H 71 0200 0215 f en
Electricity Meters IEC
HIGH PRECISION METERING
Landis+Gyr Qualigrid
ZMQ202 / ZFQ202
USER MANUAL
Landis+Gyr H 71 0200 0215 f en - ZMQ202 / ZFQ202 - User Manual
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Revision History
Index Date Comments
a 20.12.2002 First release, for approbation.
b 07.01.2003 New layout
c 07.03.2003 Chapter 2 updated, various changes:
hazard symbols, sealing, LP memory, starting load
d 19.03.2003 Minor changes to paragraph 6.3 Errors
e 30.06.2003 Updates according to the safety review (preliminary edition) and to final
review
f 19.12.2003 Updates according to product risk analysis
Landis+Gyr Ltd.
Feldstrasse 1
CH - 6301 Zug
Switzerland
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About this Document
The present user manual applies to the meters specified on the title page.
The user manual contains all the information required for application of the
meters for the intended purpose. This includes:
• Provision of knowledge concerning characteristics, construction and
function of the meters
• Information about possible dangers, their consequences and measures
to prevent any danger
• Details concerning the performance of all work throughout the service
life of the meters (parametrization, installation, commissioning, operation, maintenance, shutting down and disposal)
The contents of this user manual are intended for technically qualified
personnel of energy supply companies responsible for the system planning,
installation and commissioning, operation, maintenance, decommissioning
and disposal of the meters.
Users of this manual are familiar from their training with the basic principles of electrical engineering, in particular with the principles of energy
measurement, including circuitry types, connection technology, etc.
The follwing documents complement this user manual:
Functional description: Explains the functionality of the ZxQ meter and the
parameterisation using the MAP tool.
Technical data: States all technical data of the ZxQ meter.
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. ZxQ202 for the ZMQ202 and ZFQ202 meters).
• The digit pair "00" can be used to indicate accuracy data (e.g. ZxQ200
for the ZxQ202 and ZxQ205 meters).
• The abbreviated type designation ZMQ or ZFQ meters can be used when
all three-phase four-wire meters or three-phase three-wire meters are
meant.
Range of validit
y
Purpose
Target group
Conditions
Reference
documetation
Type designation
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Table of Contents
1 Safety _____________________________________________ 9
1.1 Safety Information_____________________________________________9
1.2 Application ___________________________________________________9
1.3 Responsibilites _______________________________________________10
1.4 Safety Regulations ____________________________________________10
2 Description of Unit __________________________________ 13
2.1 Features ____________________________________________________13
2.2 Block Schematic Diagram ______________________________________14
2.3 Measuring System ____________________________________________16
2.3.1 Input Signals ________________________________________________ 16
2.3.2 Input Circuits ________________________________________________16
2.3.3 Analogue-Digital Converter _____________________________________16
2.3.4 Signal Processor______________________________________________ 16
2.4 Microprocessor_______________________________________________18
2.4.1 Data Provided by the Microprocessor _____________________________18
2.4.2 Calculation of Measured Quantities _______________________________20
2.5 Tariff Control ________________________________________________21
2.6 Calendar Clock _______________________________________________22
2.6.1 Adjusting the Calendar Clock via the Synchronisation Input ___________22
2.6.2 Adjsuting the Calendar Clock via Communication____________________24
2.6.3 Handling the Deviations________________________________________24
2.7 Registers ___________________________________________________25
2.8 Memory ____________________________________________________25
2.8.1 Load Profile _________________________________________________25
2.8.2 Event Log ___________________________________________________26
2.9 Power Supply ________________________________________________26
2.10 Additional Power Supply _______________________________________26
2.11 Transmitting Contacts Module___________________________________26
2.12 Communication Unit (Option) ___________________________________27
2.13 Software Tools _______________________________________________27
3 Mechanical Description _______________________________ 29
3.1 Manufacturer's Seal ___________________________________________30
3.2 Verification Seal ______________________________________________ 30
3.3 Utility's Seals ________________________________________________31
3.4 Face Plate f6 ________________________________________________33
3.5 Information Plate f6___________________________________________ 33
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3.6 Terminal Connection Diagram f6 ________________________________ 34
3.7 Face and Information Plate f9 __________________________________ 34
3.8 Connection Diagram f9________________________________________ 34
3.9 Dimension Diagrams f6 _______________________________________ 35
3.10 Dimension Diagrams f9 _______________________________________ 36
3.10.1 Rack Mounting ______________________________________________ 36
3.10.2 Chassis ____________________________________________________ 37
3.10.3 Flush Mounting ______________________________________________ 39
3.11 Mounting f6 ________________________________________________ 40
4 Installation / De-installation___________________________ 41
4.1 Prerequisites ________________________________________________ 41
4.2 Connect f6 _________________________________________________ 42
4.2.1 Terminal Connection Diagram __________________________________ 42
4.2.2 Terminal Layout _____________________________________________ 42
4.2.3 Procedure __________________________________________________ 43
4.3 Connect f9 _________________________________________________ 46
4.3.1 Plug Connection Diagram ______________________________________ 46
4.3.2 Terminal Layout _____________________________________________ 46
4.3.3 Procedure __________________________________________________ 47
4.4 Installation Check ____________________________________________ 47
4.4.1 Check Procedure_____________________________________________ 48
4.4.2 Set Date and Time ___________________________________________ 49
4.4.3 Set Battery Low Indicator______________________________________ 50
4.5 Sealing ____________________________________________________ 50
4.6 Disconnect f6 _______________________________________________ 51
4.6.1 Procedure __________________________________________________ 51
4.7 Disconnect f9 _______________________________________________ 52
4.7.1 Procedure __________________________________________________ 52
5 Operation _________________________________________ 55
5.1 Operating Elements __________________________________________ 55
5.1.1 Display ____________________________________________________ 56
5.1.2 Display Buttons______________________________________________ 57
5.1.3 Optical Interface_____________________________________________ 57
5.1.4 Optical Test Outputs__________________________________________ 57
5.1.5 Alarm LED__________________________________________________ 58
5.2 Operating Menu _____________________________________________ 59
5.2.1 Select Display Menu __________________________________________ 60
5.2.2 Display List _________________________________________________ 60
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5.2.3 Load Profile _________________________________________________61
5.2.4 Event Log ___________________________________________________62
5.2.5 Register Snapshots ___________________________________________ 63
5.2.6 Losses _____________________________________________________ 63
5.2.7 Grid Diagnostic_______________________________________________64
5.3 Meter Operation in Systems ____________________________________64
5.3.1 Remote Meter Reading in Energy Production Applications _____________ 64
5.3.2 Types of Communication _______________________________________64
5.3.3 Communication Units__________________________________________65
5.3.4 MAP 120 Service Tool _________________________________________65
6 Service____________________________________________ 67
6.1 Alarm Reset Button ___________________________________________67
6.2 Service Menu ________________________________________________67
6.2.1 Select Service Menu___________________________________________68
6.2.2 Service List__________________________________________________68
6.2.3 Installation Diagnostic List______________________________________69
6.2.4 Test Mode __________________________________________________69
6.2.5 Set Battery Low Indicator ______________________________________70
6.3 Errors ______________________________________________________71
6.3.1 Fatal Errors _________________________________________________71
6.3.2 Alarms _____________________________________________________72
6.3.3 Operational Indications ________________________________________72
6.4 Repair______________________________________________________73
7 Maintenance _______________________________________ 75
7.1 Meter Tests _________________________________________________ 75
7.1.1 Measuring Times _____________________________________________75
7.1.2 Optical Test Outputs __________________________________________75
7.1.3 Test Transmitting Contacts _____________________________________75
7.1.4 Test Mode __________________________________________________76
7.1.5 No Load Test ________________________________________________77
7.1.6 Starting Load for Active Energy__________________________________ 77
7.1.7 Starting Load for Reactive Energy________________________________77
7.2 Set Time & Date, ID Numbers, Battery Time _______________________77
7.3 Change Battery ______________________________________________ 78
7.3.1 When to Change Battery _______________________________________78
7.3.2 How to Change Battery ________________________________________79
7.4 Change Communication Unit ____________________________________81
7.4.1 When to Change Communication Unit ____________________________81
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7.4.2 How to Change Communication Unit _____________________________ 81
8 Disposal___________________________________________ 85
8.1 Components ________________________________________________ 85
8.2 Meters_____________________________________________________ 85
9 Index_____________________________________________ 87
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Safety 9/88
1 Safety
1.1 Safety Information
Attention is drawn as follows in the individual chapters of this user manual
with classified word symbols and pictographs to the relevant danger level,
i.e. the severity and probability of any danger:
Danger
Definition of Danger
For a possibly dangerous situation, which could result in severe physical
injury or fatality.
Warning
Definition of Warning
For a possibly dangerous situation, which could result in minor physical
injury or material damage.
Note
Definition of Note
For general details and other useful information to simplify the work.
In addition to the danger level, all safety information also describes the
type and source of the danger, its possible consequences and measures to
counteract the danger.
1.2 Application
The ZxQ is designed to be utilised for energy measurement
• in energy production applications
• in energy transmission applications
• in industrial consumer applications
• in special, high-precision metering applications
Use of the ZxQ for any purpose not described above is considered as
misuse of the product.
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1.3 Responsibilites
The owner of the meters – usually the utility – is responsible that all
persons engaged on work with meters:
1. Have read and understood the relevant sections of the user manual.
2. Are sufficiently qualified for the work to be performed.
3. Strictly observe the safety regulations (according to section
1.4 Safety
Regulations
) and the operating information in the individual chapters.
In particular, the owner of the meters bears responsibility
• for the protection of persons,
• prevention of material damage
• and the training of personnel.
Landis+Gyr AG provides training courses for this purpose on specific
equipment; please contact the relevant agent if interested.
1.4 Safety Regulations
The following safety regulations must be observed at all times.
Danger
Trained personnel
Local safety regulations must be observed. Installation and de-installation
of the meter must only be performed by qualified meter installers, with
strict adherence to the utility's safety regulations.
Danger
Do not open the meter when energised
When the meter is connected and energised, there are live parts inside the
meter. Do not open the meter when energised.
Disconnect the measuring voltage and all auxiliary circuits before opening
the meter housing.
Danger
Dangerous voltage on conductors
Dangerous voltage is present on the conductors that the meter is to be
connected to.
Contact with the conductors when under voltage will result in severe
personal injury or death.
T
he conductors must not be under voltage when connecting or
disconnecting the meter. The relevant preliminary fuses should therefore
be removed and kept in a safe place until the work is completed, so that
other persons cannot replace them unnoticed.
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Danger
Dangerous voltage on transformers
Dangerous voltage is produced by the current transformers when the
secondary circuit is broken while current is flowing in the primary.
Contact with the transformers when under voltage will result in severe
personal injury or death. The high voltage produced will destroy the
transformers.
The current transformer secondary circuit must be short-circuited before
de-installing the meter.
Danger
Missing transformer earthing
Voltage transformers in medium and high voltage systems that are not
earthed on the secondary may reach dangerously high voltage values on
the secondary.
Voltage transformers are usually earthed on the secondary. If the voltage
transformer is not earthed, severe personal injury or death can result i
f
contact is made with the meter and the meter will be damaged beyond
repair.
If the voltage transformers are not earthed, special precautions must be
taken when working at the meter.
Danger
Galvanic isolation
T
he measuring circuits and auxiliary circuits (additional power supply, tarif
f
control input, synchronisation input, transmitting contacts, communication
interfaces) must be galvanically isolated.
Danger
Voltage paths must be fused
When installing the meter, all voltage paths (measurement voltage and all
auxiliary circuits such as the additional power supply and the tariff control
voltage) must be fused by max. 6A delay fuses.
Warning
Damage of dust, water, incorrect cleaning and handling
Damage to the meter could occur if the meter is subjected to running
water or even high-pressure devices, e.g. for cleaning purposes. The meter
may be cleaned with a damp cloth.
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Warning
Dropping meters
The meters can cause injuries if dropped.
The meters must be held securely during installation.
Meters which have dropped must not be installed, even if no damage is
apparent. They must be returned for testing to the service and repair
department responsible (or the manufacturer). Internal damage can result
in functional disorders or short-circuits.
Warning
Shipment of the meter
The meter may only be shipped in its original packing.
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Description of Unit 13/88
2 Description of Unit
The ZxQ is a high precision combimeter of class 0.2S designed for grid
metering applications.
2.1 Features
The ZxQ is the answer to customer needs, providing
• More measurement quantities (e.g. single phase, U, I, VA)
• Installation diagnostics for easy commissioning
• Quick network diagnostics on site
• Standard protocols for communication with billing station.
Excellent measurement features for Cl.0.2S
• Landis+Gyr-proven long-term stability and reliability
(75,000 Cl.0.2S meters in operation)
• All requirements guaranteed according to IEC 60687 and the new
IEC 62053-22
• Excellence in measurement from starting load to Pmax in both energy
flows
• Negligible influence if power factor is less than 1
• Reactive energy Cl.0.5 possible (IEC definitions only for Cl.2).
Special grid functions
• Measurement system five times faster than for industrial meters, giving
sufficient resolution for integration periods less than 15 minutes (1 to 5
minutes) and accurate measurement by changing energy flow
• Easy customer calibration for all phase corrections
• Transmitting meter with concentrator (extension for existing equipment)
• Additional power supply secures communication even if the measuring
voltage fails. In addition, the additional power supply prevents the line
between transformer and meter from improper voltage drops.
Communication
• Standard dlms communication protocol with the possibility of other
standard protocols for network management
• Use of modular communication units separated from measurement
(same solution as ZMD400).
Transmitting contacts
None, or 4 to 8 transmitting contacts, constant impulse frequency up to 40
imps/s, possibility for two contacts with the same value or quadrant
splitting.
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Broad range of applications:
Wall / projection-mounting and rack / flush-mounting with the same
printed circuit boards give more flexibility at the place of installation and
saves money on spare parts. Plug-in compatible version for replacing or
extending with ESSAILEC connectors.
2.2 Block Schematic Diagram
U1
U2
U3
N
I1
I2
I3
Control
inputs
Measuring system
Power supply
Supply monitor
Flash
memory
Microprocessor
LCD display
Optical test
output
Optical
interface
Signal
processing
Calibration
Measured
quantities
Billing
data
Load
profil
data
Time switch
Display buttons
Calendar clock
Alarm reset
Alarm
output
Communication
unit with
interfaces
Additional
power supply
Local
RS485 interface
U
S
U
S
A/D
Filter
A/D
Filter
E1
E2
E3
Syn
Transmitting
contacts
board
4 changeover or
8 normally
open
contacts
Tariff
control
Standard
functions
Optional
functions
Control
signals
Digital
data
The main inputs to the meter are:
• Phase voltages U1, U2, U3 and neutral conductor N
- to be processed in the measuring system
- for the three-phase power supply of the meter
- to be monitored by the voltage monitor
• Phase currents I1, I2, I3
- to be processed in the measuring system
- to be monitored by the current monitor
• Control inputs used for:
- selecting of energy tariffs (3 control inputs: E1, E2, E3)
- synchronising the internal calendar clock (1 control input: Syn)
Inputs
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Opto-couplers provide the galvanic isolation and protect the electronic
circuits of the meter from interference, which could otherwise enter via the
control inputs.
• Additional power supply U
S
to ensure the operation of the meter during
interruptions of the measurement voltage
• Push buttons
- for display control (2 buttons)
- for service functions and alarm reset (1 button)
The meter has following outputs:
• Single line, 8-digit liquid crystal display (LCD) with back light for local
reading of billing data and load profile data and additional information,
such as energy flow, type of energy, presence of phase voltages and
identification numbers
• Optical test outputs (green LEDs) for either active and reactive energy
or I
2
and U2
• Alarm output (relay and LED)
• Up to 8 transmitting contacts with selectable signal assignment on the
transmitting contacts board (static relays)
• Optical interface for the download of parameterisation data and for local
data acquisition by a suitable data acquisition unit (e.g. lap-top
computer)
• Local serial interface RS485 for the daisy-chain connection between the
individual meters
• Various communication interfaces (e.g. RS485, RS232, modem) for the
transfer of billing data and load profile data to the central station.
Outputs
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2.3 Measuring System
Signal
converter
Signal
processor
Calibration
Micro-
processor
analogue
input
signals
instantaneous
digital
values
measured
quantities
I1, I2, I3
U1, U2, U3
I, U,
P, Q,
S, fn etc
±A, ±R, etc.
digital
raw
data
Measurement processor
Input
circuits
i, u
U
I
, U
U
2.3.1 Input Signals
The measuring system of the meter has the analogue current values I1, I2,
I3 and the analogue voltage values U1, U2, U3 available as input signals.
2.3.2 Input Circuits
High resistance voltage dividers reduce the voltages U1, U2, U3 applied to
the meter (57.7 V to 132.8 V) to a proportional value of a few mV (U
U
) for
further processing.
Compensated current transformers similarly reduce the input currents I1,
I2, I3 applied to the meter (0 A to 2 A or 0 A to 7.5 A). The secondary
currents of these current transformers develop voltages over burden
resistors. These voltage values are proportional to the input currents, also
of a few mV (U
I
).
The meter can be adapted to the required current range (1 A or 5 A) by
changing the burden resistors of the current transformers.
2.3.3 Analogue-Digital Converter
The analogue input signals UU and UI are converted to digital values by
analogue-digital converters and filtered by various filter stages.
Digital instantaneous values of voltage (U) and current (I) for all three
phases are then available as intermediate values, ready for the formation
of the digital raw data by the signal processor.
2.3.4 Signal Processor
Over an integration interval of 0.2 seconds, the signal processor calculates
the digital raw data listed below.
• Active energy per phase
• Reactive energy per phase
• Phase voltages, RMS values
• Phase currents, RMS values
• Apparent energy per phase
• Phase angles (∠U1Ux, ∠U1Ix)
• Network frequency
• Phase failure
Voltage input
Current input
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Description of Unit 17/88
These values are now available as calibrated raw data. They are stored in
the output buffer of the signal processor from where they are transferred
to the microprocessor by an SPI interface.
The calculation of the energy per phase is a two-step procedure:
1. The instantaneous, single-phase values of power are produced by
multiplying the instantaneous, single phase values of voltage U and
current I.
2. The single-phase values of power are then integrated over the
integration period.
The active power is the product of the voltage multiplied by the current
component parallel to the voltage I
P
.
U
I
Calculation per phase of
P = U I cos ϕ
P = U I
P
I
Q
I
P
. .
.
ϕ
The instantaneous value of active power P is then integrated over the
integration period of 0.2 seconds to form a digital value of active energy.
For the instantaneous value of reactive power Q the instantaneous values
of voltage U and current I must be rotated by +45° and -45° respectively
prior to the multiplication.
The reactive power is the product of the voltage multiplied by the current
component vertical to the voltage I
Q
.
Calculation per phase of
Q = U I sin ϕ
Q = U I
Q
U
I
.
.
I
Q
I
.
ϕ
The instantaneous value of reactive power Q is then integrated over the
integration period of 0.2 seconds to form a digital value of reactive energy.
Single phase energy
calculation
Active energ
y
Reactive energ
y
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2.4 Microprocessor
The microprocessor of the ZxQ reads the digital raw data from the output
buffer of the signal processor every 0.2 seconds.
2.4.1 Data Provided by the Microprocessor
Based on the digital raw data provided by the signal processor, the
microprocessor calculates the measured quantities listed in the tables
below.
Depending on the functional range of the meter (energy C.4, netenergy C.6
or enerflex C.8), different sets of measured quantities are available.
Note
Availability
Meters for three-phase, three-wire networks (F-circuit) are not yet
available.
With energy (C.4) the following measured quantities are available:
Measured quantity ZMQ ZFQ
Active energy import +A Sum Sum
Active energy export –A Sum Sum
Reactive energy import +R Sum Sum
Reactive energy export –R Sum Sum
Reactive energy in quadrant I +Ri Sum Sum
Reactive energy in quadrant II +Rc Sum Sum
Reactive energy in quadrant III –Ri Sum Sum
Reactive energy in quadrant IV –Rc Sum Sum
Phase voltages (RMS) U1, U2, U3 U12, U32
Phase currents (RMS) I1, I2, I3 I1, I3
Network frequency fn yes yes
Phase angle between voltages
ϕ U
U1-U2 / U1-U3* U12-U32 **
Phase angle between voltage and current
ϕ U-I
U1-I1, U1-I2,
U1-I3 *
U12-I1,
U12-I3 **
Direction of rotating field yes yes
Phase failure yes yes
* Phase angles will only be displayed if voltage L1 is present.
** Phase angles will only be displayed if all voltages are present.
energy (C.4)
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With netenergy (C.6) the following measured quantities are available in
addition to energy (C.4):
Note
Availablity
Meters with the functional range C.6 (netenergy) are not yet available.
Measured quantity ZMQ ZFQ
Active iron losses (transformer) NLA Sum Sum
Active copper losses (line) OLA Sum Sum
Reactive iron losses (transformer) * NLR Sum Sum
Reactive copper losses (line) * OLR Sum Sum
Total active losses in positive direction +TLA Sum Sum
Total active losses in negative direction -TLA Sum Sum
Total reactive losses in positive direction * +TLR Sum Sum
Total reactive losses in negative direction * -TLR Sum Sum
Net/gross active energy in positive direction +CA Sum Sum
Net/gross active energy in negative direction -CA Sum Sum
Net/gross reactive energy in positive direction * +CR Sum Sum
Net/gross reactive energy in negative direction * -CR Sum Sum
Total losses of active energy TLA Sum Sum
Total losses of reactive energy TLR Sum Sum
THD of active energy THDA Sum / Phases Sum
THD of RMS phase voltage THDU Sum / Phases Sum
THD of RMS phase current THDI Sum / Phases Sum
* Values for reactive losses are available for compatibility reasons with
third-party products. However, Landis+Gyr recommend not to measure
reactive losses.
With enerflex (C.8) the following measured quantities are available in
addition to netenergy (C.6) and energy (C.4):
Measured quantity ZMQ ZFQ
Active energy import +A single-phase
Active energy export –A single-phase
Reactive energy import +R single-phase
Reactive energy export –R single-phase
Reactive energy in quadrant I +Ri single-phase
Reactive energy in quadrant II +Rc single-phase
Reactive energy in quadrant III –Ri single-phase
Reactive energy in quadrant IV –Rc single-phase
Apparent energy import +S Sum / Phases Sum *
netenergy (C.6)
enerflex (C.8)
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Apparent energy export -S Sum / Phases Sum *
Apparent energy in quadrant I +Si Sum / Phases Sum *
Apparent energy in quadrant II +Sc Sum / Phases Sum *
Apparent energy in quadrant III –Si Sum / Phases Sum *
Apparent energy in quadrant IV –Sc Sum / Phases Sum *
Energy flow of active energy EFA Sum Sum
Energy flow of reactive energy EFR Sum Sum
* Due to the different type of measurement of the Aron circuit, data for
the individual phases are not provided by the ZFQ.
2.4.2 Calculation of Measured Quantities
By scanning the raw data of active energy A and reactive energy R every
0.2 seconds, energy components (Ws or vars) with varying energy
magnitudes are produced at fixed intervals.
The microprocessor calculates the total active energy import +A and the
total active energy export -A by summating the raw data of active energy
A1, A2 and A3.
Measured quantities
Raw data of
active energy
Σ
A1
A3
A2
+A (Import)
-A (Export)
The microprocessor calculates the total reactive energy import +R and the
total reactive energy export -R by summating the raw data of reactive
energy R1, R2 and R3.
Measured quantities
Raw data of
reactive energy
Σ
R1
R3
R2
+R (Import)
-R (Export)
These energy components are scaled by the microprocessor corresponding
to the meter constant (primary data) and are then available as measured
quantities. The measured quantities can be selected by parameter setting
and their measured values are fed directly to the registers to record the
energy.
Active energy
Reactive energ
y
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Based on the signs of A and R the microprocessor can allocate the reactive
energy to the four quadrants.
• Reactive energy in quadrant I: +Ri
• Reactive energy in quadrant II: +Rc
• Reactive energy in quadrant III: –Ri
• Reactive energy in quadrant IV: –Rc
Import
reactive
power
Export
reactive
power
+
_
III
III IV
Export active power Import active power
cos ϕ = 0,5 (60°)
sin ϕ = 0,5 (30°)
sin ϕ = 0,5 (150°)
cos ϕ = 0,5 (- 60°)
+
_
sin ϕ =1 (90°)
Lagging
Lagging
Leading
Leading
Q
S
+Ai
+Ac
+Rc +Ri
-Ri -Rc
-Ac
-Ai
-90°
cos ϕ = 1(0°
)
I
ϕ
P
U
2.5 Tariff Control
Various signal sources can be used to select the required tariff. Tariff
control may be performed:
• Externally by the three input control signals E1, E2, E3 (with selectable
control voltage ranges: 24 V up to 230 V; the control voltage must be
specified by the customer)
• Internally by the calendar clock and the time switch
• By event signals based on threshold values of the monitoring functions,
e.g. frequency, voltage
Signals from the various signal sources can be combined to realise a
sophisticated tariff structure.
Allocation to the four
quadrants
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2.6 Calendar Clock
The internal calendar clock of the ZxQ is used to generate the date and
time information which is used:
• for the date and time information to be displayed
• for the time stamps in the load profile and event log
• for the formation of the capture period of the load profile
• to control the time switch
Calendar clock
Internal
capture
period
Network frequency
50/60 Hz
crystal
Capture
period
synchronous
capture
period
Synchronising
Date and time
The clock uses a crystal as time base. The clock may be driven by the
network frequency (50 Hz or 60 Hz), provided it is sufficiently accurate.
Tuning is then performed after each full wave, i.e. after 20 ms at 50 Hz.
The clock features an accuracy according to IEC 61038.
The calendar clock can be adjusted by an external master clock via the
synchronisation signal Syn or via communication. The period is adjustable.
A supercap (capacitor of a very large capacity) provides the power reserve
of the clock. The power reserve may be extended by the use of a battery.
• Power reserve without battery: min. 20 days (only after the meter has
been connected to the network for at least 300h)
• Power reserve with battery: 10 years
2.6.1 Adjusting the Calendar Clock via the Synchronisation Input
The calendar clock can be adjusted by an external master clock (e.g. the
central station), which sends synchronisation pulses at regular intervals.
There are two possibilities of adjusting the calendar clock using the
synchronisation signal Syn:
• The adjustment takes place several times throughout the day.
• The adjustment takes place once per day.
Note
Usage of only one type of adjustment
Only one type of adjustment can be used at a time, either several times
per day
or once per day.
Time base
Accurac
y
Synchronisation
Power reserve
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The regular adjustment takes place at regular intervals, e.g. 15 minutes.
The interval is defined by parameter setting.
Adjustment interval e.g. 15 min
> 2 s
< 100 ms bounce-free
Since the synchronisation signal is transmitted at regular intervals (e.g.
00:00h, 00:15h, 00:30h etc) it carries a time information. When, for
instance, the meter receives the third synchronisation signal of the day
(00:30h) the calendar clock is adjusted to 00:30h. The reaction of the
meter to the synchronisation signal depends on the detected deviation.
The meter will accept the synchronisation pulse any time but only once
within synchronisation interval.
Note
Ignoring second synchronisation pulse
A second synchronisation pulse within the adjustment interval will be
ignored.
With the daily adjustment, the meter allows one time window per day
within which the synchronisation pulse must be sent to the meter. The time
of the day (e.g. 22:00h) and the width (e.g. one minute) of the window
can be defined by parameter setting.
00:00h
24:00h
Daily synchronisation
time window
Daily synchronisation
pulse
If the “time of the day” parameter is set to 22:00h and the meter receives
a synchronisation signal within the defined window, the meter is adjusted
to 22:00h. The reaction of the meter to the synchronisation signal depends
on the deviation.
The meter will not accept a synchronisation pulse outside the time window
and the signal will therefore have no effect.
Several times per
day
Once per day
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2.6.2 Adjsuting the Calendar Clock via Communication
The calendar clock can be adjusted by the central station, which sends the
time information to the meter via the selected communication interface.
The time information received from the central station is compared with
the local time of the meter. The reaction of the meter to the time
information depends on the deviation.
The time can be adjusted as often as required but only once per capture
period.
Note
Time adjustment twice within capture period
If the time is adjusted a second time within the same capture period, the
capture period is reset no matter how small the deviation.
T
his is to prevent multiple adjustment with a small time shift resulting in a
large time shift that, if made in one single approach, would have reset the
capture period.
2.6.3 Handling the Deviations
Depending on the time deviation of the internal clock from the external
master clock, the adjustment has different effects on the calendar clock.
The following cases are possible:
• the time deviation is between 0 second and 2 to 9 seconds (depending
on parameter setting)
• the time deviation is longer than 2 to 9 seconds (depending on
parameter setting)
- time setting
- capture period reset
- synchronisation
- time shift
0 s
2 ... 9 s
Deviation
The effects of the adjustment are the same, no matter whether it was
triggered by a pulse or via communication.
If the difference between the internal clock and the master clock is
between 0 seconds and a maximum of 9 seconds, the time is advanced or
set back by the corresponding period of time. Advancing or setting back
the clock is only allowed once per capture period. The capture period is
shortened or elongated by the length of the time shift.
If the difference between the internal clock and the master clock is longer
than 2 to 9 seconds, the time will be reset to either the start time or the
end time of the capture period. The affected capture period is declared as
invalid.
Between 0 seconds
and 2 to 9 seconds
Longer than 2 to 9
seconds
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2.7 Registers
The following registers are available for the analysis of the individual
measured values:
• 24 rated energy registers
• 38 total energy registers (no tariffs)
• other registers for values of voltage and current, network frequency,
phase angles etc.
Measured
values
Tariff switching
Selection of data for
display and communication
Communication
Display
24 rated energy registers
38 total energy registers
Local Communication
Test output
2.8 Memory
A non-volatile memory (flash memory) contains the configuration and
parameterisation data of the meter. It also contains the load profile, the
energy profile and the event log data.
All data stored in the flash memory is prevented from loss caused by
voltage failures. No battery is required to do so.
2.8.1 Load Profile
The current statuses of various registers are saved to the load profile at
regular intervals.
Each load profile entry consists of the measured value itself (energy
registers = 8 bytes, diagnostic values = 4 bytes), a time stamp of 8 bytes
and a status code of 4 bytes.
The ZxQ meters feature a load profile memory of 1.8 MB. The memory
depth of the load profile is calculated with the formula below.
[]
[]
[]
min60h24byteentrypermemoryused
minperiodcapturebyte1'810'000
daysdepthmemory
××
×
=
A minimum of 100 days is guaranteed with 36 captured registers and a
capture period of 15 minutes.
The load profile is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry.
Load profile memory
size
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2.8.2 Event Log
Events that occur sporadically are stored in the event log. The user may
select what 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
application of the meter.
In the event log, a minimum of 256 event entries can be stored, all of
which consist of the time stamp of 5 bytes, the event number (1 byte) and
an internal offset of 1 byte.
The event log is organised as a circular buffer, i.e. the oldest entry will be
overwritten by the most recent entry.
2.9 Power Supply
The supply voltages for the meter are obtained from the three-phase
network, whereby the phase voltage may vary over the entire voltage
range without the power supply having to be adjusted. As the power
supply even works with only one phase voltage available, single-phase
voltage dips do not affect the operation of the meter.
A voltage monitor ensures correct operation and reliable data recovery in
the event of a all-phase voltage interruption and correct restarting when
the voltage is restored
2.10 Additional Power Supply
Because the three-phase network can be switched off in grid metering
applications, the meter is equipped with an auxiliary power supply in order
to prevent the meter from being switched off.
The additional power supply supplies its voltage in parallel to the normal
network supply and it ensures an uninterrupted operation of the meter, so
that the meter can be read at any time. In a special mode, the meter may
also be powered by the auxiliary power supply only (optional, depending on
parameter settings). As a result, there is no load on the line between
transformer and meter which prevents the line from voltage drops.
2.11 Transmitting Contacts Module
The transmitting contacts module is fitted inside the meter and is therefore
secured by calibration seals. It features up to four changeover contacts or
up to eight normally open contacts (solid-state relays). The contacts are
used to transmit energy pulses and/or energy direction information or
status information.
The transmitting contacts either transmit pulses with a defined pulse length
(20 ms, 40 ms or 80 ms) or pulses with a mark-to-space-ratio of 1.
There are transmitting contact modules with a pre-defined terminal
allocation while the terminal allocation of other modules can be
parameterised according to the customer’s specification.
Event log memory
size
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2.12 Communication Unit (Option)
The optional communication unit is a complete unit housed in its own case.
If mounted, it is situated under the front cover. Therefore, it is secured by
a utility seal and can be mounted and replaced in the field if necessary. It
contains communication interfaces (e.g. RS232, RS485, modem) as
required for remote reading of the meter data. Two different
communication units are available.
2.13 Software Tools
There are two software tools available with the meter, which enable easy
parameter setting and communication with the meter.
The software Landis+Gyr MAP190 is used for setting up complete
parameter sets off-line (parameter editor). The prepared parameter sets
can then be downloaded to the meter via the optical interface. The
software MAP190 is used for the order processing by regional companies.
The software Landis+Gyr MAP120 is used:
• to communicate with the meter according to dlms
• to perform service tasks
• to set certain parameter ranges such as primary data, the time switch
etc.
• to reparameterise the meter and the communication unit
MAP190
MAP120
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