they share the memory capacity which is allocated to
the load profile(s).
2.6.3 Event log
Events that occur sporadically are stored in the event log. The user may
select which events trigger an entry in the event log. The event log is used
to analyse the behaviour of the network as well as to supervise the correct
function of the meter.
Memory organisation In the event log, a maximum of 500 event entries can be stored. The
individual entries consist of the time stamp and the event number.
Additional information such as the error register or energy total registers
can also be stored with every event.
The event log is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry.
Dedicated event log Network quality events, can be stored in the dedicated event log. The
dedicated event log consists of three groups of logs.
Over-voltage events
Under-voltage events
Missing voltage events
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In the dedicated event logs, important information can be stored per entry
such as:
Duration of the events
Extreme values of the events (not for missing voltage).
Instantaneous values
Maximum three energy registers
Additional information can be read from the header of the event logs, such
as the longest entry, the shortest entry, the total number of occurrence and
the total duration of the event.
Memory organisation The dedicated event logs are organised as circular buffers, i.e. the oldest
entry will be overwritten by the most recent entry.
List of events The table below lists all events which can be captured in the event log.
Depending on the parameterisation, some events may never occur.
Events which can be stored in the dedicated event log are marked in the
corresponding column.
Number Event Entry in dedicated
event log possible
2 All energy registers cleared
3 Stored values and/or load profile cleared
4 Event log profile cleared
5 Battery voltage low
7 Battery ok
8 Billing period reset
9 Daylight saving time enabled or disabled
10 Clock adjusted (old time/date)
11 Clock adjusted (new time/date)
17 Under-voltage L1 x
18 Under-voltage L2 x
19 Under-voltage L3 x
20 Over-voltage L1 x
21 Over-voltage L2 x
22 Over-voltage L3 x
23 Power down
24 Power up
25 Over-current L1
26 Over-current L2
27 Over-current L3
28 Over-current neutral
31 Power factor monitor 1
32 Power factor monitor 2
33-40 Demand monitors 1-8
45 Error register cleared
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Number Event Entry in dedicated
event log possible
49 Missing voltage L1 x
50 Missing voltage L2 x
51 Missing voltage L3 x
55 Current without voltage L1
56 Current without voltage L2
57 Current without voltage L3
58 Missing additional power supply
59 All registers and profiles cleared
63 Wrong phase sequence
64 Correct phase sequence
66 Invalid clock
74 Backup memory access error
75 Measuring system access error
76 Time device access error
77 Load profile memory access error
79 Communication unit access error
80 Display board access error
81 Program checksum error
82 Backup data checksum error
83 Parameter checksum error
84 Load profile checksum error
85 Stored values checksum error
86 Event log checksum error
87 Calibration data checksum error
88 Load profile 2 checksum error
89 Invalid start-up sequence
93 Expired watchdog (general system error)
94 Communication locked
96 Wrong extension board identification
104 Count registers cleared
105 SMS delivery to GSM failed
106 Alert occurred
124 Compensation values changed
128 Energy total and rate register cleared
133 Terminal cover removed
134 DC Field detected ON
187 Terminal cover mounted
188 DC Field detected OFF
193 Load profile 2 cleared
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Number Event Entry in dedicated
event log possible
211 Control input 1 set
212 Control input 1 reset
2.7 Communication
The ZMD300xT meters have an optical interface for local communication
via a readout head, and a wide range of communication interfaces which
can be inserted in the meter.
2.7.1 Optical interface
The optical interface to IEC 62056-21 is a serial, bi-directional interface. It
is situated at top right on the main faceplate (also see section 3
"Mechanical construction") and serves:
For automatic local data recording by means of a suitable acquisition
unit (hand-held terminal) (see section 5.7 "Data readout")
For performing service functions, e.g. to input formatted commands
(see section 5.8 "Input of formatted commands")
As "optical button", i.e. as receiver of a light signal, e.g. generated by a
flashlight acting like the "down" display button (also see section 5.2.2
"Control of display via optical interface")
For communication with a Landis+Gyr .MAP110 Service Tool or a
Landis+Gyr MAP120 Parameterisation Tool.
2.7.2 Communication units
The communication units which can be inserted in the meter can be used:
For remote reading and for remote tariff control of meters (RS232,
RS485, CS, M-Bus, PSTN modem, GSM modem, GPRS modem,
Ethernet, etc.) or
For recording metering pulses for other physical media, such as
water, gas or heat (S0 interface).
Access via the communication interfaces is protected for specific access
levels using the meter security system by means of passwords. If the
monitoring is activated by corresponding parameterisation, communication
is inhibited for a selected time (max. 24 h) after a selected number of
password attempts with an incorrect password (max. 15). Monitoring takes
place independent of all access levels with password protection and for the
IEC W5 password.
The communication devices are accommodated in an easily exchanged
communication unit, which is plugged in behind the front door of the meter
and secured by a factory seal (also see section 3 "Mechanical
construction"). It can be fitted and removed at any time in the field without
touching the certification seal. Landis+Gyr recommend exchanging
communication units only if the meter is separated from the network and
switched off.
An initial fitting as well as retrofitting without re-parameterisation of the
meters is possible with any version of communication unit. For fitting and
removal of the already parameterised communication units, the installation
personnel do not require any special knowledge of communications.
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Modern plug connections ensure a rapid and faultless connection of the
communication units.
Figure 18. Simple fitting of the communication unit
Versions of Communication units (CU) are available in various versions. The document
communication units "Overview of Communication Applications", D000011226 contains a list of
all currently available CU-interfaces with explanations.
Further information More detailed information about Landis+Gyr Dialog communication
sources solutions can be found in the following documents.
Technical data for the various communication units
User manuals for the various communication units
Detailed application notes for numerous reference applications with
various communication units for different transmission media:
– Point-to-point Connection with internal PSTN Modem Mx
(D000011505)
– Point-to-point Connection with internal GSM Modem Gx
(D000011507)
– Etc.
All these documents as well as advisory services are available from
authorised Landis+Gyr representatives.
2.8 MAP software tools
There are two software tools available for parameterisation of the E650
meter and for communication with the meter: .MAP110 and MAP120
Areas of application
Figure 19. Application of MAP software tools
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.MAP110 The .MAP110 Service Tool covers the following applications normally
required for meter installation and in the service sector:
Billing data readout
Readout and export of profiles (load profile(s), stored values and event
log, dedicated event logs)
TOU (Time of Use) readout and modification
Billing period reset
Register and profile resets
Setting of certain parameter ranges, such as primary data, time switch,
communication parameters, etc.
Communication input settings
Communication settings for Landis+Gyr communication units readout
and modification
GSM installation aid for Landis+Gyr communication units (field
strength indicators, telephone number information, PIN-code handling)
Test SMS message transmission
Analysis and diagnostic functions
MAP120 The Landis+Gyr MAP120 software is used to parameterise the meter and
the communication unit, i.e. it is possible to read out and modify all device
parameters.
In contrast to communication devices from other manufacturers, no
additional software and training costs are incurred by the use of Landis+Gyr
communication units, since the MAP software tools support both meters
and communication units.
2.9 Anti-tampering features
The following anti-tampering features are available for ZMD310xT meters:
DC magnet detection for the detection of strong magnetic fields close
to the meter. This feature is installed during the manufacturing
process.
Terminal cover detection for the detection of situations when the
terminal cover has been opened. This feature can be a retrofit or an
integrated version. The integrated version is available if the DC
magnet detection option is selected and must be integrated during
manufacturing process.
Example of integrated terminal switch available from mid-2012.
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2.9.1 DC magnet detection
The meters ZMD310xT can be ordered with a feature which detects strong
DC magnetic fields. When a magnetic field is present, event 134 is set;
when the magnetic field disappears, event 188 is set. These events can
e.g. be entered into the event log with date and time. The meter’s type
description informs you whether this feature has been implemented (see
page 10).
With the DC magnet detection, it is possible to order the integrated terminal
cover detection option.
2.9.2 Terminal cover detection
Installed ZMD300 meters can be equipped with a terminal cover detection
unit. For this, they need to be parameterised and the unit – consisting of a
switch which detects the removal of the terminal cover – has to be installed.
Whenever the retrofit terminal cover is removed, it detects the switch status
change via control input 1 and enters event 211 in the event log with date
and time. When the terminal cover is mounted again, event 212 is entered
in the event log with date and time.
Please order terminal cover detection units – part number 74 766 0163 0
(minimum order quantity 10) – from:
Landis+Gyr AG
Service & Repair
Theilerstrasse 1
CH-6301 Zug
Switzerland
For installation of the unit, see section 4.6 "Installation of terminal cover
detection".
In case of the integrated terminal switch used, the event 133 is set when
the terminal cover is removed and event 187 when the terminal cover is
mounted.
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3 Mechanical construction
This section describes the mechanical construction of the ZMD300xT meter
and shows the most common connection diagrams.
3.1 Housing
The internal construction of the meters is not described here, since they are
protected following calibration and official certification on delivery by a
manufacturer and certification seal. It is not permitted to open the meters
after delivery. The front door is only secured with a utility seal and can be
opened to operate the reset button, to change the battery, to exchange the
tariff faceplate with connection diagram, or to fit or remove a
communication unit (see figure 21 and separate user manuals for the
communication units available).
The following drawing shows the meter components visible from outside.
Figure 20. Meter ZMD300xT
1 Combined suspension hanger 10 Display button "down"
(open or concealed)
2 Screw with manufacturer seal 11 Front door with tariff faceplate
3 Optical test output reactive energy 12 Upper part of case
consumption (red), ZMD300CT
only
4 Optical test output active energy 13 Lower part of case
consumption (red)
5 Liquid crystal display (LCD) 14 Utility seal for front door
6 Optical interface 15 Terminal cover
7 Screw with certification seal 16 Terminal cover screws with plate
utility seals
8 Front section with main faceplate 17 Alert LED (optional)
9 Display button "up"
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Case The meter case is made of antistatic plastic (polycarbonate). The upper
part of the case is provided with two transparent plastic viewing windows,
affording a view of the main faceplate (top) and the tariff faceplate (bottom).
The lower part of the case is additionally glass-fibre reinforced.
Viewing window The upper viewing window with the main faceplate is secured on the upper
right side with a certification seal, while the upper part of the case is
secured on the upper left side with a manufacturer seal (warranty) or a
second certification seal.
The lower viewing window is in the form of a hinged front door, secured
with a utility seal. The tariff faceplate with the connection diagram on the
rear side, the battery compartment, the reset button and (if present) the
communication unit are situated behind this front door.
Terminal cover The terminal cover is available in various lengths in order to ensure the
required free space for the connections.
Front door The front door must be opened to give access to the battery compartment,
reset button and tariff faceplate. To fit or remove the communication unit,
the terminal cover must also be removed.
Figure 21. Meter with front door open
1 Battery compartment
2 Reset button R
3 Communication unit or dummy
Figure 22. Meter with communication unit withdrawn
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If the meter has no communication unit, this is replaced by a dummy case.
Seal component An additional component, which is easy to install, allows the use of a
standard padlock instead of a utility seal.
Figure 23. Front door sealing using a padlock
The seal component is stowed away in a holder under the front door when
not in use.
Figure 24. Stowage of seal component when not in use
The seal component is installed as follows:
Slide the seal component into the vertical slot at an angle, as shown,
(position 1) until it contacts the rear wall.
Now turn the seal component until it is horizontal and slide it down into
position 2 as illustrated. The two bulges firmly fix the seal component
into the lateral grooves.
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Figure 25. Seal component for use with padlock
3.2 Faceplates
The faceplate is divided into two parts and is designed to customer
specifications. It contains all relevant data about the meter.
Main faceplate The main faceplate is situated behind the plastic viewing window, which is
secured by a certification seal. Recesses permit operation of the display
buttons "down" and "up" for control of the liquid crystal display.
1 2 3
Landis+Gyr E650
Readout
imp imp
13 Cl. 1 kvarh
1000 kWh Cl. 1 4
Three-phase four-wire meter
12 ZMD310CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 10(80) A 50 Hz 5
20XX
6
11 7
10 8
9 T1 T2 T3 SET Test
Figure 26. Main faceplate (example ZMD310CT)
1 Optical test output reactive energy
(with accuracy class – ZMD300CT only)
2 Meter constant R1 (referred to primary values) or R2
3 Optical test output active energy (with accuracy class)
4 Optical interface
5 Approval symbol
6 Type of connection
7 Display button "up"/Display button "down"
8 Symbol for double protective insulation
9 Status indication
10 Arrows for present status indication
11 Liquid crystal display (LCD)
12 Meter data (type designation, serial number, rated values, year of
construction)
13 Alert LED (optional)
The operating elements and displays are described more detailed in
section 5 "Operation".
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Tariff faceplate The tariff faceplate is placed in the front door, which can be swung out
sideways to the left and is secured by a utility seal. The connection diagram
of the meter is shown on the back of the faceplate and is therefore visible
with the front door open.
8.8... Display check 0.1.0 Reset counter C.6.0 Battery hours counter
1 F.F Functional error 0.9.1 Time-of-day 2:1.8.0 S01
73 994 032
0.0 Identification 0.9.2 Date 3:1.8.0 S02
+A -A +Ri +Rc -Ri -Rc
1.2.0 2.2.0 5.2.0 6.2.0 7.2.0 8.2.0 Pmax cumulated
2 1.4.0 2.4.0 5.4.0 6.4.0 7.4.0 8.4.0 Last tm/P running
1.5.0 2.5.0 5.5.0 6.5.0 7.5.0 8.5.0 Plast integr. period
1.6.0 2.6.0 5.6.0 6.6.0 7.6.0 8.6.0 Pmax
1.8.T 2.8.T 5.8.T 6.8.T 7.8.T 8.8.T Energy
1.8.0 2.8.0 5.8.0 6.8.0 7.8.0 8.8.0 Total energy
T = Energy tariff
S01: 1 imp = 10 Wh K1: 1 imp = 10 Wh (+A)
3 S02: 1 imp = 10 Wh K2: 1 imp = 10 Wh (-A)
K3: 1 imp = 10 varh (+Ri)
K4: 1 imp = 10 varh (+Rc)
4
5 Ownership designation K5: 1 imp = 10 varh (-Ri)
K6: 1 imp = 10 varh (-Rc)
6
Figure 27. Tariff faceplate (example ZMD310CT)
1 General data appearing in the display
2 Measured quantities
3 Pulse input data
4 Output contact data
5 Ownership designation
6 Communication unit data (if present)
3.3 Connections
Figure 28. Meter with terminal cover removed (example ZMD300CT)
The terminal block with all meter connections is situated behind the
terminal cover. Two utility seals in the fixing screws of the terminal cover
prevent unauthorised access to the phase connections and therefore also
prevent unrecorded energy consumption.
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Terminal layout The top row of terminals (level 1) consists of spring-loaded terminals and
(example ZMD300xT) comprises
Extension board terminals on the left
Depending on the version, up to 4 control inputs or 6 output contacts, 3
digital inputs and 2 relays outputs or a combination of these with
maximum 6 inputs and outputs, or voltage connections for a separate
supply
Communication unit terminals on the right
The centre row of terminals (level 0) likewise consists of spring-loaded
terminals and comprises
Voltage outputs U1, U2, U3 and N, tapped from the relevant phase
input
3 fixed control inputs with a common return line G (electrically isolated)
2 output contacts for transferring fixed valency pulses or control
signals (electrically isolated)
The lower row of terminals comprises the phase connections with input and
output of the circuit for each phase with the voltage connection in between
and neutral conductor at far right.
Inputs and/or Pulse Communication
output contacts of inputs interfaces
extension board Communication unit
Control inputs and
U1 U2 U3 N output contacts
Voltage outputs
L1 L2 L3 N
Phase connections
Figure 29. Terminal layout ZMD300xT
3.4 Connection diagrams (examples)
Binding connection diagrams
The following connection diagrams should be considered examples. The
connection diagrams provided at the rear of the front door and visible when
the door is open are always binding for the installation.
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ZMD300xT
for three-phase
four-wire networks
Figure 30. Connection diagram of measuring unit ZMD300xT
In case the ZMD300 is used in a 3-wire network without neutral:
For a 3-phase, 3-wire connection, the measurement of phase-to-neutral
voltage as well as the measurement of single-phase energy have no
meaning, as no neutral voltage is supplied to the meter.
Control inputs / Basic version:
output contacts 3 control inputs
2 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 31. Connection diagram fixed control inputs/output contacts
Extension board Extension board 4200:
4200 4 control inputs
2 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 32. Connection diagram extension board with 4 control inputs and 2 output
contacts
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Extension board Extension board 2400:
2400 2 control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 33. Connection diagram extension board with 2 control inputs and 4 output
contacts
Extension board Extension board 0600:
0600 no control inputs
6 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 34. Connection diagram extension board with 6 output contacts
Extension board Extension board 0450:
0450 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 35. Connection diagram extension board with auxiliary power supply and 4
output contacts
Extension board Extension board 0460:
0460 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 36. Connection diagram extension board with auxiliary power supply and 4
output contacts
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Extension board Extension board 0470:
0470 with auxiliary power supply
no control inputs
4 output contacts (solid-state relays)
Signal allocation and numbering of
terminals for free parameterisation
Figure 37. Connection diagram extension board with auxiliary power supply and 4
output contacts
Extension board Extension board 3260:
3260 with auxiliary power supply
3 control inputs
2 relay outputs (8 A)
G + - Signal allocation and numbering of
terminals for free parameterisation
50 51 52 53 15 16 17 18 61 64
Figure 38. Connection diagram extension board with auxiliary power supply,
3 control inputs and 2 relay outputs
Ground terminal connection
Please note that the Ground terminal (G) of the control inputs on the
extension boards is NOT internally connected to the Ground terminal on the
base. If the Ground level is the same, then an external wire must be
connected between the two Ground terminals.
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3.5 Dimensions
75
extended hook: 230
standard hook: 206
190
26
40
150
177
Figure 39. Meter dimensions (Standard terminal cover)
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4 Installation and uninstallation
This section describes the installation and connection of meters for direct
connection. In addition, the necessary steps for checking the connections,
commissioning of the meter and the final functional check are described as
well as the uninstallation.
Dangerous voltage
Dangers can arise from live electrical installations to which the meters are
connected. Touching live parts is dangerous to life. All safety information
should therefore be strictly observed without fail.
4.1 Basic information for connecting meter
It is recommended to use the following circuits whenever possible for
connecting the meter to the various voltage levels.
4.1.1 Connection with 3 phases and neutral
L1 L2 L3 N
Connecting
fuses
Consumer
1 2 3 4 6 7 9 10 11 12
fuses
Loads
Figure 40. Connection with 3 phases and neutral
Neutral The neutral is normally looped through terminals 10 and 12. Some power
supply companies, however, make a simple connection between terminal
10 or 12 and the neutral. This avoids possible contact errors in the neutral
conductor.
4.1.2 Connection with 3 phases without neutral (Aron circuit)
A version ZFD300xT for the rarely encountered three-phase networks
without neutral with 3 x 230 V is not available.
4.2 Mounting the meter
Dangerous voltage on conductors
The connecting conductors at the point of installation must be voltage-free
for installation of the meter. Contact with live components is dangerous to
life. The relevant supply fuses should therefore be removed and kept in a
safe place until finishing work, so that they cannot be re-inserted by other
persons unnoticed.
When you have identified the correct meter position for mounting the meter,
it should be mounted as follows on the meter board or similar device
provided for this purpose:
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1. Determine the desired form of fixing (open/covered meter mounting or
extended suspension hook for 230 mm suspension triangle height). If
holes for a suspension triangle height of 230 mm are already present,
use the optional extended suspension hook depicted below. This
hook can be ordered with the part number 74 109 0072 0 (minimum
order quantity 50) from:
Landis+Gyr AG
Service & Repair
Theilerstrasse 1
CH-6301 Zug
Switzerland
Figure 41. Extended suspension hook for installations with 230 mm
suspension triangle height
2. Either set the meter suspension hook in the relevant position as shown
below or replace the suspension hook with the extended hook by lifting
the latch slightly and pulling out the shorter hook. Insert the extended
hook into the grooves in the same way the shorter hook was inserted
(bent towards rear) and push it down until it clicks into place.
Figure 42. Positioning of meter suspension eyelet
3. Check with a phase tester or universal measuring instrument whether
the connecting wires are live. If so, remove the corresponding supply
fuses and keep them in a safe place until installation is completed, so
that they cannot be replaced by anyone unnoticed. Open the voltage
connections at the test terminal block with an insulated screwdriver
and check whether the short-circuit jumpers of the circuit are closed.
4. In case there are no holes provided, e.g. as in the case with the 230
mm suspension triangle: Mark the three fixing points (suspension
triangle as in following illustration) on the mounting surface provided:
– horizontal base of suspension triangle = 150 mm
– height of suspension triangle for open mounting = 206 mm
– height of suspension triangle for covered mounting = 190 mm
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206 or 190 mm respectively
75 mm
150 mm
Figure 43. Drilling plan
5. Drill the three holes for the fixing screws.
6. Unscrew the meter terminal cover.
7. Fit the meter with the three fixing screws on the mounting surface
provided.
4.3 Connecting meter
Dangerous voltage on conductors
The connecting conductors at the point of installation must be voltage-free
for installation of the meter. Contact with live components is dangerous to
life. The relevant supply fuses should therefore be removed and kept in a
safe place until finishing work, so that they cannot be re-inserted by other
persons unnoticed.
Connecting conductor cross-section
ZMD310CT meters with a maximum current of 100 or 120 A require
connecting conductors of 35 mm² cross-section. Owing to the terminal
opening of 9.5 mm, only cable is possible.
The electrical connections to the meter should be made as follows
according to the connection diagram:
1. Check with a phase tester or universal measuring instrument whether
the connecting wires are live. If so, remove the corresponding supply
fuses and keep them in a safe place until installation is completed, so
that they cannot be replaced by anyone unnoticed.
Connecting the phase connection lines
1. Shorten the phase connecting wires to the required length and then
strip them.
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2. Insert the phase connecting wires in the relevant terminals (the
terminals are numbered as shown in the connection diagram) and
tighten the terminal screws firmly (torque 3 to 5 Nm).
With small conductor cross-sections (e.g. 4 mm²) the connecting line
must be placed in the indentation (stamping) of the current loops, so
that it cannot shift sideways when tightening the terminal screws.
Ensure that the connecting line remains in the indentation when
tightening.
Indentation (stamping) for smaller connection lines
Current loop conductor
Figure 44. Cross-section through current loop conductor
If smaller connection lines are used, it's possible to adapt the cable
section with terminal holes using "assembling aids" or "centering parts"
in order to have a safe connection:
P000225650 (x100 pcs) – 8.5 mm
P000172980 (x100 pcs) – 9.5 mm
Please contact your sales representative for ordering.
It is recommended to identify the beginning and end of the relevant
conductors with a suitable test unit (e.g. buzzer) to ensure that the
right consumer is connected to the meter output.
Inputs and/or Pulse Communication
output contacts of inputs interfaces
extension board Communication unit
Control inputs and
U1 U2 U3 N output contacts
Voltage outputs
L1 L2 L3 N
Phase connections
Figure 45. Meter connections (example ZMD300xT)
Power losses at the terminals
Insufficiently tightened screws at the phase connections can lead to
increased power losses at the terminals and therefore to undesirable
heating. A contact resistance of 1 mΩ causes a power loss of 10 W at 100
A!
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Connecting the signal inputs and outputs
Maximum current at auxiliary terminals
The circuits connected to the auxiliary terminals must be built in such a way
that the maximum current is never exceeded, as this might damage the
meter.
Maximum current of the voltage outputs: 1 A.
Maximum current of the output contacts: 100 mA.
Use fuses or protective relays between external and internal circuits to
avoid defects and a possible exchange of the meter.
1. Shorten the connecting wires of the signal inputs and outputs to the
required length and strip them for approx. 4 mm (wires and strands up
to 2.5 mm² can be connected).
Use ferrules with stranded wires
If stranded wire is used, provide it with ferrules for connection.
2. Connect the connecting wires of the signal inputs and outputs as
follows to the screwless spring-loaded terminals (the terminals are
numbered as shown on the connection diagram):
– Insert a size 1 screwdriver in the upper opening and insert it turning
slightly upwards (figure 46 A).
– Now place the stripped connecting wire in the lower opening and
hold it there securely (figure 46 B).
– Withdraw the screwdriver. The connecting wire is then firmly fixed
(figure 46 C).
Figure 46. Connection in screwless spring-loaded terminals
Bare end of connecting wire must not be too long
The insulation of the connecting line must extend as far as the terminal
indentation, i.e. there must be no further bare part of the connecting line
visible above the terminal edge (as shown in figure 46 C). Touching live
parts is dangerous to life. The stripped part of the connecting wire should
be shortened if necessary.
Only one wire or ferrule per terminal
Only one wire or ferrule with strand(s) may be connected in screwless
spring-loaded terminals. The terminal could otherwise be damaged or the
contact not properly made.
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If a connecting wire must be disconnected again for any reason, this is
performed in the reverse sequence:
Figure 47. Releasing connection from spring-loaded terminal
Damage to terminals
Never withdraw connecting wires with the terminal closed, since this could
damage the terminal.
4.3.1 Connecting the RS485 interface
If you connect the RS485 interface you must not strip back the shielded
cables, e.g. to connect the individual wires to an external terminal block
(see figure below), as this considerably increases the likelihood of
interference.
Figure 48. How to connect RS485 correctly
It is also possible to use RS485 distributors instead of connecting the
RS485 cables directly to the meter.
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4.4 Check of connections
Effects of connection errors
Only a properly connected meter measures correctly!
Every connection error results in a financial loss for the power company!
Before putting into operation, check again whether all meter connections
are connected correctly according to the connection diagram.
4.5 Commissioning, functional check and sealing
Dangerous voltage on conductors
The supply fuses must be re-inserted before commissioning and functional
check of the meter. If the terminal cover is not screwed tight, there is a
danger of contact with the connection terminals. Contact with live
components is dangerous to life. The relevant supply fuses should
therefore be removed before making any modifications to the installation
and these kept in a safe place until completing the work to prevent anyone
re-inserting them unnoticed.
Prerequisites for commissioning and functional check
If no mains voltage is present, commissioning and functional check must be
performed at a later date.
The installed meter should be put into service and checked as follows:
1. Insert the supply fuses removed for installation. The meter is switched
on.
2. Check whether the operating display is correct (no error message).
3. Check on the display whether all three phases L1, L2 and L3 are
indicated and show the right phase sequence.
– If one phase is not present or less than 20 V, then the relevant
symbol is absent.
– With the normal phase sequence L1-L2-L3 the symbols are dis-
played continuously.
– If, however, the meter is connected with reversed phase sequence
(e.g. L2-L1-L3) the symbols flash. The direction of field rotation
(clockwise or anticlockwise) is determined by the parameterisation.
This has no influence on the measuring behaviour of the meter.
Figure 49. Phase sequence indication
4. Remove all supply fuses.
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5. Insert the supply fuse of phase 1 and check the display of the energy
direction: +P to right. If the energy direction arrow P points to the left,
the input and output of phase 1 are interchanged. If the meter displays
no energy direction, the calibration link is open, the supply fuse is
defective or the neutral is not connected.
6. Remove the supply fuse of phase 1 again.
7. Repeat the same test for the other phases as in points 5 and 6.
8. You can now check further values such as phase voltages. This is
preferably done with MAP110 or, if parameterised, via the service list,
which you can reach via the service menu.
9. Check the tariff displays and switch the control voltages to the tariff
inputs on and off. The arrow symbols of the tariff display must change.
10. If the meter is connected to a meter readout system via the electrical
interface, check the data transmission.
11. If a GSM modem is connected to the meter, the SMS transmission
function should be checked by sending a test SMS message according
to the instructions found in the respective application note or user
manual, e.g. to your own mobile telephone.
12. Mount the terminal cover if the meter is operating correctly. Otherwise
first locate and eliminate the error.
13. Seal the terminal cover with two utility seals.
14. Set the current date and time with the relevant formatted command
(see section 5.8 "Input of formatted commands") or in the set mode
(see section 5.9 "Set time and date, ID numbers, battery time").
15. Close the front door.
16. Re-seal the front door.
4.6 Installation of terminal cover detection
1. Ensure that control input 1 has been parameterised for this function.
2. Connect cables 1 and 2 to terminal according to the figure below.
1
3 2
Figure 50. Connection of cables of cover detection unit
3. Fix terminal cover detection unit to meter. See figure below.
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Figure 51. Fixing of cover detection unit to meter
4. Connect cable 3 as shown above.
4.7 Uninstallation
Dangerous voltage on conductors
The connecting wires at the place of installation must not be live when
removing the meter. Touching of live parts is dangerous to life. Remove the
corresponding supply fuses and keep these in a safe place until work is
completed, so that they cannot be replaced by anyone unnoticed.
The meter should be removed as follows:
1. Remove the two utility seals at the screws of the terminal cover.
2. Release the two screws of the terminal cover and remove it.
3. Check that the connecting wires are not live using a phase tester or
universal measuring instrument. If they are live, remove the
corresponding supply fuses and keep these in a safe place until work
is completed, so that they cannot be replaced by anyone unnoticed.
4. Remove the connecting wires of the signal inputs and outputs from the
screwless spring-loaded terminals as follows:
– Place a size 1 screwdriver in the upper opening and insert it turning
slightly upwards (figure 52 A).
– Then draw the wire from the lower opening (figure 52 B).
– Withdraw the screwdriver (figure 52 C).
Figure 52. Removing connections in screwless spring-loaded terminals
Damage to terminals
Never withdraw connecting wires from closed terminals. The terminals
could be damaged.
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5. Release the terminal screws 1, 3, 4, 6, 7, 9, 10 and 12 of the phase
connecting wires with a suitable screwdriver and withdraw the phase
connecting wires from the terminals.
6. Fit a substitute meter as described in section 4.3 "Connecting meter"
and the following sections.
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5 Operation
This section describes the location and function of all operating elements
and displays of the E650 ZMD300xT meters as well as operating sequences.
Illustrations
The illustrations of the faceplate and display in this section always show the
ZMD300CT combi-meter (with additional optical test output for reactive
energy, together with direction of reactive power and quadrant display).
5.1 Operation with auxiliary power supply
Meters equipped with an auxiliary power supply which is supplied with
electricity (see section 3.4 "Connection diagrams (examples)") are
completely functional even in case of a power cut. Despite missing voltage
at the terminals they can be read out via display, remote readout, etc. and
parameterised, if desired.
Connect the auxiliary power supply as follows:
1 2 3 4
Figure 53. Auxiliary power supply connections
Type 045x: 1 and 2: 100–240 V AC/DC
Type 046x: 1: + (12–24 V DC)
Type 046x: 2: – (12–24 V DC)
Type 326x: 3: + (12–24 V DC)
Type 326x: 4: – (12–24 V DC)
5.2 Control elements
E650 meters have the two display buttons "down" and "up" and a reset
button as conventional operating elements. The display can also be
controlled with the aid of a light source via the optical interface.
5.2.1 Display buttons
The two display buttons "down" and "up" are placed on the main faceplate
(top) on the right of the liquid crystal display.
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Landis+Gyr E650
Readout
imp imp Cl. 1
Cl. 1 kvarh
1000 kWh
Three-phase four-wire meter
ZMD310CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 10(80) A 50 Hz
20XX
Display key
"up"
Display key
"down"
T1 T2 T3 SET Test
Figure 54. Display buttons
By pressing the lower display button "down", the display changes to the
next value in the list. By pressing the upper display button "up", the display
changes to the previous value (also see section 5.4.2 "Display menu").
5.2.2 Control of display via optical interface
All E650 meters have an "optical button" in addition to the "up" and "down"
display buttons. The optical interface serves to receive a light signal, e.g.
generated by a torch (works only with warm light, i.e. LED torches cannot
be used for this). The light signal acts like the "down" display button and
controls the display in one direction from one value to the next. This type of
display control only functions when voltage is supplied to the meter.
The reader can also control the display at a distance from the meter
depending on the light intensity from the source, e.g. through a protective
glass in front of the meter.
5.2.3 Reset button
The reset button is situated to the right of the battery compartment behind
the front door. To permit operation of the reset button the front door must
be opened and therefore the utility seal be removed.
The reset button can be used to perform a manual reset. If the display
check is displayed (after operation of a display button), however, pressing
the reset button produces the service menu (also see section 5.4.3 "Service
menu").
Figure 55. Reset button behind front door
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5.3 Display
5.3.1 Introduction
E650 meters are provided with a liquid crystal display (LCD).
The display can be provided with background lighting for easier reading
(optional). This is switched on by pressing one of the display buttons and is
extinguished automatically after a short time if no further button is pressed.
5.3.2 Basic layout
The basic layout shows all the indication possibilities of the display.
Figure 56. Basic layout of the liquid crystal display (LCD)
1 Active power direction (+P: import, -P: export)
2 Reactive power direction (not used with ZMD300AT)
3 Phase voltages (flash if rotating field reversed)
4 Battery status (charge voltage)
5 Units field
6 Index field (8 digits)
7 Value field (8 digits)
8 12 arrow symbols for status information (e.g. tariffs)
Active power direction Shows always the sum of the three phases:
positive active energy direction (imported from power
company)
negative active energy direction (exported to power
company)
negative active energy direction of individual phases
(second arrow flashes).
Reactive power Indicates for combi-meters ZMD300CT always the sum of the three phases (not
direction used for active energy meters ZMD300AT).
positive reactive energy direction
negative reactive energy direction
Quadrant display Indicates for combi-meters ZMD300CT in which quadrants the present
measurement is made (not used for active energy meters ZMD300AT):
1st quadrant
2nd quadrant
3rd quadrant
4th quadrant
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Phase voltages Indication of presence of phase voltages.
If the rotating field corresponds to the parameterised,
symbols L1, L2 and L3 are continuously lit. Otherwise
they flash every second.
Battery condition The symbol appears if the charge voltage of the battery
fitted is too low (provided the meter is parameterised as
"fitted with battery").
Units field The following units are shown:
W, var, VA, k..., M..., ...h, V, A, h, Hz, m³
(var and VA only for combi-meters)
Index field Up to 8-digit indices are displayed, which define
the value in the value field.
Value field Up to 8-digit values are displayed.
Arrow symbols An arrow symbol is an additional status indication for tariff
rates, reset block, test mode, etc. The arrow points to a
status description on the faceplate.
5.3.3 Index system
The information concerning which data are shown in the display is made
with an index system and is supported by the unit over the value field.
The 8-digit index field permits all currently known index systems such as
DIN, LG, VEOe, OBIS, etc.
The B:C.D.E.F structure applies to OBIS (Object Identification System):
B Defines the channel number, i.e. the number of the input of a metering
device having several inputs for the measurement of energy of the
same or different types (e.g. in data concentrators, registration units).
This enables data from different sources to be identified.
C Defines the abstract or physical data items related to the information
source concerned, e.g. active power, reactive power, apparent power,
cosφ, current or voltage.
D Defines types, or the result of the processing of physical quantities
according to various specific algorithms. The algorithms can deliver
energy and demand quantities as well as other physical quantities.
E Defines the further processing of measurement results to tariff
registers, according to the tariff rates in use. For abstract data or for
measurement results for which tariffs are not relevant, this value group
can be used for further classification.
F Defines the storage of data according to different billing periods. Where
this is not relevant, this value group can be used for further classification.
To simplify reading of the index field, individual parts of the OBIS code can
be omitted. The abstract or physical data C and type of data D must be
shown.
For further details about OBIS code see Appendix 1.
Examples 1.8.0: 1 = Active energy import (all phases); 8 = Status; 0 = Total
0.9.1: Local time
Reference is made for examples to the following display list and the
readout log (see section 5.7 "Data readout")
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5.4 Types of display
The ZMD300xT has the following three types of display:
Operating display The values specified by the parameterisation are shown as a rolling display
in the operating display. The display is always in operating mode when the
display buttons are not operated. The meter returns automatically from the
display list to the operating display after a defined time. This display can
consist of one or more values.
Display menu By pressing the display button, the display check is activated, and from
there the user reaches the display menu by pressing the display button
again. From the display menu, values of the display list, the load profile(s),
the event log, etc. can be accessed. The values of the display list and also
the sequence can be parameterised. The display buttons permit scrolling
up and down in the list.
Service menu The user reaches the service menu by pressing the reset button starting
from the display check. From the service menu, values of the service list,
the set mode, etc. can be accessed. The service list, for example, is an
extended display list with additional values.
5.4.1 Operating display
The values always displayed are considered the operating display. This can
be parameterised as a fixed display (only one value present, e.g. the
present tariff rate) or as a rolling display (several values alternate at a fixed
rate, e.g. every 15 seconds).
running average demand
value with status of
integrating period
Figure 57. Example of a fixed display
Error message The meter can generate an error message on the basis of self-tests.
According to parameterisation, this can be permanently included in the
operating display. In the event of a serious error (fatal or critical error), it
replaces the normal operating display. After a fatal error, the meter no
longer operates and must be replaced. In case of a critical error, the error
message can be acknowledged with the display button.
Figure 58. Example of an error message (insufficient battery voltage)
In case of an error message the procedure described in section 6.2 "Error
messages" should be followed.
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5.4.2 Display menu
Figure 59. Display menu overview
Display check Brief operation (< 2s) of the display button "down" or "up" causes a change
of the operating display, e.g.:
to the display check:
All segments of the display are active here. The index and value fields
should be checked each time for missing segments. This can prevent
incorrect readings.
Display menu Pressing the display button "down" or "up" again briefly changes to the
display menu or directly to the display list. The first menu item appears, e.g.
"Display list" (standard data):
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The menu item only appears when several menu items exist. Otherwise
direct entry is made to the display list.
The next menu item appears for every further brief operation of the "down"
display button, e.g. "Data profile", "Event log", etc. The first menu item
appears again after the last item.
The preceding menu item is displayed again by briefly pressing the "up"
display button.
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from any display menu.
Value display The first value of the list associated with the present menu is displayed by
pressing the display button "down" or "up" for longer (at least 2 seconds),
and is normally the error message:
The next list value appears for every further brief operation of the "down"
display button. Brief operation of the "up" button again displays the
preceding value. The sequence of values in the list is determined by the
parameterisation.
A rapid run is started by holding down the display button "down" or "up" for
longer (at least 2 seconds). The main values of the list are then displayed
while the button remains pressed, but no stored values.
Examples of values in a display list:
Reset counter
Date of resetting
stored value 03 (March)
Cumulated maximum
demand
active power
rate 1
Active energy
present status
rate 1
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Reactive energy
present status
rate 1
Battery hours counter
Status of signals at
control terminals
Number of total voltage
failures
To return to the menu level from the list at the end of the display list press
the display button "down" or "up" for longer (at least 2 seconds).
Load profile 1 The load profile 1 menu item for selection in the display menu (denoted
P.01) is shown as follows:
The first value of the load profile 1 is displayed by pressing the display
button "down" or "up" for longer (at least 2 seconds).
Load profile 2 The load profile 2 menu item for selection in the display menu (denoted
P.02) is shown as follows:
The first value of the load profile 2 is displayed by pressing the display
button "down" or "up" for longer (at least 2 seconds).
Event log The event log menu item for selection in the display menu (denoted P.98)
is shown as follows:
The first entry in the event log is displayed by pressing the display button
"down" or "up" for longer (at least 2 seconds).
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5.4.3 Service menu
Figure 60. Service menu overview
Service menu Pressing the reset button during the display check changes the display to
the service menu or directly to the service list. The first menu item appears,
e.g. the service list:
The menu item only appears if there are several items present. Otherwise
pressing the reset button directly leads to the values of the service list.
The next menu item appears for every further brief operation of the "down"
display button, e.g. "Set mode", "Test mode on/off", etc. The first item
appears again following the last menu item "End".
The preceding menu item appears again by pressing the "up" button
briefly.
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from the service menu.
Value display The first value of the list associated with the present menu is displayed by
pressing the display button "down" or "up" for longer (at least 2 seconds).
The next list value appears for every further brief operation of the "down"
display button. Brief operation of the "up" button again displays the
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preceding value. The sequence of values in the list is determined by the
parameterisation.
A rapid run is started by holding down the display button "down" or "up" for
longer (at least 2 seconds). The main values of the list are then displayed
while the button remains pressed, but no stored values.
To return to the menu level from the list at the end of the display list press
the display button "down" or "up" for longer (at least 2 seconds).
Both display buttons ("down" and "up") must be pressed simultaneously to
return to the operating display from the list.
Set mode Values can be changed in the set mode with the aid of the reset button and
display buttons (for setting time and date, identification numbers, battery
hours counter, etc.). The procedure is described in section 5.9 "Input of
formatted commands".
5.5 Alert LED
The red alert LED (optional) on the main faceplate indicates that certain
event(s) have occurred. Which event(s) trigger the alert LED can be set by
parameterisation.
Landis+Gyr E650
Readout
imp imp
Alert LED Cl. 1 kvarh
1000 kWh Cl. 1
Three-phase four-wire meter
ZMD310CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 10(80) A 50 Hz
20XX
T1 T2 T3 SET Test
Figure 61. Alert LED
5.6 Optical test output
The optical test outputs – one for active energy in all meters and a second
for reactive energy in combi-meters – are fitted in the main faceplate above
the liquid crystal display.
Optical
test output
Landis+Gyr E650
Readout reactive energy
Cl. 1
imp
kvarh
1000
imp
kWh
Cl. 1 (combimeters
Three-phase four-wire meter only)
ZMD310CT44.4207 S3 Nr. XX XXX XXX
3 x 230/400 V 10(80) A 50 Hz
20XX
Optical
test output
active energy
T1 T2 T3 SET Test
Figure 62. Optical test outputs
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The optical test outputs are used for testing the meter (also see section 7.1
"Meter testing"). They transmit visible red pulses corresponding to the
current measured values (active and reactive energy).
5.7 Data readout
The energy supply company can record the data stored locally in the meter
at any time in two ways:
Reading the liquid crystal display of the meter. The displayed data is
defined by parameterisation.
Automatic data readout via the optical interface with a readout device
(e.g. laptop).
Readout data
For readout to IEC 62056-21, all data determined by the parameterisation
are read out in the specified sequence.
For readout according to DLMS (Device Language Message Specification),
the data requested by the readout unit are read out.
If the meter is fitted with the appropriate communication unit (see
associated separate operating instruction), remote readout of the meter
data is also possible.
Procedure for data readout via optical interface
1. Start the readout device (according to the details in the associated
operating instructions).
2. Connect the cable of the reading head to the readout device.
3. Place the reading head in the "Readout" indentation on the plastic
viewing window of the meter. The reading head cable must point to-
wards the terminal cover (when mounted vertically downwards). The
reading head is held magnetically.
4. Start the data readout on the readout device (according to the details
in the associated operating instructions).
5. Remove the reading head from the meter again after completing the
readout.
5.7.1 Readout to IEC 62056-21
The data read out according to IEC 62056-21 are recorded in the form of
the example shown below. The quantity and sequence of values in the log
is determined by parameterisation.
Log example Significance
/LGZ4\2ZMD3104100 Designation of meter
(reply on transmit request)
F.F (00000000) Error message
0.0.1 (417242) 1st identification number
0.1.0 (28) Number of resets
0.1.2.04 (98-05-01 00:00) Time of last reset
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1.2.1 (26068.7*kW) Pmax cumulated Rate 1
1.2.2 (15534.8*kW) Pmax cumulated Rate 2
1.6.1 (192.4*kW)(00-05-06 10:45) Pmax present Rate 1
1.6.1*04 (202.4)(00-04-22 09:30) with April stored value 1) Rate 1
1.6.2 (086.7*kW)(00-05-04 22:30) Pmax present Rate 2
1)
1.6.2*04 (100.9)(00-04-14 23:00) with April stored value Rate 2
1.8.1 (0244948*kWh) Active energy (import) Rate 1
1)
1.8.1*04 (0234520) with April stored value Rate 1
1.8.2 (0082520*kWh) Active energy (import) Rate 2
1)
1.8.2*04 (0078197) with April stored value Rate 2
5.8.1 (0106103*kvarh) Reactive energy (inductive) Rate 1
5.8.1*04 (0100734) with April stored value 1) Rate 1
5.8.2 (0039591*kvarh) Reactive energy (inductive) Rate 2
1)
5.8.2*04 (0036152) with April stored value Rate 2
1.8.0 (0327468*kWh) Total active energy
5.8.0 (0145694*kvarh) Total reactive energy (inductive)
8.8.0 (0001452*kvarh) Total reactive energy (capacitive)
0.9.1 (14:18:06) Time-of-day of readout
0.9.2 (00-05-20) Date of readout
C.7.0 (00087) No. of voltage failures of all phases
C.72.0 (00157) Number of under-voltages
C.73.0 (00000) Number of over-voltages
C.74.0 (00306) Number of over-loads (over-current)
C.3.0 (500) Active pulse constant
C.3.1 (500) Reactive pulse constant
C.2.1 (00-03-26) Date of last parameterisation
! End of log
1)
If the sequence is parameterised as month.
Notes By parameterisation, the energy supply company can select between a
standard identification and its own identification. The standard identification
has the following structure:
/LGZ... Manufacturer (Landis+Gyr)
/LGZ 4... Transmission rate 4 = 4800 bps
/LGZ4 \2... Extended communication possibility
2 = DLMS-compatible meter
/LGZ4\2 ZMD310... Meter Type of measuring unit
/LGZ4\2ZMD310 41... Basic version tariff section
/LGZ4\2ZMD31041 00... Additional functions
(auxiliary power supply)
/LGZ4\2ZMD3104100 .B32 Firmware version
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Stored values The hyphen following the identification
number and the rate (1.6.1) denotes the
type of resetting:
e.g. 1.6.1*04 *04 Resetting made internally or
remote controlled
e.g. 1.6.1&04 &04 Resetting performed manually
The identification by the energy supply company itself uses an identification
number. ID1.1 (designation of ownership by the energy supply company),
ID1.2 (any desired number) or ID2.1 (serial number) are available. The
identification is comprised as follows in this case:
/LGZ... Manufacturer (Landis+Gyr)
/LGZ 4... Transmission rate 4 = 4800 bps
/LGZ4 \2... Extended communication possibility
2 = DLMS-compatible meter
/LGZ4\2 \B32... Meter Firmware version
/LGZ4\2\B32 12345678 Identification number specified
by parameterisation (maximum
8 characters)
5.7.2 Readout to DLMS
While the readout according to IEC 62056-21 uses a predefined protocol,
readout to DLMS enables the power supply company to read out values
individually. The company therefore has systematic access to specific
values without being influenced by other values that are not required.
DLMS specification Various meter manufacturers – including Landis+Gyr – together with
related organisations, have compiled the language specification DLMS
(Device Language Message Specification).
Objective The objective of DLMS is to use a common language for data exchange in
energy measurement and other sectors. In addition to end units such as
meters, tariff units, etc. DLMS also defines the interfaces, transmission
channels and system software.
Principle DLMS delivery oriented protocol can be compared to sending a letter: the
sender writes the address of the recipient on the letter and hands it to the
post office for transport. The way in which the postal department transports
the letter is of no consequence to the sender and receiver. The only
important thing is that the address of the recipient is clearly shown and that
the letter is received, read and it can be seen from whom the letter
originates.
Units with DLMS operate in a similar way. They provide the values –
termed objects – required by the receiver (e.g. control centre) and pass
them via interface to the transport medium (channel). How the values reach
the recipient is again immaterial for both parties.
DLMS items DLMS is an object-oriented language. The DLMS objects
have an unique name in the form of the EDIS identification number
contain the value in an exactly defined form and
are configured in a similarly exactly defined format.
Examples are number of resets with date and time, cumulative maxima,
rolling mean values, maxima, energy status, associated stored values, etc.
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The sender feeds these objects to a transport medium, e.g. the telephone
network. This transmits them to the receiver, so that the objects are
received in the same form as supplied by the sender.
5.8 Input of formatted commands
The following operating data or meter characteristics can be modified by
the input of formatted commands. The user of formatted commands,
however, must have the necessary access authorisation according to the
security system.
The following commands can be used both according to IEC 62056-21 and
also with DLMS:
Set time/date
Set identification numbers for the energy supply company and for the
manufacturer (by line).
Reset
Neutralise reset inputs KA/KB
Set/reset reset counter
Control tariff rates via interface
Set/reset energy registers
Set/reset total energy registers
Set/reset demand maximum registers
Set/reset power factor registers
Reset stored values
Reset battery hours counter
Reset voltage failures registers
Switch on/off increased resolution (test mode) of energy registers
Define by additional parameters whether the optical test output for
active energy in test mode supplies active or reactive energy pulses
Delete error messages
Change passwords P1,P2 and W5
Reset load profile 1 / load profile 2
Reset event log
Reset dedicated event log groups
The following commands can only be executed with DLMS:
Reset event register
– Under- and over-voltages
– Demand messages
– Current messages
– Power factor messages
Set thresholds for messages
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Formatted commands are transferred to the meter with a suitable device
via the optical interface or via an interface circuit of the communication unit.
5.9 Set time and date, ID numbers, battery time
The following values can be changed at any time from the service menu
(set mode):
Date and time
Identification numbers
Operating time of battery
Below is an example on how to set the date and time.
Operating
display
1. All segments of the Display check
display are lit
2. Enter service menu Set mode
R
3. Enter set mode Identification
number
4. Select required Date, old
setting value
5. Select digit to be Digit flashes
R changed
6. Change digit value Digit flashes
7. Select digit to be Next digit
R changed flashes
8. Repeat steps 5 – 7 for all digits to be changed. All digits flash
9. Confirm new Date, new
R setting value
10. Repeat steps 4 – 9 for all settings to be changed.
11. Advance display End of set
until End mode
12. Back to service Service menu
menu
13. Advance display End of service
until End menu
14. Back to operating Operating
display display
15. Close and re-seal the front door.
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6 Service
This section describes the necessary servicing work after the appearance
of operating faults or error messages.
6.1 Operating faults
If the liquid crystal display is illegible or the data readout does not function,
the following points should first be checked:
1. Is the network voltage present (supply fuses intact and test terminals
closed)?
2. Is the maximum permissible ambient temperature exceeded?
3. Is the plastic viewing window over the faceplate clean (not scratched,
painted over, misted over or soiled in any way)?
Danger of short-circuits
Never clean soiled meters under running water or with high pressure
devices. Water penetration can cause short-circuits. If the meter is heavily
soiled, it should be uninstalled if necessary and sent to an authorised
service and repair centre, so that a new plastic viewing window can be
fitted.
If none of the points listed is the cause of the fault, the meter should be
disconnected, removed and sent to the responsible service and repair
centre (according to section 6.3 "Repairing meters").
6.2 Error messages
The meters regularly perform an internal self-test. This checks the correct
function of all important parts.
In case of a serious error detected (fatal or critical error according to
classification in the following degrees of severity), the meters displays an
error code. This error code appears as an eight-digit number together with
"F.F" or "FF" in the display (error code F.F 00000000 = no error).
Classification of The degree of severity of an error occurring is assessed as follows:
degree of severity
A fatal error indicates a severe problem, which prevents the meter
maintaining measuring operation, e.g. a defective hardware component.
The meter stops its operation and the error code is displayed permanently.
The meter must be exchanged.
A critical error indicates a severe problem, but with which the meter
continues to function and measurement is still possible. The data are stored
in the memory and suitably marked in case of doubt. After a critical error,
the error code is displayed until acknowledged with the display button or
until the error register is reset, e.g. via the electrical interface. Depending
on the type of the error this can cyclically occur again, since with the
acknowledgement the error cause is usually not repaired. The meter must
in this case be exchanged as soon as possible.
Non-critical errors can influence the meter functions (temporarily or
permanently). These errors are recorded in the error register. The meter
remains serviceable and normally needs not to be exchanged.
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Deleting error If nothing else is specified in the following description of the error groups,
messages the error messages can only be deleted with formatted commands (see
section 5.8 "Input of formatted commands"). If the error occurs again, the
meter should be removed and sent to the responsible service and repair
centre (according to section 6.3 "Repairing meters").
6.2.1 Structure of an error message
An error message has the following form:
Figure 63. Error message on E650 meters
All E650 meters use the same format for error messages. It consists of four
groups of 2 digits each, whereby the groups have the following significance:
Figure 64. Significance of error message
Each group has two digits written in hexadecimal notation and can there-
fore have the values 0 to 9 and letters A to F. Both digits each form the sum
of the individual values of 4 possible types of error as shown in the
following diagrams.
6.2.2 Error groups
Time-base errors
Group 1 of error messages
(clock) of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Low battery
Invalid clock
*
*
* * not used
*
*
*
Figure 65. Group 1 of error messages
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The first digit in the first group has no significance, since no error messages
are assigned to it.
The second digit can have values between 0 (no error message) and 3
(both error messages set). Significance:
F.F 01 00 00 00 Low battery (non-critical error)
The battery is missing or discharged. If there is no mains voltage at the
meter and the internal supercapacitor is discharged (after about 3 weeks)
then the calendar clock will stop.
The error is deleted automatically when the battery voltage has again
reached a sufficient value (e.g. after inserting a new battery as described in
section 7.2"Changing the battery").
This error message only appears if the meter is parameterised as "fitted
with battery". Otherwise there is no check of the battery condition.
The same applies to messages where the bit is set:
F.F 03 .. .. ..
F.F 02 00 00 00 Invalid clock (non-critical error)
The meter has found that the calendar clock has stopped at some time,
e.g. due to insufficient power reserve (battery low). The clock is running,
but shows the wrong time and/or date.
The error is deleted automatically when the time and date have been set
correctly by the relevant formatted command or manually in the set mode
(see section 5.8 "Input of formatted commands"). or section 5.9 "Set time
and date, ID numbers, battery time"). If necessary, replace the battery.
The same applies to messages where the bit is set:
F.F 03 .. .. ..
Errors for write/read
access Group 2 of error message
of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Main memory access error
Backup memory access error
Measuring system access error
Time device access error
Load profile memory access error
not used
Communication unit access error
not used
Figure 66. Group 2 of error messages
In the second group both digits can have values between 0 (no error
message) and F (all four error messages set). Significance:
F.F 00 x1 00 00 Main memory access error (fatal error)
This error message appears if the main memory could not be accessed
several times during the start-up of the meter.
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The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. x3/x5/x7/x9/xB/xD/xF .. ..
F.F 00 x2 00 00 Backup memory access error (non-critical error)
This error message appears if the backup memory could not be accessed
several times.
The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. x3/x6/x7/xA/xB/xE/xF .. ..
F.F 00 x4 00 00 Measuring system access error (non-critical error)
This error message appears in case of repeated failures when accessing
the measuring system, possibly because of a completely discharged
supercapacitor, which causes an incorrect start-up behaviour.
Power-up meter and wait for a short time, then clear error via
communication. If the error does not reoccur, it is recommended to equip
the meter with a battery. If the error reoccurs, replace the meter.
The same applies to messages where the bit is set:
F.F .. x5/x6/x7/xC/xD/xE/xF .. ..
F.F 00 x8 00 00 Time device access error (non-critical error)
The meter sets this message in the event of repeated failures when
accessing the time device. The calendar clock may display an invalid time
or date.
The error can be reset via communication. If it occurs repeatedly, the
meter must be exchanged.
The same applies to messages where the bit is set:
F.F .. x9/xA/xB/xC/xD/xE/xF .. ..
F.F 00 1x 00 00 Load profile memory access error (critical error)
This error message appears in case of repeated failures when accessing
the load profile memory.
Load profile data will be marked in the status code (bit 2 "corrupted
measurement" and bit 0 "critical error" set).
It may not be possible to access the load profile memory. The memory may
contain incorrect data. The meter must be exchanged.
The same applies to messages where the bit is set: F.F .. 5x .. ..
F.F 00 4x 00 00 Communication unit access error (non-critical error)
The meter sets this message in the event of repeated failures to access the
communication unit. Communication fails or is slow.
The error can be reset via communication. If it reoccurs, replace first the
communication unit, check the function again. If the error still occurs, the
meter must be exchanged.
The same applies to messages where the bit is set: F.F .. 5x .. ..
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Checksum errors
Group 3 of error messages
of E650 meters
Sum of values
8 4 2 1 8 4 2 1 Value in hexadecimal code
Program checksum error
Backup data checksum error
Parameter checksum error
Load profile 1 checksum error
Stored values checksum error
Event log checksum error
Calibration data checksum error
Load profile 2 checksum error
Figure 67. Group 3 of error messages
The first digit in the third group can have the value 0 (no error message) or
1 (error message set).
The second digit can have values between 0 (no error message) and F
(all four error messages set). Significance:
F.F 00 00 x1 00 Program checksum error (fatal error)
The meter does not operate and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x3/x5/x7/x9/xB/xD/xF ..
F.F 00 00 x2 00 Backup data checksum error (critical error)
This error message appears when the backup data checksum test fails.
Load profile data will be marked in the status code (bit 2 "corrupted
measurement" and bit 0 "critical error" set). The meter may contain
incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x3/x6/x7/xA/xB/xE/xF ..
F.F 00 00 x4 00 Parameter checksum error (critical error)
This error message appears when the parameter checksum test fails.
Load profile data will be marked in the status code (""bit 0 "critical error"
set). The meter may contain incorrect data and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. x5/x6/x7/xC/xD/xE/xF ..
F.F 00 00 x8 00 Load profile 1 checksum error (non-critical error)
Load profile 1 data of the defective memory area will be marked in the
status code (bit 2 "corrupted measurement" set).
The error can be reset via communication. Reset the load profile first
and then the error. If it occurs repeatedly, the meter must be replaced as
soon as possible.
The same applies to messages where the bit is set:
F.F .. .. x9/xA/xB/xC/xD/xE/xF ..
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F.F 00 00 1x 00 Stored values checksum error (critical error)
Data in the defective memory area will be marked in the status code (bit 0
"critical error" set).
The error can be reset via communication. If it occurs repeatedly, the
meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 3x/5x/7x/9x/Bx/Dx/Fx ..
F.F 00 00 2x 00 Event log checksum error (non-critical error)
Data in the defective memory area will be marked in the status code (bit 0
set).
The error can be reset via communication. If it occurs repeatedly, the
meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 3x/6x/7x/Ax/Bx/Ex/Fx ..
F.F 00 00 4x 00 Calibration data checksum error (critical error)
Data in the defective memory area will be marked in the status code (bit 0
"critical error" set).
The meter must be replaced as soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 5x/6x/7x/Cx/Dx/Ex/Fx ..
F.F 00 00 8x 00 Load profile 2 checksum error (non-critical error)
Load profile 2 data of the defective memory area will be marked in the
status code.
The error can be reset via communication. Reset the load profile first
and then the error. If it occurs repeatedly, the meter must be replaced as
soon as possible.
The same applies to messages where the bit is set:
F.F .. .. 9x/Ax/Bx/Cx/Dx/Ex/Fx ..
Other errors
Group 4 of error messages
of E650 meters
Sum of values
Value in hexadecimal code
Invalid power down
*
* * not used
*
Expired watchdog
Communication locked
Wrong EEPROM/Flash identifier
Wrong extension board
Figure 68. Group 4 of error messages
The first digit in the fourth group can have the values 0 to F.
The second digit can have values between 0 (no error message) and 1
(Invalid power down). Significance:
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F.F 00 00 00 x1 Invalid power down (non-critical error)
The meter has detected that the last data storage was not performed
correctly. The meter may contain incorrect data or may have lost data since
the last storage, i.e. for 24 hours maximum.
The error can be reset via communication. If it occurs repeatedly,
contact Landis+Gyr Customer Services.
F.F 00 00 00 1x Expired watchdog (non-critical error)
The microprocessor was restarted due to a disturbance (e.g. lightning). The
meter may lose all data recorded since the last storage, i.e. for 24 hours
maximum.
The error can be reset via communication. If it occurs repeatedly,
contact Landis+Gyr Customer Services.
The same applies to messages where the bit is set:
F.F .. .. .. 3x/5x/7x/9x/Bx/Dx/Fx
F.F 00 00 00 2x Communication locked (non-critical error)
This error indicates access attempts via the communication interface with
wrong passwords.
The error is automatically deleted after the inhibition time or at midnight.
The same applies to messages where the bit is set:
F.F .. .. .. 3x/6x/7x/Ax/Bx/Ex/Fx
F.F 00 00 00 4x Wrong EEPROM/Flash (fatal error)
Incorrect EEPROM/ Flash memory is installed in meter.
The meter does not operate and must be exchanged.
The same applies to messages where the bit is set:
F.F .. .. .. 5x/6x/7x/Cx/Dx/Ex/Fx
F.F 00 00 00 8x Wrong extension board (non-critical error)
Identification of extension board differs from that parameterised in the
meter.
The meter might not have the required functions such as data profile,
control inputs or output signals. The meter has to be exchanged.
The same applies to messages where the bit is set:
F.F .. .. .. 9x/Ax/Bx/Cx/Dx/Ex/Fx
6.3 Repairing meters
Meters must only be repaired by the responsible service and repair centre
(or manufacturer).
The following procedure should be adopted if a meter repair is necessary:
1. If the meter is installed, remove the meter as described in section 4.7
"Uninstallation" and fit a substitute meter.
2. Describe the error found as exactly as possible and state the name
and telephone number of the person responsible in case of inquiries.
3. Pack the meter to ensure it can suffer no further damage during
transport. Preferably use the original packing if available. Do not
enclose any loose components.
4. Send the meter to the responsible service and repair centre.
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7 Maintenance
This section describes the necessary maintenance work.
7.1 Meter testing
Meter tests should be performed at periodic intervals according to the valid
national regulations (either on all meters or on specific random samples). In
principle, the meters should be uninstalled for this purpose according to the
instructions in section 4.7 "Uninstallation" and replaced by a substitute
meter. The meter test can also be performed on the spot in certain
circumstances.
7.1.1 Test mode
The test mode permits increasing the resolution of the energy registers by 1
to 5 digits. This allows the energy supply company to carry out the so called
measuring unit test in a reasonably short time.
In test mode, the same registers shown as a rolling list in the operating
display are always displayed, but with high resolution and not rolling.
The energy registers comprise a total of 12 digits. A maximum of 8 digits,
however, is shown on the display. The effective number of digits shown and
the number of decimal places are determined by the parameterisation. For
the test mode, more decimal places are normally parameterised (maximum
5) to permit a quicker test of the transmission to the energy registers.
Figure 69. Display changeover normal mode – test mode
Changeover from normal to test mode and back is made by formatted
commands (see section 5.8 "Input of formatted commands") or manually in
the service menu.
In test mode, the optical test output for active energy can also provide
reactive energy pulses depending on the parameterisation. Reactive
energy pulses are supplied to this test output if the register shown on the
display represents a reactive energy register. Active energy pulses are
supplied for all other measured values shown as in normal operating mode.
Formatted commands can also be used to define whether the optical test
output for active energy in test mode should supply active or reactive
energy pulses, independent of the type of register shown on the display.
This permits changeover without manual intervention.
7.1.2 Measuring times
For technical reasons, greater measuring deviations can occur during
short-term measurements. It is therefore recommended to use sufficiently
long measuring times in order to achieve the required accuracy.
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Table of measuring times required at the optical test output:
ZMD300xT Measuring uncertainty
0.1 %
Un = 230 V Current 3P 1P 3P
Ib = 5 A % Ib cosφ=1 1 0,5
5 40 s 40 s 90 s
10 20 s 20 s 40 s
20 10 s 10 s 20 s
50 8s 8s 10 s
100 6s 6s 8s
1000 6s 6s 6s
2000 6s 6s 6s
2400 6s 6s 6s
3 P = universal
1 P = single-phase
7.1.3 Optical test output
The red optical test outputs on the meter above the LCD should be used for
meter testing. These supply pulses at a frequency dependent on the meter
constant R, whereby the rising edge is always decisive for the test.
Note that the digital signal processing provides a delay of 2 seconds
between the instantaneous power at the meter and the appearance of the
pulses at the optical test outputs. No pulses are lost.
The number of pulses per second for the desired power is obtained by
multiplying the meter constant R by the power in kW divided by 3600.
Example: Meter constant R = 1000
Power P = 35 kW
f-test output = R x P / 3600 = 1000 x 35 / 3600 = 10 imp/s
The optical test outputs are continuously lit at no-load.
Test mode The test mode enables you to select which measuring value (active,
reactive) is shown on the optical test output.
In the display, values for active, reactive and apparent energy are available.
Depending on parameter setting, the resolution of the display register can
be increased for faster testing. In the test mode, the resolution is increased
by one decimal point compared with the normal mode. A maximum of 5
decimal points is possible.
Operating
display
1. All segments of the Display check
display are lit
2. Enter service menu Set mode
R
3. Select test mode Test mode
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4. Enter test mode First value
5. Select required Value x
value
6. Repeat step 3 for all values to be tested
7. Exit test mode Operating
display
Examples
First value and value x are examples. The real values are defined in the
parameter settings and are the same as the operating display.
The measured values are displayed at the optical test outputs as shown in
the following table:
Test output Test output
Mode Register on Display
reactive active
Normal Some sort of register |R| |A|
mode
Test mode Reactive energy register |A| |R|
Active energy register or one of |R| |A|
not mentioned registers in this
table.
7.1.4 No-load test
A test voltage Up of 1.15 Un is used for the no-load test (creep test) to IEC
62053-21 (e.g. Up = 265 V with Un = 230 V).
Procedure:
1. Disconnect the meter from the network for at least 10 seconds.
2. Then switch on the test voltage Up and wait approx. 10 seconds. After
this time the energy direction arrows must disappear. The red optical
test outputs are permanently "lit".
3. Switch on test mode (high resolution).
4. The meter must not deliver more than one pulse during the no-load
test. Check the energy levels for changes in test mode. They must not
increase by more than the value of one pulse (see faceplate).
7.1.5 Starting test active part
Procedure:
1. Apply a load current of 0.1% of the base current Ib (IEC-meters) or
0.1% of the reference current Iref (MID-meters) – e.g. 5 mA with Ib=Iref=
5 A – and the voltage Un (three-phase in each case) and cosφ = 1.
The meter must remain in no-load.
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2. Increase the load current to 0.4% Ib (IEC-meters) or 0.4% Iref (MID-
meters) – e.g. 20 mA with Ib= Iref = 5 A. The energy direction arrow "P"
must appear within 10 seconds. The optical test output for active
energy consumption is no longer permanently "lit".
7.1.6 Starting test reactive part
Procedure:
1. Apply a load current of 0.1% of the basic current Ib (e.g. 5 mA with Ib =
5 A) and the voltage Un (three-phase in each case) and sinφ = 1. The
meter must remain in no-load.
2. Increase the load current to 0.4% Ib (i.e. 20 mA with Ib = 5 A). The
energy direction arrow "Q" must appear within 10 seconds. The optical
test output for active energy consumption is no longer permanently "lit".
7.2 Changing the battery
If the meter is provided with a battery, this must be changed if one of the
following events occurs:
The symbol appears on the display.
The battery has been in the meter for more than 10 years (preventive
servicing). It is recommended to note the date of insertion on the
battery. The 10 years depend on the product and on the age of the
battery when inserting it into the meter.
The battery operating hours counter indicates over 80,000 hours (can
be read under code C.6.0 in service mode).
The battery charge indicates less than 4.8 V (can be read under code
C.6.1 in service mode).
Meters with or without battery
Only meters parameterised as "fitted with battery" have the
and the battery operating hours counter.
symbol
Dangerous voltage on contacts in the battery compartment
The contacts in the battery compartment may have mains voltage applied.
Therefore only remove the battery with the existing battery holder and
insert the new battery only with the battery holder. Ensure that the contacts
are never touched.
Replacement battery
As a replacement, use only a lithium battery with a rated voltage of 6 V and
the same construction as the original battery.
Procedure:
1. Remove the front door seal.
2. Open the front door.
The battery compartment is on the left below the liquid crystal display.
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Figure 70. Battery compartment
3. Press on the latch of the plastic battery holder until it releases and then
withdraw the battery holder with the old battery.
Figure 71. Removing the battery
4. Mark the current date on the new battery.
5. Withdraw the old battery from the holder and insert the new battery.
6. Push the battery holder with battery into the battery compartment until
the latch engages.
7. Reset the battery hours counter to zero with the relevant formatted
command (see section 5.8 "Input of formatted commands") or in the
set mode (see section 5.9 "Set time and date, ID numbers, battery
time").
8. Close the front door.
9. Re-seal the front door.
10. Dispose of old batteries as hazardous waste in accordance with local
regulations.
Checking time-of-day and date
After inserting the battery, check the time-of-day and date without power
applied and set these values again if necessary.
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8 Disposal
Electronic waste treatment
This product must not be disposed of in regular waste. Use a professional
electronic waste treatment process.
The components used to manufacture the device can, in the main, be
broken down into constituent parts and sent to an appropriate recycling or
disposal facility. When the product is removed from use, the whole product
must be sent to a professional electronic waste treatment process. The
waste treatment and disposal plants must be approved by local regulatory
authorities.
The end processing of the product and recycling of its components must
always be carried out in accordance with the rules and regulations of the
country where the end processing and recycling are done.
On request, Landis+Gyr will provide more information about the
environmental impact of the product.
Disposal and environmental protection regulations
The following are general guidelines and should NOT take priority over
local disposal and environmental policies which should be adhered to
without compromise.
Components Disposal
Printed circuit boards, Delivered to recycling plants
LEDs, LCD display
Metal components Sorted and delivered to metal recycling plants
Plastic components Sorted and delivered to re-granulation if at all
possible
Batteries Removed from meter and delivered to
specialised recycling plants
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9 Index
.MAP110 ........................................................28 Control of display via optical interface .......... 51
Active component ..........................................15 Cover detection unit ...................................... 48
Active energy .................................................18 Creep test ..................................................... 74
Active power ..................................................15 Critical error .................................................. 65
Active power calculation ................................15 CS interface .................................................. 14
Active power direction ...................................52 Data preparation for billing............................ 13
Additional control inputs ................................13 Data readout ................................................. 60
Additional output contacts .............................13 Data readout via optical interface ................. 60
Alert LED .......................................................59 Date and time
Anti-tampering features .................................28 Set ...................................................... 64, 73
Apparent energy ............................................19 DC magnet detection .................................... 29
Apparent energy calculation ..........................19 Decommissioning ......................................... 77
Aron circuit.....................................................40 Dedicated event log ...................................... 23
Arrow symbols ...............................................53 Deleting error messages............................... 66
Arrows for status indication ...........................33 Device description .......................................... 8
Automatic data readout .................................60 Digital intermediate values............................ 15
Auxiliary power supply ...................................13 Dimensions ................................................... 39
Background lighting for LCD ..........................52 Direct connection ............................................ 8
Backup data checksum error .........................69 Direction of rotating field ............................... 21
Backup memory access error ........................68 Display .................................................... 33, 52
Basic information for meter connection .........40 Display buttons ....................................... 30, 50
Basic layout of LCD .......................................52 Display check................................................ 55
Battery charge status .....................................75 Display examples.......................................... 56
Battery compartment ...............................31, 76 Display menu ................................................ 55
Battery condition ............................................53 Display range changeover ............................ 72
Battery exchange ...........................................75 Disposal ........................................................ 77
Battery operating hours counter ....................75 Disposal regulations ..................................... 77
Billing data .....................................................13 DLMS items .................................................. 62
Block schematic diagram ...............................11 DLMS specification ....................................... 62
Block schematic diagram of measuring unit ..14 Dummy communication unit ......................... 31
Buttons ..........................................................11 Electronic waste treatment ........................... 77
Calculation of apparent energy ......................19 Energy components ...................................... 18
Calibration data checksum error ....................70 Energy consumption recording ..................... 60
Calibration stage ............................................15 Energy magnitude......................................... 18
Case of meter ................................................31 Environmental protection regulations ........... 77
Changing the battery .....................................75 Error code ..................................................... 65
Changing values in set mode ........................64 Error message ........................................ 54, 65
Characteristics of meters .................................8 Error severity ................................................ 65
Check of connections ....................................46 Errors for write/read access .......................... 67
Checksum errors ...........................................69 Event log ................................................. 23, 57
Combi-meter ....................................................8 Expired watchdog ......................................... 71
Commissioning ..............................................46 Extended suspension hook........................... 41
Communication ..............................................26 Extension board ............................................ 13
Communication interface ...............................14 Extension boards .............................. 36, 37, 38
Communication locked ..................................71 External pulse transmitter ............................. 14
Communication unit .................................14, 64 Faceplate ...................................................... 33
Communication unit access error ..................68 Fatal error ..................................................... 65
Connecting conductor ..............................40, 42 Field of application of meters .......................... 8
Connecting meter ..........................................42 Fixing of cover detection unit ........................ 48
Connecting phase connection lines ...............42 Form of fixing ................................................ 41
Connecting signal inputs and outputs ............44 Formation of mean values ............................ 16
Connection diagrams ...........................2, 35, 50 Formation of measured quantities ................ 18
Connection diagrams extension board ..........36 Four-quadrant measurement ........................ 19
Connections ...................................................34 Front door ..................................................... 31
Control elements ...........................................50 Functional check ........................................... 46
Control inputs ................................................11 Harmonics..................................................... 15
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Identification numbers ................................... 64 OBIS.............................................................. 81
IEC 62056-21 .......................................... 60, 63 Objectivefor DLMS ........................................ 62
Impulse inputs ............................................... 14 Operating display .......................................... 54
Index field...................................................... 53 Operating faults ............................................. 65
Index system ........................................... 53, 81 Optical button ................................................ 51
Input of formatted commands ....................... 63 Optical interface ................................ 30, 33, 64
Input signals .................................................. 14 Optical test output ............................. 30, 59, 73
Inputs ............................................................ 11 Output contacts ............................................. 34
Installation ..................................................... 40 Outputs.......................................................... 12
Interfaces ...................................................... 14 Ownership designation.................................. 34
Intermediate values....................................... 15 Parameter checksum error............................ 69
Internal current transformers ......................... 14 Phase angles ................................................ 21
Invalid clock .................................................. 67 Phase connections ........................................ 11
Invalid power down ....................................... 71 Phase current ................................................ 20
Laptop ........................................................... 60 Phase voltage ............................................... 20
LCD ......................................................... 33, 52 Phase voltages.............................................. 53
Liquid crystal display ..................................... 33 Power factor .................................................. 20
Lithium battery .............................................. 75 Power supply................................................. 13
Load profile 1 ................................................ 23 Profile 2 ......................................................... 23
Load profile 2 (option) ................................... 23 Program checksum error............................... 69
Load profile 2 checksum error ...................... 70 Pulse inputs....................................... 12, 14, 34
Load profile checksum error ......................... 69 Purpose of this manual ................................... 5
Load profile memory access error ................ 68 Push buttons ................................................. 11
Log example ................................................. 60 Quadrant display ........................................... 52
Low battery ................................................... 67 Quadrants ..................................................... 19
Main characteristics of meters ........................ 8 Rapid run................................................. 56, 59
Main faceplate............................................... 33 Reactive component ..................................... 16
Main memory access error ........................... 67 Reactive energy ............................................ 18
Mains frequency ...................................... 16, 21 Reactive power ............................................. 15
Maintenance ................................................. 72 Reactive power calculation ........................... 15
Manufacturer seal ................................... 30, 31 Reactive power direction ............................... 52
MAP120 ........................................................ 28 Reading head ................................................ 60
Mean value formation ................................... 16 Readout device ............................................. 60
Measured quantities ................................ 12, 17 Readout log ................................................... 60
Measured quantity indication ........................ 34 Readout to DLMS.......................................... 62
Measuring deviations .................................... 72 Readout to IEC 62056-21 ............................. 60
Measuring system ......................................... 12 Recording counting pulses for other physical
Measuring system access error .................... 68 media .......................................................... 8
Measuring times............................................ 72 Reference documents ..................................... 5
Measuring uncertainty ................................... 73 Releasing connection from spring-loaded
Measuring unit .............................................. 14 terminal ..................................................... 45
Memory ......................................................... 13 Removing connections in spring-loaded
Meter board................................................... 40 terminals ................................................... 48
Meter case .................................................... 31 Removing meter ............................................ 48
Meter connection .......................................... 42 Repairing meters ........................................... 71
Meter connections ......................................... 34 Replacement battery ..................................... 75
Meter constant .............................................. 73 Reset button .................................................. 31
Meter tests .................................................... 72 Reset button R .............................................. 51
Modem .......................................................... 14 Rolling display ............................................... 54
Modifying operating data or meter Rotating field ................................................. 16
characteristics .......................................... 63 RS232 interface ............................................ 14
Natural error compensation .......................... 15 RS485 interface ............................................ 14
Neutral .......................................................... 40 S0 interface ................................................... 14
Neutral current .............................................. 20 Safety
No-load test................................................... 74 Information.................................................. 6
Non-critical errors.......................................... 65 Regulations................................................. 7
Normal mode ................................................ 72 Responsibilities........................................... 6
Numbering of quadrants ............................... 19 Seal component ...................................... 32, 33
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80/84 Index
Sealing.....................................................30, 46 Tariff faceplate .............................................. 34
Sealing with padlock ......................................32 Telemetering ................................................... 8
Seals..............................................................30 Terminal cover ........................................ 30, 31
Self-tests ..................................................54, 65 Terminal cover detection .............................. 29
Series designation .........................................10 Test mode ......................................... 72, 73, 74
Service ...........................................................65 Test voltage .................................................. 74
Service and repair centre ..............................71 Testing meter ................................................ 72
Service menu .................................................58 Time device access error .............................. 68
Set date and time ..........................................64 Time-base errors .......................................... 66
Set identification numbers .............................64 Total active energy ....................................... 18
Set mode .................................................59, 64 Total apparent energy ................................... 19
Set operating time of battery .........................64 Total harmonic distortions............................. 21
Severity of errors ...........................................65 Total reactive energy .................................... 18
Signal processing ..........................................12 Transmission contact ...................................... 8
Signal processor ......................................15, 16 Type designation .......................................... 10
Signal utilisation .............................................12 Type of measurement ZMD400xT ................ 14
Software tools ................................................27 Types of display ............................................ 54
Software version ............................................11 Types of error ............................................... 66
Spring-loaded terminals .................................35 Uninstallation ................................................ 48
Standard data ................................................55 Units field ...................................................... 53
Starting test ...................................................74 Utility seal ............................................... 30, 31
Status indication arrows ................................33 Value display .......................................... 56, 58
Stored value profile ........................................23 Value field ..................................................... 53
Stored values checksum error .......................70 Verification seal ...................................... 30, 31
Structure of error messages ..........................66 Viewing window ............................................ 31
Substitute meter ................................49, 71, 72 Voltage divider .............................................. 14
Summation channels .....................................22 Wrong EEPROM/Flash ................................. 71
Suspension eyelet .........................................41 Wrong extension board................................. 71
Suspension triangle .......................................41 Zero passage .......................................... 16, 21
Target group of this manual .............................5 ZMD300AT/CT................................................ 8
Tariff control ...................................................13
© Landis+Gyr D000030108 en m – E650 Series 3 – ZMD300AT/CT – User Manual
Appendix 1 OBIS code 81/84
Appendix 1 OBIS code
Object Identification System
The OBIS code (Object Identification System) is structured as follows:
A B C D E F Value group
M- KK: GG. AA. T W According to VDEW
A: Medium Defines the medium used. If only one medium is used it does not have to
[1 … 9] be specified. The Values represent the following objects:
1 Electricity
2, 3 Not used
4 Heating costs
5 Cooling system
6 Heating system
7 Gas
8 Cold water
9 Hot water
B: Channel Defines the channel number, i.e. the number of the input of a metering
[1 … 64] equipment with several inputs for the measurement of energy of the same
or different types (e.g. in data concentrators, registration units). This
enables data from different sources to be identified. If only one channel
(only one meter) is used, it does not have to be specified.
C: Measured quantity Defines the abstract or physical data items related to the information
[1 … 99] source concerned, e.g. active power, reactive power, apparent power,
cos, current or voltage.
General data 0
Active energy + (import) ∑Li 1 L1 21 L2 41 L3 61
– (export) 2 22 42 62
Reactive energy + 3 23 43 63
– 4 24 44 64
QI (quadrant I) 5 25 45 65
QII 6 26 46 66
QIII 7 27 47 67
QIV 8 28 48 68
Apparent energy + (import) 9 29 49 69
– (export) 10 30 50 70
Current 11 31 51 71
Voltage 12 32 52 72
Power factor 13 33 53 73
Frequency 14
Service data C
Error message F
Profile data P
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82/84 Appendix 1 OBIS code
D: Measuring type Defines types, or the result of the processing of physical quantities
[1 ... 73, F, P] according to various specific algorithms. The algorithms can deliver energy
and demand quantities as well as other physical quantities.
The following list is an excerpt.
Capture period 1 2 3
Cumulated minimum 1 11 21
Cumulated maximum 2 12 22
Minimum 3 13 23
Running average 4 14 24
Last average 5 15 25
Maximum 6 16 26
Instantaneous value 7
Time integral 1 (energy status) 8
Time integral 2 (energy consumption) 9
Time integral 3 (excess consumption) 10
...
Test average 55
Test time integral 4 58
...
Error message F
Load profile 01
E: Tariff Defines the further processing of measurement results to tariff registers,
[1 ... 9] according to the tariffs in use. Total values are marked with ‘0’. For abstract
data or for measurement results for which tariffs are not relevant, this value
group can be used for further classification.
F: Stored value Defines the storage of data according to different billing periods. Where this
[01 ... 99] is not relevant, this value group can be used for further classification.
Display code To simplify the reading of the display code, individual parts of the OBIS
code can be omitted. The abstract or physical data C and type of data D
must be shown.
Examples
1.8.0 1 = all-phase active power in positive direction
8 = cumulative value (meter reading)
0 = total energy (no tariffs)
0.9.1 Local time
© Landis+Gyr D000030108 en m – E650 Series 3 – ZMD300AT/CT – User Manual
Appendix 1 OBIS code 83/84
D000030108 en m – E650 Series 3 – ZMD300AT/CT – User Manual © Landis+Gyr
Contact:
Landis+Gyr AG
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