Prometer 100 (R3E rack-mount / P3E wall-mount)

Precision Metering Series

User Manual
BGX501-943-R09
 CE MARKING DECLARATION OF CONFORMITY

Prometer 100 (R3E/P3E) conform to all the essential requirements of EU Measuring Instrument Directive
2004/22/EC and WEEE Directive 2012/19/EU.

Copyright © 2014-2019, SIHPL

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Table of Contents
1 Important safety information ........................................................................................................6
2 Disclaimer .......................................................................................................................................6
3 Introduction ....................................................................................................................................7
3.1 Prometer 100 meter....................................................................................................................................... 7
3.1.1 The Prometer 100 meter in an energy management system ......................................................... 8
4 Physical features............................................................................................................................9
4.1 Power supply, auxiliary and other details ...................................................................................................... 9
4.1.1 Field replaceable battery .............................................................................................................. 11
4.2 Front panel of Prometer 100-R.................................................................................................................... 12
4.3 Front panel of Prometer 100-W ................................................................................................................... 13
4.4 Connections to the Prometer 100-R ............................................................................................................ 14
4.5 Connections to the Prometer 100-W ........................................................................................................... 16
4.6 Sealing arrangement in Prometer 100 – R .................................................................................................. 17
4.6.1 Front cover sealing ....................................................................................................................... 17
4.6.2 Rear sealing arrangement ............................................................................................................ 18
4.7 Sealing arrangement in Prometer 100 – W ................................................................................................. 19
4.8 Pulse inputs and outputs ............................................................................................................................. 20
5 Prometer 100 and M-Cubed 100 BCS .........................................................................................21
5.1 M-Cubed 100 BCS ...................................................................................................................................... 21
6 Using the display .........................................................................................................................21
6.1 Auto-cycle .................................................................................................................................................... 22
6.2 Manual ......................................................................................................................................................... 23
6.3 Display buttons ............................................................................................................................................ 24
6.4 Menu example screens ............................................................................................................................... 25
6.5 Events .......................................................................................................................................................... 42
7 Functions ......................................................................................................................................44
7.1 Meter clock .................................................................................................................................................. 44
7.1.1 Time set ........................................................................................................................................ 44
7.1.2 Daylight saving time ...................................................................................................................... 44
7.1.3 External synchronisation............................................................................................................... 44
7.2 Support for different types of energy ........................................................................................................... 45
7.2.1 Defraud energy metering .............................................................................................................. 48
7.3 Instant values .............................................................................................................................................. 48
7.3.1 Overview ....................................................................................................................................... 48
7.3.2 Harmonics measurement.............................................................................................................. 49
7.3.3 THD............................................................................................................................................... 49
7.4 Daily energy snapshot ................................................................................................................................. 50
7.5 Digital inputs and outputs ............................................................................................................................ 50
7.5.1 Inputs ............................................................................................................................................ 50

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 7.5.2 Outputs ......................................................................................................................................... 50
7.6 Communications and security ..................................................................................................................... 52
7.6.1 Communication speed .................................................................................................................. 52
7.6.2 Security ......................................................................................................................................... 53
7.7 Loggers ........................................................................................................................................................ 53
7.7.1 Overview ....................................................................................................................................... 53
7.7.2 Logging interval and total channels .............................................................................................. 55
7.7.3 Storage of logged values .............................................................................................................. 55
7.8 Alarms ......................................................................................................................................................... 56
7.8.1 Overview ....................................................................................................................................... 56
7.8.2 Indication....................................................................................................................................... 58
7.8.3 Display of events .......................................................................................................................... 58
7.9 Maximum demand ....................................................................................................................................... 59
7.10 Historical registers ....................................................................................................................................... 60
7.11 Time of use .................................................................................................................................................. 60
7.11.1 Day type ........................................................................................................................................ 60
7.11.2 Season .......................................................................................................................................... 61
7.11.3 Special Days ................................................................................................................................. 61
7.11.4 TOU energy registers ................................................................................................................... 61
7.12 Billing cycle support ..................................................................................................................................... 61
7.12.1 Billing cycle ................................................................................................................................... 61
7.12.2 History of energy, rate and MD register........................................................................................ 61
7.12.3 History for the cause of billing register ......................................................................................... 61
7.12.4 Cumulative maximum demand registers ...................................................................................... 62
7.13 Meter reading .............................................................................................................................................. 62
7.14 Transformer compensation ......................................................................................................................... 62
7.14.1 Overview ....................................................................................................................................... 62
7.14.2 Instrument transformer compensations ........................................................................................ 62
7.14.3 Power transformer losses ............................................................................................................. 63
7.15 Quality of supply .......................................................................................................................................... 63
7.15.1 Voltage monitoring ........................................................................................................................ 63
7.16 Using the meter’s IEC 61850 network server .............................................................................................. 64
7.16.1 Configuring network settings ........................................................................................................ 64
7.16.2 Uploading CID and IEC 61850 program files ............................................................................... 66
Appendix A: Abbreviations ...............................................................................................................67
Appendix B: Material declaration .....................................................................................................68
Appendix C: Communication ports ..................................................................................................68
Appendix D: How to read meter through Ethernet port .................................................................70
Appendix E: Calculation principles ..................................................................................................75
Appendix F: Connection and general details ..................................................................................80
Appendix G: Events ...........................................................................................................................83

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Appendix H: Hardware security ........................................................................................................86
Frequently Asked Questions (FAQs) ...............................................................................................88

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1 Important safety information
Installation, wiring, testing and service must be performed in accordance with all local and national electrical
codes.
• Apply appropriate personal protective equipment (PPE) and follow safe electrical work practices.
• This equipment must only be installed and serviced by qualified electrical personnel.
• Turn off all power supplying this device and the equipment in which it is installed before working on the
device or equipment.
• Always use a properly rated voltage sensing device to confirm that all power is off.
• Do not perform Dielectric (Hi-Pot) or Megger testing on this device.
• Connect protective ground (earth) before turning on any power supplying this device.
• Live parts inside the meter so always disconnect all wires carrying dangerous voltages if opening the
meter cover.
• Do not use solvents or abrasive materials to clean the meter, use only a soft and dry cloth.
• The meter contains batteries that must be disposed of in a suitable manner at the end of its life.

Observe local safety norms when disposing of the product and any batteries that
it contains, at the end of their life, to ensure that they do not enter the household
waste stream.
Secure Meters (UK) Ltd Battery Producers Registration Number: BPRN03577

Danger of Electrocution

Read the instructions carefully before installing and using the product.

Failure to comply with the above safety measures could cause serious injuries.
If the meter is used in a manner not specified by the manufacturer, the protection
provided by connections may be impaired. The manufacturer shall not be held
responsible for failure to comply with the instructions in this manual.

2 Disclaimer
This user manual covers all types of the Prometer 100 (R3E / P3E) energy meter. Depending on the product
offering based on business proposal, some features or functionalities may or may not be available in the
supplied version. It is therefore recommended to refer the features or functionalities according to the product
proposal.
The details of complete software’s features are out of the scope for this document, please contact concern sales
representative for its details if required. Note that due to variations between computers and improvements in
software, the screen shots shown in this manual may vary slightly from the appearance of the software on your
system.
In the unlikely event of suspicion that the product is not functioning correctly, confirm by verifying the product
functionality with that of the reference product/instrument. Product complies and covers all the risk as per
relevant safety standards, hence additional risk assessment is not applicable.
For service and maintenance details, refer to the Prometer 100 (R3E / P3E) Installation and Basic
Commissioning Guide.

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Note: ‘Type’ and ‘Model’ are same for Prometer 100. You can use the terms ‘Type’ and ‘Model’ synonymously
in the document, wherever needed.

3 Introduction
This manual discusses the Prometer 100 (R3E / P3E) meter features and provides the information needed to
configure and use the meter. The manual covers all versions of Prometer 100-R (R3E rack-mount) and
Prometer 100-W (P3E wall-mount) meters.
By the time you are ready to use this guide, your meter should be installed, most basic setup should have been
performed, and communications/basic operation should have been verified. If the unit is not yet installed and
operational, refer to the Installation Guide shipped with the meter.
This section provides an overview of Prometer 100 meter and summarizes many of their key features.

3.1 Prometer 100 meter

Prometer 100 meter provides revenue-accurate measurements of voltage, current, power and energy; and is
complemented by extensive I/O capabilities, comprehensive logging and advanced power quality measurement.
The meter is intended for indoor installation and come with an extensive selection of pre-configured data
screens and measurements, so you can use the meter as it is shipped from the factory or customize it to fit your
unique requirements.
You can integrate the meter with software such as M-Cubed 100 or with other energy management, SCADA,
automation and billing systems, using multiple industry-standard communication channels and protocols
including IEC 61850.
Common meter applications
• Generation, transmission and distribution metering
• Revenue and tariff metering
• Total harmonic distortion monitoring
• Load management
• Integration with sub-station automation system
• Online monitoring system

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3.1.1 The Prometer 100 meter in an energy management system
You can use Prometer 100 meter as standalone device, but its extensive capabilities are fully realized when
used with software as part of an energy management system (EMS). EMS gives energy suppliers, service
providers, and large industrial and commercial energy consumers the tools to meet all the challenges and
opportunities of the new energy environment. EMS uses real-time information and control to directly address a
broad range of requirements throughout the power delivery chain. This system offers an integrated solution for
managing new billing structures, distributed generation, energy purchasing, energy cost control, operational
efficiency, power quality and reliability.
Applications that include the meter typically require additional equipment. Display and analysis software tools
are almost always used to manage, interpret and distribute the data measured or logged by a meter. There are
usually a variety of tools used, and often these tools are connected using different communications standards
and protocols. In many cases, a meter must also provide control capabilities and device-level data sharing.
The meter can adapt to many situations. Advanced communications allow data to be shared simultaneously
across multiple networks, built-in I/O provides monitoring and control capabilities, and a variety of display and
analysis tools to help you get the most from your power system.

Industry
Standard
Mounting

Multiple
Graphical
Communication
Display
Channels

Prometer
100

Multiple Pulse
Scalability and
Input and
Modularity
Output

Wide range
Voltage and
Current supply

Figure 1: An Overview

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4 Physical features
Prometer 100 is configurable for HV 3-phase 3-wire, HV 3-phase 4-wire or LV 3-phase 4-wire and is suitable for
mounting in a panel or on a wall (cemented, concrete or similar type of wall).
Prometer 100 has self-powered (or VT powered), auxiliary-powered; and a combination of self-powered and
auxiliary-powered variants. The auxiliary-powered variant also comes with dual auxiliary support so that you can
put AC or DC voltage for main and backup supply for powering up the meter. The auxiliary circuit is not intended
to be connected to the secondary of measurement VT. For example, the VT secondary supply of 63.5 V AC
(phase to neutral voltage) or 110 V AC (phase-to-phase voltage) needs to be supplied as a voltage input to the
product. Similarly three CTs, namely R/L1, Y/L2 and B/L3, need (as applicable) to be given as a current input to
the product of 1A/ 5A from secondary side.
Prometer 100-R Prometer 100-W
Meter Connection Type
HV3/HV4/LV4 HV3/HV4/LV4 or LV4

Based on hardware and software configuration, the meter variants can further be categorised as Advance,
Standard and Basic. The meter variant information can be viewed on the meter display under Default Display
Sequence.

4.1 Power supply, auxiliary and other details

Details for the power supply and measurement options are shown below:

Figure 2: Power supply options

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 No. of Aux power
Variants Main supply Backup supply supply inputs Range of Aux supply
supported

Measurement 60-240 V AC/DC ± 20%, 50/60 Hz

Aux. supply input One
Self+Aux power supply voltage terminals or
(Aux. 2) (Aux 2)
(VT supply) 24-48 V DC ± 20%

Measurement
Self power supply voltage terminals Not available Not available Not applicable
(VT supply)

Two (for dual

Aux. supply input Aux.) Both as 60-240 V AC/DC ± 20%,
Aux. 2 (for dual Aux. 1 & Aux. 2 50/60 Hz
Aux. 1 (for dual
Auxiliary power supply Aux.) or
Aux.)
Aux. 1 (for One (for single one as 24-48 V DC ± 20%
single Aux.) Aux.) (applicable only for Aux. 2)
Aux. 1

Table 1: Different power supply and other variants available in Prometer 100

• In case of auxiliary powered and self+auxiliary powered variants, meter will draw power from Aux 2
supply input. In its absence it will shift to Aux 1 supply (in case of auxiliary powered variant) and VT
supply (in case of self+auxiliary powered variant).
Note: Refer to alarm information for details on indication for auxiliary power supply failure.
• Do not connect voltage transformer (VT) to any of the Aux supply input terminal as a general practice. If
it is necessary to connect VT secondary to Aux input then make sure to connect it to the Aux1 supply
only in presence of Aux 2 so that burden on measurement VT secondary can be minimal.
• Connect your reliable auxiliary supply source like DC bank/AC lighting load/ Aux power transformer etc
to Aux 2 terminal only so that meter burden will be handled by it; or take your best judgment to connect
auxiliary supply source considering the rating and suitable operation of meter and best installation
practices followed.
• Ensure that the correct auxiliary voltage rating is used with the meter. The wrong voltage rating could
cause damage to the meter. Therefore it is recommended to verify and crosscheck the rating-plate on
the actual product in use at the site.
The firmware version can be viewed on the rating plate/ meter display (under default display sequence).

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 IEC

EN
Figure 3: Rating plate of Prometer 100-W

Figure 4: Rating plate of Prometer 100-R

Note: Barcode reader (compatible to barcode type ‘Code 39’) that is suitable for reading Direct Part Marking
(DPM) should be used to read the barcode information on the rating plate.
The meter has two calibration LEDs for Active (total/fundamental) and Reactive/Apparent energy; two alarm
LEDs and two pulse output LEDs which can be configured for visual indication of different status or events.
The calibration LED constant can be configured as either primary or secondary using M-Cubed 100. Primary
meter constant depends on the CT/VT ratio configured in the meter and can be selected from the available
values through display or M-Cubed 100. Secondary meter constant value is fixed as 25600 impulse/ k.

4.1.1 Field replaceable battery

The field replaceable battery is used as RTC backup. It is also used for meter reading through optical
communication and viewing display along with backlight, in absence of mains power supply. It only supplies
sufficient power to the meter reading over IEC 1107 port and display circuitry; and will not fully power-up the
meter.
The meter can be powered up in battery mode by pressing the Enter button for a maximum of ten seconds until
the display turns on (in case the meter does not power up, refer to page 91 for details). If no reading is
performed or no button is pressed in battery mode for 20 seconds, the battery will be disconnected. On
resuming the mains supply, the battery will be automatically disconnected.

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The battery can be replaced in the field. Take care while inserting the battery; make sure that the polarity and
fitment are correct.
Note:
• Useful life of field replaceable battery can be viewed on the meter display.
• The field replaceable battery will support meter RTC for 10 years in case it is not used for display
viewing or meter reading. (Useful life of field replaceable battery for meter reading and display viewing
is up to 6 hours)
• In absence of field replaceable battery, the internal battery supports meter RTC for 10 years.

4.2 Front panel of Prometer 100-R

Figure 5: Front view

The front cover is made of translucent plastic with a transparent window to view the display. The cover has two
top hinges which allow the front cover to swing-up, allowing access to the sealed button and field replaceable
battery. The cover is secured in position by a retaining screw and also has provision to seal it.

Figure 6: Front cover opened

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4.3 Front panel of Prometer 100-W

Figure 7: Front view

The front cover is made of translucent plastic with a transparent window to view the display. The top cover is
used to seal the field replaceable battery and sealed button. The extended terminal block cover is secured in
position by retaining screws and also has provision to seal it.

Figure 8: Top cover removed

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4.4 Connections to the Prometer 100-R
The diagram shows the rear connector with its pin diagrams for the meter. There are different options that may
be provided as per the specification agreed with the customer at the time of order.
The meter variant information can be viewed on the meter display under Default Display Sequence.

Connect L1 L2 L3 N Dual AUX

L/+ Terminal N/- Terminal
Supply
CT IN A01 A02 A03 NC
AUX1 B8 B9
CT OUT A1 A2 A3 NC
AUX2 B5 B6
VT B1 B2 B3 B0
Note:
NC - Not Connected

Digital Input/Output
8 Outputs and 4 configurable Input/Output
O/P 1 C1, C0 I/O 1 D3, D2
O/P 2 C1, C2 I/O 2 D9, D4
O/P 3 C4, C3 I/O 3 D7, D8
O/P 4 C4, C9 I/O 4 D5, D6
O/P 5 C7, C8
O/P 6 C7, C6
O/P 7 D0, C5
O/P 8 D0, D1
Note:
O/P - Fixed output
I/O - Configurable as input or output

Figure 9: Rear connector with pin details

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Note: For 3-phase 3-wire, refer to figure A
For 3-phase 4-wire, refer to figure B
For 3-phase 3-wire and 3-phase 4-wire, connections from B5 to D9 are the same.
For self-powered variant, Aux.1 (B8 and B9) supply is not available.
L1=R, L2=Y, L3=B
Figure 10: Connection diagram
Note: One side of the CT secondary wiring should be earthed according to local practice.
The recommended size of the CT, VT and Aux power supply cable is 2.5 sq mm with lugs type as ring (M3 type)
for CT and H type for Aux and VT terminals.
In case of Prometer 100-R the internal earthing cable between the meter and the rack should also be
connected, and for this an M4 size screw is used in the meter and in the rack. The same ring type connector as
used in the CT connection can also be used.
The internal earthing cable should be about 5-10 cm in length to allow for ease of fitting and access and not
fouling with sharp edges of rack etc. Finally a proper earthing cable from rack to earth should be put up by
installer. Other accessories or shipway kit is supplied based on the requirement like seals, communication cords
etc.
Product dimensions are compatible to DIN 43862, but in case if product is to be fitted in already available rack
or user wants to install it in a specific customised rack then suitable back plate can be used to fit the product.
Note: For installing the meter into rack having third party back-plate connector, check connections’ compatibility
before installation.

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4.5 Connections to the Prometer 100-W
Connections to the Prometer 100-W are made on the meter terminal under the terminal cover.
The meter variant information can be viewed on the meter display under Default Display Sequence.

Connect R/L1 Y/L2 B/L3 N Dual AUX

L/+ Terminal N/- Terminal
Supply
CT IN 1 4 7 -
AUX 1 13 14
CT OUT 3 6 9 -
AUX 2 15 16
VT 2 5 8 11

Digital Input/Output
7 Outputs and 4 configurable Inputs/Output
O/P 1 18, 19 I/O 1 32, 33
O/P 2 20, 21 I/O 2 34, 35
O/P 3 22, 23 I/O 3 36, 37
O/P 4 24, 25 I/O 4 38, 39
O/P 5 26, 27
O/P 6 28, 29
O/P 7 30, 31
Note:
O/P - Fixed output
I/O - Configurable as input or output

Only for Basic variant

2 fixed Digital Outputs
O/P 3 36, 37
O/P 4 38, 39
Note:
O/P - Fixed output
Figure 11: Connector with pin details

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 Current, voltage and auxiliary supply connections

Pulse Input/ Output connections

Figure 12: Connection diagram
The recommended size of the copper cable is 2.5 sq mm for current and voltage terminals; and 1.5 sq mm for
auxiliary and pulse I/O terminals. However, bigger size cables can be used considering the bore diameter which
is 5.6 mm, reliable field installation practices and ensuring reliable electrical connections.

4.6 Sealing arrangement in Prometer 100 – R

This section describes the sealing arrangement in Prometer 100-R.

4.6.1 Front cover sealing

The front cover can be sealed in the closed position. This will stop the front cover from being opened and
restrict unauthorised access to the sealed button and internal areas. There are also sealing points on either side
of the meter for securing it to a rack or frame. The sealing bore diameter is 2.0 mm and is suitable for seals.

Transparent
Window
Translucent
Front
Cover

Right-hand side
Left-hand side Sealing & Locking point
Sealing & Locking point Locking Screw
& Sealing points

Figure 13: Front cover sealing arrangement

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4.6.2 Rear sealing arrangement
When the meter is fitted into the rack, a cover can be fitted which conceals all the rear connectors. The figure
below show the sealing points for the rear cover. The figure shows the single rack example with an enlarged
detailed view of the sealing points.

Figure 14: Front and rear sealing points – 11” rack installation
Note: IEC 1107 sealing cover slides upwards till 35 mm and hence refer to the installation guide in case where
stacked up installations are done for rack products. This sealing cover if not sealed can be detached from the
window if needed.
Note: The meter is sealed at the manufacturing end using manufacturer-specific seals (as shown below) to
prevent unauthorised personnel from gaining access to meter internals.

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4.7 Sealing arrangement in Prometer 100 – W
The meter incorporates sealing bars and screws with through-holes, through which traditional lead/wire seals
can be inserted. The sealing bore diameter is 2.0 mm. When utilised, these lead/wire seals can help prevent
unauthorised personnel from gaining access to meter internals or to button under the cover. The sealing
provision in Prometer 100-W is as follows:
• The front cover can be sealed through the two sealing points under the terminal cover.
Note: The front cover is sealed at the manufacturing end using manufacturer-specific seals (as shown
below) to prevent unauthorised personnel from gaining access to meter internals.

• The secondary terminal cover can be sealed through a sealing point.

• The extended terminal cover can be sealed through the two sealing points.
• The top cover can be sealed through the two sealing points.
• The 1107 optical communication port can be sealed using rotational seal.

Figure 15: Sealing points

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4.8 Pulse inputs and outputs
The product support multiple pulse inputs and outputs. A maximum of eight pulse outputs (for Prometer 100-R)
and seven pulse outputs (for Prometer 100-W); and four configurable pulse input/ output can be provided as per
the specification agreed at the time of order.
Two pulse outputs are linked to two pulse output LEDs indication as available on front side of meter so that user
can have a visualisation sort of feature by physically seeing the LEDs. The following table shows the pulse
outputs (of Prometer 100-R and Prometer 100-W, refer to Figure 10 and Figure 12 for details) that are linked to
the pulse output LEDs.

Pulse Output LED Pulse Output of Prometer 100-R Pulse Output of Prometer 100-W
LED 1 3 2
LED 2 4 3

Note: For Basic variants, pulse outputs 3 and 4 (refer to Figure 11) are linked to pulse output LEDs LED 1 and
LED 2 respectively.

The pulse output LEDs can be configured through M-Cubed 100 either at factory or in field. One pulse input can
be used for time synchronisation application.
Configurable pulse input/output rating: 24 to 240 V AC/DC. Isolation will be available for each individual
input/output. In case of over voltages, pulse inputs are protected by clamping the input voltage to 320 V AC.
Pulse output rating: 24 to 48 V DC or 48 to 240 V AC/DC @ 100 mA (Pulse outputs will have volt free contact).
The only one rating will be applicable for entire block (each containing four outputs) and so isolation available
will be for entire block. The outputs are of solid-state type and when the meter is turned off, they are open.
It is recommended to use conditioned power supply (isolated from Mains) for driving loads through pulse output
of product so that any malfunction in the load or related circuit will not affect the metering. A tentative scenario
for reference is shown in below diagram.

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5 Prometer 100 and M-Cubed 100 BCS
This section describes the various operations that can be performed using the M-Cubed 100 BCS with Prometer
100 meter.

5.1 M-Cubed 100 BCS

Figure 16: Prometer100 and M-Cubed 100 BCS

M-Cubed 100 (stands for Modular Meter Management) is a software suite for programming meters, reading data
and reporting from energy meters. M-Cubed 100 has separate modules that can be configured to suit particular
applications and access rights required by individual users.
M-Cubed 100 can be used for:
• Configuration
• Meter Reading
• Data Viewing
Refer to M-Cubed 100 help for detailed description of all these functions.

6 Using the display

This section describes how the Prometer 100 display can be used to read measurement values and also to
control certain functions in the meter.
There are two types of display mode: Auto-cycle and Manual.
The display parameters are arranged in display sequences. There is no limitation of setting different parameters
to be displayed in an individual sequence, but in general, the meter can have a maximum of 242 display
parameters including auto-cycle and manual display sequences. The maximum number of display parameters
for a meter depends on the requirement.
The meter display can be configured using M-Cubed 100 to show single parameters with OBIS codes,
Import/Export quantities with +/- sign, elapsed/ remaining time of the rising demand period.

Slight differences may be observed between net derived energy and the equivalent displayed values. This is not
an error but due to the truncating effect of the display value. There is no energy loss and the difference will not
increase or decrease with time.
For dial test (zero power factor situations for reactive energy registers logging) refer to the main energy register
display for reactive import (Q1+Q2) and reactive export (Q3+Q4). Similarly one needs to first ensure about tariff
being configured for apparent energy logging either in lag only or lag + lead mode before performing dial test on
display.

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6.1 Auto-cycle
Auto-cycle is the default display mode. A large number of parameters can be configured for this mode using M-
Cubed 100. The display delays can be configured in the field using M-Cubed 100 or by the display keys. Once
the display button is pressed, the auto-cycle mode will be interrupted and will switch to manual mode. If no
button is pressed in manual mode, the display will time out and revert to auto-cycle mode. The display will
resume from the last displayed parameter. The display backlight remains ON in auto-cycle mode as per the
configuration done by the user.
The example of auto-cycle displays are shown below (details can be checked as agreed in purchase order):

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6.2 Manual
Display parameters are grouped in to a number of sequences. Each sequence parameters can be individually
selected. A considerable number of parameters can be assigned in manual mode.
Display groups
The display parameters are arranged into groups for easier navigation.
• Default display sequence: This sequence consists of default display parameters (not configured by
tariff). The meter variant information can be viewed on the meter display under Default Display
Sequence.
• User configurable display sequences: These sequences consist of user selected display parameters.
Sequence name can also be configured. Up to seven display sequences can be configured.
• Sealed button display sequence: This sequence can be configured using M-Cubed 100. The sealed
button display sequence can be accessed by pressing the sealed button.
• Favourite sequence: This sequence is configured in field only using display key and a maximum of 20
parameters can be selected from other display sequences.
• Configuration menu: The configuration menu is password protected which can be accessed only by
users authorised to set-up and enable features such as calibration LED, display delays, delete favourite
sequence, acknowledge battery change, calibration LED constant, MODBUS (ID and baud rate), IP
configuration (static IP, subnet mask and gateway IP) and display language. The configuration menu
password can be configured using M-Cubed 100.
• Abbreviations: This sequence consists of full form of all the abbreviations used in the displays.

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6.3 Display buttons
The meter has four push buttons. The sealed button can be used for performing MD reset, for navigating
through the sealed button display sequence or accessing hardware security feature depending on the
requirement and is behind a sealable cover. The other three buttons are used for navigating through the display
and configuration menu options.

Figure 17: Push buttons

A display sequence/configuration menu can be selected by pressing the Enter button. A navigation screen will
appear showing all the available options. The Up and Down buttons can then be used to choose an option.
Press the Enter button to select your choice.

Figure 18: Selecting a sequence

Once you have selected a target display sequence/configuration menu, you can then use the Up/Down buttons
to scroll through that selected display sequence/configuration menu. Parameters are cyclically displayed in the
selected display sequence/configuration menu, i.e. after the last parameter in the list is displayed, the display
will return to the first in the list, and so on.
Press the Enter button to return to the immediate parent menu.

Page 24 of 92 Prometer 100 User Manual BGX501-943-R09

6.4 Menu example screens
Default display sequence
Select the Default Display Sequence from the top line menu. The following screens will be displayed:

Figure 19: Default display sequence

The default display sequence is shown below:

This display shows the date, time This display shows the date and
and active quadrant information as time; meter serial number, primary
per IEC 62053-23. and secondary values for voltage
and current; maximum current and
meter type (HV 3P4W, HV 3P3W
or LV 3P4W).
The display shows the meter variant information. There are different options
that may be provided as per the specification agreed with the customer at
the time of order. The available options are Advance, Standard and Basic.
Advance:
Hardware configuration- Precision energy meter with accuracy 0.2S/0.5S,
communication RS232/RS485/IEC 61850 (left and right modules) and
Ethernet port; digital input/output - 0, 4 configurable, 4 configurable and 7
outputs or 4 configurable and 8 outputs.

Standard:
Hardware configuration- Precision energy meter with accuracy 0.2S/0.5S,
communication RS232/RS485/IEC 61850 (left and right modules) and
Ethernet port; digital input/output - 0, 4 configurable, 4 configurable and 7
outputs or 4 configurable and 8 outputs.
Software configuration- CT/VT error compensation and power transformer
loss are not applicable and only single logger is available.

Basic:
Hardware configuration- Precision energy meter with accuracy 0.5S,
communication RS232/RS485 (left module); and digital outputs - 0 or 2
outputs.
Software configuration- CT/VT error compensation and power transformer
loss are not applicable and only single logger is available.
Note: The Basic variant is not applicable for Prometer 100 Rack-mount
meter.

BGX501-943-R09 Prometer 100 User Manual Page 25 of 92

 (In case of 3-phase 4-wire) (In case of 3-phase 3-wire)

(In case of 3-phase 4-wire) (In case of 3-phase 3-wire) (In case of 3-phase 4-wire)

(In case of 3-phase 3-wire)

This display shows that the VT This display shows that the Aux 2
supply / Aux 1 supply is ok and supply is not ok, as supply is lost
supply is not lost. since 17 Aug 2017 14:54 hrs.
Note: Note: ‘NOK’ means Not Ok.
‘NA’ means Not applicable. ‘NA’ means Not available.
On restoration of the supply, the
Aux 2 supply status will be
displayed as ok along with the
period of time during which supply
was lost.

Page 26 of 92 Prometer 100 User Manual BGX501-943-R09

 (In case of auxiliary powered)

(In case of self powered) (In case of battery mode) The meter has seven pulse
outputs and four configurable
pulse input/output. Out of four
configurable pulse I/Os, three
(pulse I/Os 1, 2 and 3) are
configured as pulse outputs and
one (pulse I/O 4) is configured as
pulse input.

If Energy Pulse Weight of a pulse This display shows the energy This display indicates that out of
output is 0.0005 kWh, it means pulse weight of pulse outputs 5, 6 four configurable pulse I/Os, two
that when 0.0005 kWh amount of and 7. (pulse I/Os 3 and 4) are
energy is consumed then one configured as pulse outputs and
pulse is generated. two (pulse I/Os 1 and 2) are
This display shows the energy configured as pulse inputs.
pulse weight of pulse outputs 1, 3 Note:
and 4; and also indicates that ‘NA’ means Not applicable.
energy parameter is not
‘- - -‘ means that energy
configured for pulse output 2.
parameter is not configured for
pulse output.

BGX501-943-R09 Prometer 100 User Manual Page 27 of 92

 Note:
Refer to Abbreviations for the full form of the abbreviations used in the
displays.

The following displays appear only in meter variant supporting IEC 61850 communication.

User configurable display sequences

Up to seven user configurable display sequences can be defined along with sequence name e.g. Instant
Parameters, see Figure 20 below. The sequence name can have a maximum of 20 alphanumeric characters.
The illustrations shown below are indications of how the sequences and their respective displays will be
displayed. The final sequences and their corresponding displays are dependent on the meter configuration.

Page 28 of 92 Prometer 100 User Manual BGX501-943-R09

 Figure 20: User configurable display sequences

Energy registers
In this example the user defined sequence has been configured to view the energy registers and an appropriate
sequence name has been chosen for easy identification. Always choose a user friendly and self-explanatory
name for your sequence. For example, “Energy Register” is used as the name of the sequence.

Use the Up/Down buttons to scroll to the Page 1: Energy registers

sequence. The selection will be highlighted.
Press the Enter button to open the sequence.
Use the Up/Down buttons to scroll within the sequence and view the
various screens.

BGX501-943-R09 Prometer 100 User Manual Page 29 of 92

 Note:
Refer to Abbreviations for the full form of the abbreviations used in the displays.

Demand data
This sequence has been set up to capture demand values.

Use the Up/Down buttons to scroll to the Page 2: Demand sequence.

The selection will be highlighted.
Press the Enter button to open the sequence.
Use the Up/Down buttons to scroll within the sequence and view the
various screens.

This display shows the value of

History-3, CMD TOU register 1.
Refer to meter configuration for time
zone details for TOU register 1.

Note:
Refer to Abbreviations for the full form of the abbreviations used in the displays.

Page 30 of 92 Prometer 100 User Manual BGX501-943-R09

Instantaneous parameters
This sequence has been set up to capture instantaneous parameters.

Use the Up/Down buttons to scroll to the Page 3: Instant Data

sequence. The selection will be highlighted.
Press the Enter button to open the sequence.
Use the Up/Down buttons to scroll within the sequence and view the
various screens.

BGX501-943-R09 Prometer 100 User Manual Page 31 of 92

 The time can be configured as
elapsed / remaining time of the
demand period.

Note:
Refer to Abbreviations for the full form of the abbreviations used in the displays.

Page 32 of 92 Prometer 100 User Manual BGX501-943-R09

General
This sequence details general displays.

Use the Up/Down buttons to scroll to the Page 4: General information

sequence. The selection will be highlighted.
Press the Enter button to open the sequence.
Use the Up/Down buttons to scroll within the sequence and view the
various screens.

This display shows that the billing

action is performed due to change
in CT/VT ratio.

Note:
Refer to Abbreviations for the full form of the abbreviations used in the displays.

Graphical display parameters

This sequence has been set up to view the graphical displays such as bar graphs, phasor diagrams and
waveforms.

Use the Up/Down buttons to scroll to the Page 5: Graphical display

parameters sequence. The selection will be highlighted.
Press the Enter button to open the sequence.
Use the Up/Down buttons to scroll within the sequence and view the
various screens.

BGX501-943-R09 Prometer 100 User Manual Page 33 of 92

 Bar graph for Logger 1 Bar graph for Logger 2 Phasor diagram (3P4W)
C1, C2, C3 and C4 is the C1, C2, C3 and C4 is the
consumption of last four SIP consumption of last four SIP

Note:
Refer to Abbreviations for the full form of the abbreviations used in
Phasor diagram (3P3W) the displays.

THD data
This sequence has been set up to capture THD data.

Use the Up/Down buttons to scroll to the Page 6: THD Data sequence.
The selection will be highlighted.
Press the Enter button to open the sequence.
Use the Up/Down buttons to scroll within the sequence and view the
various screens.

Note:
Refer to Abbreviations for the full
form of the abbreviations used in the
displays.

Page 34 of 92 Prometer 100 User Manual BGX501-943-R09

Events
This sequence details events and status. Events are discussed in section 6.5
The following table shows example of various types of events shown on the meter display at any point of time.

Example of event
Type of event Description
shown on display
THD%: 1 _ _ The message indicates current high THD (%) in
L1 phase.
Bypass The message indicates current terminal shorting
in any phase CT.
Open _ 2 _ The message indicates current circuit open in L2
phase CT.
CT related events
Unbalance The message indicates current unbalance.
Reverse: _ _ 3 The message indicates reverse current direction
in L3 phase.
Miss: 1 _ 3 The message indicates current missing in L1 and
L3 phase.
THD%: _ _ 3 The message indicates voltage high THD (%) in
L3 phase.
Low The message indicates under voltage in any
phase.
High The message indicates over voltage in any phase.
VT related events
Unbalance The message indicates voltage unbalance.
Miss: 1 _ _ The message indicates missing voltage in L1
phase.
Invalid The message indicates invalid voltage.
ND The message indicates neutral disturbance.
Magnet The message indicates magnetic field detection.
ETBC The message indicates extended terminal block
cover open detection.
Cover The message indicates front cover open
Other than CT/VT events detection.
Feeder fail The message indicates feeder supply fail or all
phases are missing.
Invalid Ph Association The message indicates invalid phase association.
LPF The message indicates system low power factor.

BGX501-943-R09 Prometer 100 User Manual Page 35 of 92

 Use the Up/Down buttons to scroll to the Page 7: Events sequence. The
selection will be highlighted.
Press the Enter button to open the sequence.
Use the Up/Down buttons to scroll within the sequence and view the
various screens.

This display shows that the This display shows that the following
This display shows that the
following CT related events have other than CT/VT events have
following VT related events have
occurred: occurred:
occurred:
• reverse current direction • feeder supply fail or all
• missing voltage in all
in all phases phases missing
phases
• current circuit open in all • neutral disturbance
• voltage high THD in all
phases
phases • magnetic field detection
• current terminal shorting
• invalid voltage • front cover open detection
in any phase
• voltage unbalance • extended terminal block
• current missing in all
• over voltage in any cover open detection
phases
phase • invalid phase association
• current THD in all
phases • under voltage in any • system low power factor
phase
• current unbalance

Page 36 of 92 Prometer 100 User Manual BGX501-943-R09

Scroll lock
Locking of individual parameter in user configurable display sequences (manual displays) –

Up

press and hold

the Up Key for
5 seconds

Figure 21: Locking the manual display parameter

The screen can be locked to show a desired parameter. To screen lock a parameter, select the parameter using
the menu buttons (this is applicable under user configurable display sequences only). Press the Up key for 5
seconds. During this process the display will temporarily move to the next parameter, then after 5 seconds will
display your selection.
To unlock the screen (i.e. revert to auto-cycle mode) press the Up key for 5 seconds.

Favourite sequence
This sequence is used for your selection of display parameters.

press and hold

the Down Key
for 5 seconds

Down

Figure 22: Adding parameter to favourite sequence

To add a parameter, go to the display containing the parameter that you require. Once the required display is
selected press the down key for 5 seconds, the selected parameter will now be added to your favourite
sequence.
When the favourite sequence is full, you will need to delete complete list in this sequence to make space for the
new one, so be sure before selecting parameters as maximum 20 parameters can be selected in favourite
display sequence.
To delete the complete list of Favourite parameters, go to the configuration menu and select ‘Delete Fav.
Sequence’.

Configuration menu

Figure 23: Front view showing calibration LEDs

BGX501-943-R09 Prometer 100 User Manual Page 37 of 92

The configuration menu is used to set-up and enable features such as the calibration LEDs, display delays,
calibration LED constant, acknowledge battery change, MODBUS configuration and display language on
display. They are also used to manage your favourite selections.
The configuration menu is password protected which can be accessed only by users authorised to change the
above configurations.
At the password prompt enter the 6-digit password (default password is ‘000000’) using Up and Down buttons
Use the Down key to enter a digit at the cursor position and use the Up key to move the cursor to the right while
entering a digit. After completing the entry, press the Enter button to confirm. Correct password gives access to
the first screen of configuration menu. An incorrect password will display ‘Incorrect Password’ message.

The Prometer 100 meter display can be set to different languages. The following languages are available:
• English
• Swedish
• German
• French
• Spanish
• Italian
• Russian
• Arabic
• Vietnamese
• Indonesian
The configuration menu is shown below.

Use the Up/Down buttons to scroll to the Configuration Menu. The

selection will be highlighted.
Press the Enter button and enter the correct password using Up and
Down buttons to open the sequence.

Use the Up/Down buttons to scroll Back- This option is used to go to

to the required option and press the previous menu
the Enter button to select.

Page 38 of 92 Prometer 100 User Manual BGX501-943-R09

 The display delays can be configured in the field using M-Cubed 100 or by the display keys.
Auto Cycling Delay - Auto-cycle displays advance sequentially to the next display in every 5 to 120 seconds
(as configured in the meter).
Return to Auto Cycling - If no button is pressed in manual mode for 10 to 240 seconds (as configured in the
meter) the display will time out and revert to automatic display cycling sequence.
Display Off Duration - After completing one full automatic display cycling sequence, there will be a delay of 0
to 240 seconds (as configured in the meter) before the display resumes from the beginning.

Press the Up button for 5 seconds

to go to the previous page.

Note: The calibration LED

constant configuration is
applicable only for Primary meter
constant.

BGX501-943-R09 Prometer 100 User Manual Page 39 of 92

 The display language can be
configured in the field using M-
Cubed 100 or by the display keys.

Note:
Refer to Abbreviations for the full form of the abbreviations used in the
displays.

The following displays are self-explanatory and occur at the time of events such as configuration, file download
etc. and are included here for your reference only.

Page 40 of 92 Prometer 100 User Manual BGX501-943-R09

Abbreviations
This sequence is used to display the full form of the abbreviations used in the displays.

Use the Up/Down buttons to scroll to the Abbreviations sequence. The

selection will be highlighted.
Press the Enter button to open the sequence.
Use the Up/Down buttons to scroll within the sequence and view the
various screens.

BGX501-943-R09 Prometer 100 User Manual Page 41 of 92

User selectable display examples

Battery Status Battery Status Battery Status

(Less than 20%) (Greater than equal to 30%) (Less than 30% and greater than or
equal to 20%)

6.5 Events
The Prometer 100 has a number of defined events that are stored in the meter’s event log when they occur and
restore. The events are arranged into different logical compartments with defined number of events logging. An
event is displayed with a description and a time stamp in M-Cubed 100. All the events will be displayed in
following categories in meter display as– voltage related, current related; and events other than voltage and
current related. The events do not enforce any electrical value changes inside the meter.
Events are logged if the condition for the detection of an event persists for a specified duration, known as the
delay. Events can have a different delay for occurrence and restoration as applicable. The delay for an
occurrence as well as for restoration is configurable for respective event as applicable. However some events
like power on/off, magnet will not have any restoration time because of the nature and type of the event.
Similarly some events can have the same condition of tamper detection as per the nature and type of the event
in a given circumstances.
The general events supported are as follows –
1. Missing voltage phase-wise
2. Voltage unbalance
3. Invalid voltage
4. Over voltage
5. Under voltage
6. Reverse current direction phase-wise
7. Current missing phase-wise
8. Current unbalance
9. Feeder supply fail (All phase missing)
10. Power failure
11. Invalid phase association
12. Current circuit open
13. Current circuit shorting
14. Front cover and ETBC open detection in power on/off condition (applicable for Prometer 100-W)

Page 42 of 92 Prometer 100 User Manual BGX501-943-R09

 15. Low power factor
16. Neutral disturbance (ND)
17. Magnetic field detection
There are other customised events like %THD for voltage and current are also supported in meter.
Note: Phase 2 current reversal, Phase 2 current miss, CT open, CT bypass, neutral disturbance and invalid
phase association are not applicable for 3-phase 3-wire.

BGX501-943-R09 Prometer 100 User Manual Page 43 of 92

7 Functions
This section provides an overview of the functions available in Prometer 100. All functions in the meter can be
both configured and read in M-Cubed 100. In many cases, M-Cubed 100 can also export data to a file or print
out data.

7.1 Meter clock

The Prometer 100 has an integrated real-time clock for time-dependent functions. Information about time
adjustment and daylight saving time status is recorded with tags on the logged values (refer to the section
Loggers on page 53). Time set is also noted as an event in the event log; see the section Display of events (pg.
58).

7.1.1 Time set

The meter’s date and time can be set to an absolute point in time. Instantaneous adjustment of the meter’s time
can influence logged values. For this reason, instantaneous adjustment of the meter clock is primarily intended
for use at initial configuration of the meter.

7.1.2 Daylight saving time

Prometer 100 offers the alternative of letting the meter clock follow daylight savings time. At a specified date,
the meter clock is adjusted forward, and at another, adjusted backward. Prometer 100 can store 25 years of
DST configuration.
Example: On 28 March the clock is to be adjusted forward, from 02:00 to 03:00. The adjustment back to
standard time is to occur on 31 October at 3:00 (daylight savings time) when the clock is to be set back to
02:00. The following is set in the meter: Begin March, 28, 02:00. End October, 31, 03:00 and the standard time
is to be adjusted by 60 minutes.

7.1.3 External synchronisation

The meter time can be adjusted by a pulse on one of the meter’s digital inputs. When a pulse is registered, the
clock is adjusted to the closest multiple of a specified synchronisation interval. If the synchronisation interval is,
for example, one minute and the time is 13:00:10, a pulse will adjust the clock to 13:00:00. If the time had
instead been 13:00:52, the clock would have been adjusted to 13:01:00. This will depend upon the time
adjustment limit configured in the meter.
Available synchronisation intervals are:

1, 2, 5, 10, 15, 20, 30, 45 and 60 minutes

12 and 24 hours
A digital input must be configured for clock synchronisation (refer to the section Digital inputs and outputs on
page 50).
Note: Meter will not sync the time if the time difference is more than the time adjustment limit configured in the
meter. By default, the time adjustment limit is set as 25 seconds. The time adjustment limit can be configured as
any value between 0 to 30 seconds.

Time synchronisation through SNTP

Prometer 100 also supports time sync through SNTP (Ethernet communication) protocol. Time sync through
SNTP is considered most suitable method in revenue as well as power quality application.
The time synchronisation source and the duration between time synchronisation messages determine the
accuracy of the meter’s clock. The clock is adjusted by synchronising the meter’s time with another time source.
Simple Network Time Protocol (SNTP) is a simplified version of Network Time Protocol (NTP) that is used to
synchronise computer clocks on a network.
Note: If you are configuring your meter clock remotely from another time zone, make sure you modify the
meter’s configuration to match local time.
Time synchronisation triggers automatically at defined interval and request is sent to the SNTP server.

Page 44 of 92 Prometer 100 User Manual BGX501-943-R09

Note: To help maintain data integrity, some energy management systems impose a blackout rule where time
synchronisation triggers near energy interval boundaries are ignored.
Use only one time synchronisation source or method on each network to help prevent conflicting time
synchronisation information. For meters connected to energy management system, the same time
synchronisation method must be set for all meters connected to the system to help prevent timestamp
inconsistencies.
For time synchronisation sources with a resolution of one second or more, the meter time is only adjusted by a
time synchronisation message if the difference between the meter time and the message time is equal or less
than configured time adjustment limit. By default, the time adjustment limit is set as 25 seconds.
For SNTP time synchronisation, your meter must be connected to an Ethernet network that has an active SNTP
server and be configured with the server’s information.
Note: Meter will not sync the time if the time difference is more than the time adjustment limit configured in the
meter. By default, the time adjustment limit is set as 25 seconds. The time adjustment limit can be configured as
any value between 0 to 30 seconds.

7.2 Support for different types of energy

Prometer 100 meter is used for feeder based applications where energy may flow in both the directions.
Prometer 100 is an Import Export type meter; its metering unit is capable of logging energy in both directions.

Note: The above representation is shown as per IEC62053-23 (ed. 1.0).

Quadrants Phase angle Current relative to voltage
I 0 to 90° Lagging
II 90 to 180° Leading
III -180 to -90° or 180 to 270° Lagging
IV -90 to 0° or 270 to 360° Leading

BGX501-943-R09 Prometer 100 User Manual Page 45 of 92

Prometer 100 supports different tariff structures and number of Energy types (refer to Table 2). Any combination
of energy types can be provided as per the specification agreed at the time of order.
The energy channel registers are shown below:

Sr. TOD MD TOD Daily Logger 1 Logger 2

Parameters Instantaneous Billing
No. / UMD Rate Energy
Active Import Total
1 Y Y Y Y Y Y Y
(Q1+Q4)
Active Export Total
2 Y Y Y Y Y Y Y
(Q2+Q3)
Active Import
3 Fundamental (without Y Y Y Y Y Y Y
harmonics) (Q1+Q4)
Active Export
4 Fundamental (without Y Y Y Y Y Y Y
harmonics) (Q2+Q3)
Reactive Import while
5 Y Y Y Y Y Y Y
Active Import – Q1
Reactive Import while
6 Y Y Y Y Y Y Y
Active Export – Q2
Reactive Export while
7 Y Y Y Y Y Y Y
Active Export – Q3
Reactive Export while
8 Y Y Y Y Y Y Y
Active Import – Q4
Apparent – While
9 Active Import (See Note Y Y Y Y Y Y Y
2)
Apparent – While
10 Active Export (See Y Y Y Y Y Y Y
Note 2)
Reactive Import
11 Y Y Y Y Y Y Y
(Q1+Q2)
Reactive Export
12 Y Y Y Y Y Y Y
(Q3+Q4)
Reactive Inductive
13 Y Y Y Y Y Y Y
(Q1+Q3)
Reactive Capacitive
14 Y Y Y Y Y Y Y
(Q2+Q4)
Net Active (Imp – Exp)
15 Y Y N N Y Y Y
*
Net Reactive (Q1+Q2-
16 Y Y N N Y Y Y
Q3-Q4) *
17 Net reactive High* Y Y N N Y Y Y
18 Net reactive Low* Y Y N N Y Y Y
19 Reactive High Import Y Y N N Y Y Y
20 Reactive Low Import Y Y N N Y Y Y
21 Reactive High Export Y Y N N Y Y Y
22 Reactive Low Export Y Y N N Y Y Y
Active Import Total
23 Y Y N N Y Y Y
(Q1+Q4) - L1
Active Import Total
24 Y Y N N Y Y Y
(Q1+Q4) - L2

Page 46 of 92 Prometer 100 User Manual BGX501-943-R09

 Active Import Total
25 Y Y N N Y Y Y
(Q1+Q4) - L3

Active Export Total Y

26 Y Y N N Y Y
(Q2+Q3) - L1

Active Export Total

27 Y Y N N Y Y Y
(Q2+Q3) - L2
Active Export Total
28 Y Y N N Y Y Y
(Q2+Q3) - L3
Active Import
Fundamental (without
29 Y Y N N Y Y Y
harmonics) (Q1+Q4) -
L1
Active Import
Fundamental (without
30 Y Y N N Y Y Y
harmonics) (Q1+Q4) -
L2
Active Import
Fundamental (without
31 Y Y N N Y Y Y
harmonics) (Q1+Q4) -
L3
Active Export
Fundamental (without
32 Y Y N N Y Y Y
harmonics) (Q2+Q3) - L
1
Active Export
Fundamental (without
33 Y Y N N Y Y Y
harmonics) (Q2+Q3) -
L2
Active Export
Fundamental (without
34 Y Y N N Y Y Y
harmonics) (Q2+Q3) -
L3
All phase Forwarded
35 Y Y Y Y Y Y Y
Active Total
All phase Forwarded
36 Y Y Y Y Y Y Y
Reactive Lag
All phase Forwarded
37 Y Y Y Y Y Y Y
Reactive Lead
All phase Forwarded
38 Y Y Y Y Y Y Y
Apparent Total
All phase Gross Active
39 Y Y Y Y Y Y Y
Import Total
All phase Gross Active
40 Y Y Y Y Y Y Y
Export Total
41 Defraud energy N Y N N N N N

Table 2: Energy channel registers

Note:
1) All the bi-directional energy registers (* marked) will have sign indication (‘-‘sign will be available for
negative value and no sign for positive value).
2) In ‘Apparent’ and ‘Net Active’ energy calculation, ‘Active’ energy can be either ‘fundamental’ or ‘total’.
This can be configured through M-Cubed 100.
3) Single phase measurements (23-34) are supported by the 4-wire configuration. L2 phase
measurements (24, 27, 30 and 33) are not supported by 3-wire configuration.
4) Apparent energy can be configured as Lag only or Lag + Lead.

BGX501-943-R09 Prometer 100 User Manual Page 47 of 92

For energy types 17-22:
Reactive high and reactive low energies are special registers, which can increment based on voltage and
reactive load conditions.
The reactive high and reactive low registers increment only when certain voltage conditions are met and based
on these, one or none of these may increment at any particular point of time. The voltage conditions are two
average voltage levels Vlowthres (low threshold voltage) and Vhighthres (high threshold voltage). If average voltage
falls below Vlowthres, then reactive low register is incremented. Similarly if average voltage is above Vhighthres, then
reactive high register is incremented. If average voltage is between Vlowthres and Vhighthres, then none of reactive
high or reactive low register is incremented. By default the average voltage levels are set to 97% for Vlowthres and
103% for Vhighthres.
If low voltage is detected, then none of reactive high or reactive low register is incremented. By default the low
voltage limit is set to 60% and hysteresis for low voltage is set to 3%.
Hysteresis means that the limit for a state and the limit for when it is restored are different. This is to avoid
several states being registered when the voltage level varies around a limit. The hysteresis limit is always
midway between the low limit and nominal voltage.
For example, if the low voltage limit is 60% and hysteresis is 3% then the low voltage event occurs when any
phase voltage falls below 57% and restores when the phase voltage becomes 60%.

Recording of all supported energy types is possible but only those energy types are logged into the memory
which is specified by the configuration file. An individual register is provided for all selected energy types. These
register are called Main Energy Registers. Whenever an individual energy type is generated / consumed, its
value is updated in the corresponding main energy register. These registers can be reset by unlocking the meter
at level 5.
The presentation for units and the number of decimals can be configured using M-Cubed 100.
Note: The capacity of energy registers on meter display should be a minimum of 20 years.

7.2.1 Defraud energy metering

In defraud energy metering mode, Prometer 100 computes energy based on Imaximum and Vnominal as follows:
Defraud energy = 3 x fraud factor x Imaximum x Vnominal
Where, fraud factor is a percentage taken into account for defrauded energy metering. The fraud factor can be
configured as 100% or 150% depending on the requirement. By default, it is set as 100%.
Defraud energy metering can be enabled for magnet event for either active; or active and reactive energy
registers, depending on the requirement. By default, it is enabled for active and reactive energy registers. There
will be separate register for defrauded energy and will be available on display and BCS, if configured.

7.3 Instant values

Besides energy, the Prometer 100 can also measure instant values. Instant values are constantly changing
values such as current, voltage, power and harmonics. The instant values are updated every second. The
formulas and definitions used to calculate the values are presented in Appendix E: Calculation principles on
page 75.

7.3.1 Overview
This table provides an overview of the instant values that can be read on the meter. Readings can be viewed
with M-Cubed 100, on the display and with other software that has implemented Prometer 100’s communication
protocol. Most instant values can be logged; for more information, see section Loggers on page 53.
Instant value Available on 3-element, wire Available on 2-element, wire
type (3P4W) meter type (3P3W) meter
Real Time Clock – Date and Time Yes Yes
Phase Voltage Yes (L1, L2, L3, Average) No
Line Voltage (L12, L23, L31, Average) Yes Yes
Line Current Yes (L1, L2, L3, Average) Yes (L1, L3, Average)
Active Current Yes (L1, L2, L3, Average) Yes (L1, L3, Average)

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 Reactive Current Yes (L1, L2, L3, Average) Yes (L1, L3, Average)
Voltage Phase angle (L12, L23, L31) Yes Yes
Current Phase angle Yes (L1, L2, L3) Yes (L1, L3)
Active power total Yes Yes
Active power per phase Yes No
Active power fundamental Yes Yes
Active power fundamental per phase Yes No
Reactive power total Yes Yes
Reactive power per phase Yes No
Apparent power total Yes Yes
Apparent power per phase Yes No
Power factor total Yes Yes
Power factor per phase Yes No
Frequency Yes Yes
Average THD voltage Yes Yes
THD voltage per phase Yes No
Average THD current Yes Yes
THD current per phase Yes No
Average THD power Yes Yes
THD power per phase Yes No

For instant values such as current, voltage and power, the presentation for units and the number of decimals on
the display depends on the CT/VT ratio (primary current and voltage value).

7.3.2 Harmonics measurement

Harmonics numbers 2 to 31 are measured for all currents and voltages. At a fundamental frequency of 50 Hz,
the second harmonic is 100 Hz, the third harmonic is 150 Hz, etc. Both the harmonics’ amplitude and phase
angle are measured and included in the calculation of power and energy, and their magnitude can be read via
the meter’s communication protocols (DLMS and MODBUS). In M-Cubed 100, harmonic magnitude is
presented with a chart.
Voltage harmonics
Parameter Available on 3-element, wire Available on 2-element, wire
type (3P4W) meter type (3P3W) meter
Real Time Clock – Date and Time Yes Yes
Voltage harmonics (2 to 31) – L1 Yes Yes
Voltage harmonics (2 to 31) – L2 Yes No
Voltage harmonics (2 to 31) – L3 Yes Yes

Current harmonics

7.3.3 THD
THD stands for Total Harmonics Distortion and is a measurement of the amount of harmonics present in a
signal. Voltage and current THD can be read via M-Cubed 100 and on the display.

BGX501-943-R09 Prometer 100 User Manual Page 49 of 92

7.4 Daily energy snapshot
Energy snapshot feature saves the value of a particular energy register at midnight (00:00). Prometer 100
stores snapshot of different energy registers (can be up to 34 energies) on a daily basis at midnight. Snap shots
can be stored for a maximum of 100 days. The updating of energy snapshot records is done in a rollover
fashion, i.e. each day a new energy snapshot is stored in the memory and the earliest record is deleted. So at
any time a meter will have energy snapshot records for the last 100 days.

7.5 Digital inputs and outputs

The Prometer 100 has several inputs and outputs that can be configured to perform various tasks. Both inputs
and outputs are protected against overvoltages by varistors. They also have an isolated interface between the
electronics and the surroundings to ensure personal safety. For electrical data on the meter’s inputs and
outputs, see Appendix F: Connection and general details (page 80).

7.5.1 Inputs
The inputs can be configured as follows:
• Not used
The input is not used.
• Billing action
An incoming pulse will result in the present period ending; and energy and demand registers being
copied to historical registers. By setting limits for maximum and minimum pulse lengths, the meter can
be limited as to what it detects as a valid pulse. Pulses with lengths beyond the established limits are
ignored. For a pulse to Billing Action, it is also necessary that the Billing Registers and Control be
configured to allow this (select ‘Enable MD reset through digital input’ option). For more information, see
the section Historical registers (pg.60).
• Pulse input
To register pulses from pulse-producing units such as energy meters or water meters, pulse inputs are
used. Incoming pulses are accumulated in registers called external registers. There is an external
register connected to each input on the meter.
• Time sync pulse
When incoming pulses are received, the meter’s clock is synchronised at a specific interval For
available synchronisation intervals and more detailed information on time synchronisation, see the
section Meter clock (pg. 44).
7.5.1.1 Registration of pulses
A pulse must be at least 40 ms (for 50 Hz) and 32 ms (for 60 Hz) long to be guaranteed of being detected by the
meter.

7.5.2 Outputs
The outputs can be configured as follows:
• Not used
The output is not used.
• Energy pulse
The output is used to pulse an energy type that the meter is measuring. The pulse weight and pulse
length at the supply frequency is specified for all pulse outputs. The available options for pulse weight
depend on the CT/VT ratio configured in the meter. The pulse length at the supply frequency (50 Hz or
60 Hz) can be configured between 20 ms (for 50 Hz)/ 16 ms (for 60 Hz) and 1000 ms.

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 Pulse Gap

Maximum pulse frequency at outputs is limited so that the gap is at least as long as the pulse length.
• Long pulse
The output is used to generate long pulse whose length is between 2 seconds and 15 seconds. By
default, the pulse length is set as 10 seconds. The long pulse output is used for the following functions:
o End of MD Period
On switching the MD registers, the output generates a long pulse.
o End of Rate Period
On switching the Rate registers, the output generates a long pulse.
o Billing Action Start
On performing billing action, the output generates a long pulse.
o Demand Integration Period Start
At the start of a set demand integration period, the output generates a long pulse.
o Logger Integration Period Start
At the start of a set logger integration period, the output generates a long pulse.
• Remote control
With this function, the output can be made active or inactive by sending commands to the meter via the
DLMS protocol. This function can be used to control anything that can be controlled with a digital relay
output. For this, it is also necessary that the Billing Registers and Control be configured to enable
remote control using M-Cubed 100.
• State output
o MD Register
With this function, the output remains active or inactive for the time zones during which the
selected MD registers are activated.
o Rate Register
With this function, the output remains active or inactive for the time zones during which the
selected Rate registers are activated.
o Alarm Output
When an output is set to function as an alarm output, multiple user-defined alarms can be
selected to indicate at the output. When an alarm occurs, the output switches to active, and
when the alarm state ceases, the output returns to inactive. In the section Alarms (pg. 56), user-
defined alarms are described and how they can be configured.
Note that the outputs are inverted via firmware. If the meter loses its power, the relay will open, regardless of it
is inverted or not.
7.5.2.1 Output states
An active output means a closed relay when the output is not inverted. When the output is inverted, the active
relay is open. The Prometer 100 outputs are of the solid-state type and when the meter is turned off, they are
open.

BGX501-943-R09 Prometer 100 User Manual Page 51 of 92

7.5.2.2 Meter variants

Inputs/Outputs Prometer 100-R Prometer 100-W

4 configurable input/output ● ●
8 outputs and 4 configurable input/output ●
7 outputs and 4 configurable input/output ●
2 outputs ●
No inputs/outputs ●

7.6 Communications and security

Prometer 100 has optical port, RS232, RS485 and Ethernet ports for communication.
Note:
The Prometer 100-W supports attachment of field replaceable communication modules for RS232 and RS485.
These modules are optional and can be procured separately.

Communication channel Default / Max Supported protocol Usage

supported Baud
rate
Optical port- IEC1107 300 / 19200 bps DLMS Sign ON Local meter reading
Meter reading, online
RS485 (RJ-45 in & out) 9600 / 57600 bps DLMS, Modbus RTU
monitoring, third party interface
Remote meter reading through
RS232 9600 / 57600 bps DLMS
external modem
Modbus TCP (port no.: 502)
Meter reading, online
Ethernet port 10 / 100 Mbps DLMS TCP (port no.: 4059)
monitoring, third party interface
SNTP
Ethernet port (for IEC
61850 network) applicable Meter reading, online
10 / 100 Mbps IEC 61850, SNTP
for variant supporting IEC monitoring, third party interface
61850 communication
Note:
• For meter variants supporting IEC 61850 communication, the Modbus protocol can be configured for either
RS485 port or Ethernet port.
• For more information on protocol support, contact concerned sales person.

7.6.1 Communication speed

The meter’s optical port always starts with a baud rate of 300 bps, regardless of what is configured, before
shifting over to the specified communication speed. This means that software (for example, M-Cubed 100) that
communicates with the meter via the optical port does not need to know the speed that the meter’s optical port
is set to. RS232 and RS485 communication ports differ in this respect. They start at the specified baud rate from
the beginning, which means that connected software must be aware of the speed to be able to communicate.
RS232 communication port can be set at a speed of between 9600 bps and 57600 bps, and RS485
communication port can be set at a speed of between 9600 bps and 57600 bps. The optical port can be set at a
speed of between 1200 and 19200 bps. The configured protocol and baud rate for the communication ports can
be viewed on the meter display under page ‘Default Display Sequence’.

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7.6.2 Security
The meter has five authorisation levels that can limit access to the meter during communication via any of the
meter’s communication ports. Authorisation levels are password-protected.

Authorisation levels
1 Provides access to reading.
2 Provides access to everything in level 1 plus access to set the clock and reset maximum demand
values.
3 Provides access to everything in level 2 plus access to configure the meter, CT/VT ratio and linear
transformer correction; reset events and change password for levels 1, 2 and 3
4 Provides access to everything in level 3 plus access to non-linear transformer correction, change
password for levels 3 and 4.
5 Provides access to reset passwords for levels 1 to 4, reset energy registers; and upgrade
application firmware in the meter. By default, Level 5 password is not provided to user due to
security reasons and is provided on demand (contact technical support team for level 5 password
for meter, if required). Level 5 password is linked to the customer ID and meter serial number and
is in form of an encrypted file known as Key Data File (KDF).
Refer to M-Cubed 100 help for information on importing KDF, upgrading application firmware and
resetting energy registers.
Note: By default, Prometer 100 supports time set transaction at level 2. The meter can also support time set
transaction at level 1 if required, for third party system integration. This feature can be configured using
M-Cubed 100 at level 4.

7.6.2.1 Limitation of total access attempts

The meter limits the total number of access attempts to seven when incorrect passwords are entered. At the
eighth attempt, the meter blocks access whether the password is correct or not. The block is in effect until the
next hour shift. After that, new password attempts may be made. This is in line with Code of Practice (Balancing
and settlement code).
7.6.2.2 Passwords
The passwords can be a combination of alphanumeric and underscore characters. The password can have a
minimum of 6 characters and a maximum of 16 characters (and maximum 15 characters for level 1).
7.6.2.3 Access restriction for measuring and calibration LED configuration
The measuring and calibration LED configuration requires level 4. (Refer to Appendix H: Hardware security for
details)
Note: If the calibration LED configuration is protected by hardware security then the calibration LED
configuration will not be available under configuration menu on display.

7.7 Loggers
The Prometer 100 has two identical, parallel and individually configurable loggers. That which is described in
this section applies both to logger 1 and logger 2.
7.7.1 Overview
A logger in a Prometer 100 can log values for instant quantities, energy registers and external registers. Some
quantities can be logged both by phase and as total values for all three phases, others only as total values. The
table provides an overview of quantities that can be logged. Certain instant values in the table are not available
in 2-element, wire type (3P3W) meters and thus cannot be logged; see the section Instant values (pg. 48).
Logger parameters can be read as profile data and SIP wise.

Quantity Computation Method

Real Time Clock – Date and Time Instant
Active Import Total (Q1+Q4) Consumption / Cumulative
Active Export Total (Q2+Q3) Consumption / Cumulative

BGX501-943-R09 Prometer 100 User Manual Page 53 of 92

 Active Import Fundamental (Q1+Q4) Consumption / Cumulative
Active Export Fundamental (Q2+Q3) Consumption / Cumulative
Reactive Import while Active Import – Q1 Consumption / Cumulative
Reactive Import while Active Export – Q2 Consumption / Cumulative
Reactive Export while Active Export – Q3 Consumption / Cumulative
Reactive Export while Active Import – Q4 Consumption / Cumulative
Apparent – While Active Import Consumption / Cumulative
Apparent – While Active Export Consumption / Cumulative
Reactive Import (Q1+Q2) Consumption / Cumulative
Reactive Export (Q3+Q4) Consumption / Cumulative
Reactive Inductive (Q1+Q3) Consumption / Cumulative
Reactive Capacitive (Q2+Q4) Consumption / Cumulative
Net Active (Imp – Exp)* Consumption / Cumulative
Net Reactive (Q1+Q2-Q3-Q4)* Consumption / Cumulative
Active Import Total (Q1+Q4) - Phase 1 Consumption / Cumulative
Active Import Total (Q1+Q4) - Phase 2 Consumption / Cumulative
Active Import Total (Q1+Q4) - Phase 3 Consumption / Cumulative
Active Export Total (Q2+Q3) - Phase 1 Consumption / Cumulative
Active Export Total (Q2+Q3) - Phase 2 Consumption / Cumulative
Active Export Total (Q2+Q3) - Phase 3 Consumption / Cumulative
All phase Forwarded Active Total Consumption / Cumulative
All phase Forwarded Reactive Lag Consumption / Cumulative
All phase Forwarded Reactive Lead Consumption / Cumulative
All phase Forwarded Apparent Total Consumption / Cumulative
All phase Gross Active Import Total Consumption / Cumulative
All phase Gross Active Export Total Consumption / Cumulative
Phase Voltage - Phase wise, All phases Min / Max / Avg / Instant
Line Voltage - Phase wise, All phases Min / Max / Avg / Instant
Line Current - Phase wise, All phases Min / Max / Avg / Instant
Active Power - Phase wise, All phases Min / Max / Avg / Instant
Reactive Power - Phase wise, All phases Min / Max / Avg / Instant
Apparent Power - Phase wise, All phases Min / Max / Avg / Instant
Power Factor - Phase wise, All phases Min / Max / Avg / Instant
THD Voltage (%) - Phase wise, All phases Min / Max / Avg / Instant
THD Current (%) - Phase wise, All phases Min / Max / Avg / Instant
THD Power (%) - Phase wise, All phases Min / Max / Avg / Instant
Frequency Min / Max / Avg / Instant
Voltage Phase Angles Min / Max / Avg / Instant
Voltage Current Angles Min / Max / Avg / Instant
Voltage Harmonics - Phase wise, All phases (3rd, 5th, 7th,
Min / Max / Avg / Instant
9th, 11th, 13th and 15th)
Current Harmonics - Phase wise, All phases (3rd, 5th, 7th,
Min / Max / Avg / Instant
9th, 11th, 13th and 15th)
Pulse Input Counter (1 to 4) Instant
Active TOU register Instant

Energy can be logged as consumption (Delta value) or cumulative value. On changing configuration from
consumption to cumulative energy logging or vice-versa, the logger data will be erased. Instantaneous values
Page 54 of 92 Prometer 100 User Manual BGX501-943-R09
can be logged as average, maximum, minimum and instant value during the logging interval or as the
instantaneous value at the end of the logging interval. Maximums and minimums are detected based on interval
snapshots, and average is calculated based on interval snapshots.
Notes:
• Maximum 50 parameters can be selected for each logger.
• Pulse input must be configured through ConfigView.

7.7.2 Logging interval and total channels

A logger can store data in 1 to 50 channels. The logging interval is common for all channels in a logger and it
can be configured from one minute up to one hour. A logger’s capacity is dependent on number of channels,
logging interval and type of parameters configured. For example, Prometer 100 meter can be configured to
store 480 days of load profile data at 30 minutes SIP for 10 parameters (other than energy and status flags).
When the logger is full, the oldest values will be written over.
Notes:
• Survey Integration Period (SIP) for Instantaneous and energy parameters can be configured as 1, 2, 3,
4, 5, 10, 15, 20, 30 or 60 minutes.
• A logger’s capacity will vary depending on the type of parameters configured.
• Maximum 1000 days can be configured.

7.7.3 Storage of logged values

Logged values are saved with time stamps and flags that indicate events that have occurred during the logging
interval.
• The time stamp indicates the end-time. If the logging interval is configured to 15 minutes, a value with
the time stamp 15:30 refers to the period 15:15 to 15:30.
• To indicate events or states during an interval, a logged value can be stored with one or more flags.

S.No. Event or state Explanation

During the past interval, the meter clock has been adjusted either
1 Date or time changed
instantaneous or a sliding adjustment is in progress.
The past interval is incomplete. For example, an interval shortened by the
meter being without auxiliary power or if the logging memory has been reset.
2 SIP incomplete The first value after the logging memory having been configured will thus
always be indicated with "Faulty value” (the logging memory is reset in
conjunction with reconfiguration).
In conjunction with user-defined alarms being configured, it may be specified
that an alarm will also be indicated with logged values. When a user-defined
3 Alarm ON
alarm has triggered during the past interval, this is indicated with the flag
“Alarm”.
Load survey parameter
4 Changes in logger’s parameter or CT/VT ratio
changed
5 Daylight savings time Daylight saving time has been in effect during the past interval.
6 Phase failure During the past interval all measuring voltages have been lost or missing.
Field Replaceable
7 Battery (for meter Estimated battery lifetime is up/ no battery/ battery drained.
reading/ RTC backup)
8 Power failure During the past interval, the meter has been powered off.
9 Low voltage During the past interval measuring voltage has been low
10 Current reversal During the past interval measuring current direction detected as reverse
11 Data invalid Invalid data due to change in parameters or time set etc.
12 TOU flag Active TOU register information

BGX501-943-R09 Prometer 100 User Manual Page 55 of 92

 For several of the flags, additional information can be viewed in the event log. A more exact time for events
is specified in the log.
According to IEC 62056-62, Prometer 100 supports the compression method for logged data to minimise the
volume and reading time. The meter supports configuration of the following data compression methods:
• Data value: The value (excluding time stamp) will be expressed in shortest data type.
• Time stamp: The time stamp information will be replaced by null data.
• Data value and time stamp: The meter will apply both data value and time stamp compression methods.

7.8 Alarms
The Prometer 100 is equipped with alarms to be able to indicate when measured quantities are over or under a
threshold limit value. The meter enters the alarm state when the limit value is reached. An alarm is generated
only after the alarm state has continued for a configurable time (delay). Alarms are configurable by the user
using M-Cubed 100 and are therefore called user-defined alarms. The delay can be configured to a maximum of
20 minutes.
Note: There are alarms and events that cannot be configured, but instead, are always active. Examples of such
alarms are indication that the clock has been changed or that an auxiliary power loss has occurred. For more
information, see the section Display of events (pg. 58).

7.8.1 Overview
For most user-defined alarms, the limit value is specified as a percentage of the nominal value, which is the
configured, nominal primary value (current, voltage or power). For 3-element wire type 3P4W meters, the limit
value corresponds to phase voltage, and for 2-element wire type 3P3W meters, phase to phase voltage. The
following table provides an overview of available alarms.

Alarm/Event Description and occurrence condition

Low voltage is detected if any phase voltage value is below the configured
limit (percentage of Vnominal). Precondition is that missing voltage phase wise
Low voltage should not persists in meter.
Alarm can be configured for low voltage event. Occurred condition is treated
as alarm condition.
High Voltage is detected if any phase voltage value exceeds the configured
limit (percentage of Vnominal).
High voltage
Alarm can be configured for high voltage event. Occurred condition is treated
as alarm condition.
Voltage unbalance is detected if voltage deviation exceeds the configured
limit (percentage of Vnominal). Voltage deviation is the difference between any
Voltage unbalance phase voltage and average voltage.
Alarm can be configured for voltage unbalance event. Occurred condition is
treated as alarm condition.
Current unbalance is detected if current deviation exceeds the configured
limit (by default, it is set as percentage of Inominal / Ibasic and can be configured
as percentage of Iaverage depending on the requirement). Current deviation is
the difference between any line current and nominal/basic current
(Inominal / Ibasic).
Current unbalance Precondition is that current open, current terminal shorting, missing voltage
phase wise and invalid voltage should not persists in meter.
Alarm can be configured for current unbalance event. Occurred condition is
treated as alarm condition.

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 High THD voltage is detected if any phase THD voltage value exceeds the
configured threshold (% THD voltage).
High THD voltage
Alarm can be configured for voltage THD event. Occurred condition is treated
as alarm condition.
High THD current is detected if any THD current value exceeds the
configured threshold (% THD current).
High THD current
Alarm can be configured for current THD event. Occurred condition is treated
as alarm condition.
High THD power is detected if any THD power value exceeds the configured
threshold (% THD power).
High THD power
Average value of THD for all power phases exceeds the limit value.

Missing voltage phase Missing voltage phase wise is detected if any phase voltage value is below
wise the configured threshold (percentage of Vnominal). Precondition is that
respective line current should be above predefined limits (default limit is 10%
or
of Inominal / Ibasic).
Any phase VT miss or
Alarm can be configured for VT miss event (any phase). Occurred condition
Current without voltage (any phase) is treated as alarm condition.

Auxiliary supply fail Any auxiliary supply fails

System power factor is below limit value.

Low power factor Low power factor is detected if 3-phase average power factor value falls to
the configured limit.
System active power is below limit value.
Low active power Low active power is detected if 3-phase system active power value is below
the configured limit (percentage of nominal power).
System active power is above limit value.
High active power High active power is detected if 3-phase system active power value exceeds
the configured limit (percentage of nominal power).
Any phase voltage individual harmonics value (2nd to 31st) is above the
configured limit (percentage of Vnominal) value. Every 5 second meter will scan
High harmonic voltage
2nd to 31st harmonic values for one phase and in next 5 sec meter will scan for
next phase. Hence resolution of checking for each phase is 15 second.
Any phase current individual harmonics value (2nd to 31st) exceeds the
configured limit (percentage of Inominal / Ibasic). Every 5 second meter will scan
High harmonic current
2nd to 31st harmonic values for one phase and in next 5 sec meter will scan for
next phase. Hence resolution of checking for each phase is 15 second.
Internal error / RTC fail / In case of internal failure like RTC fail (as per event logged), battery fail or
Battery fail system status.
Reverse current is detected if current direction is reversed or the phase angle
for a phase deviates by more than 90 degrees from another phase.
Reverse energy Precondition is that respective phase voltage should be healthy.
direction
Alarm can be configured for CT reverse event (any phase). Occurred
condition (any phase) is treated as alarm condition.

Note:
• Two LEDs are available for alarm information.
• Multiple alarms can be selected on single LED.
• Events selected only for alarm, shall not log event. For logging purpose event has to be selected. Refer
to Appendix G for details.

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7.8.2 Indication
Alarms can be configured to indicate in one or more of the following ways:
• Alarm LED on meter front
• Changed digital output level
• Indication of a logged value with a flag
The alarm LED stops flashing and the digital output returns to inactive low after the alarm state passes.

7.8.3 Display of events

The events status can be viewed on the meter’s display if the tamper information displays are configured to be
included in one of the meter’s display sequences. A more detailed description of the meter's events can be
viewed in M-Cubed 100. Via M-Cubed 100, the event log can also be printed out or saved to a file.

Maximum
number of
Sr.No Compartment name Events Snapshot
events per
compartment
1 Missing voltage phase wise
2 Voltage related Over voltage Y
100
3 events Under voltage
4 Voltage unbalance
Reverse current direction
5
phase wise

Current related Current circuit open phase

6 100 Y
events wise
7 Current terminal shorting
8 Current unbalance
9 Power failure / Power On-Off
Power failure related
10 Auxiliary 1 fail 100 N
events
11 Auxiliary 2 fail
Transaction related Time set transactions
12 100 Y
events
13 Neutral disturbance
14 Other events Magnet detection 100 Y
15 Low power factor
Cover open (In case of cover
open during power fail
16 Non-rollover events duration, time stamp and 100 Y
snapshot will be logged at
power up time)
Device ID (bus address)
17
Change
18 Password change (level 1)
High level security keys
19 change (passwords of levels
Configuration events 2, 3 and 4) 100 N
Tariff download
• Transformer loss change
20 • Error compensation
change
• Commission change

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 (when CT/VT ratio is
changed)
• Configuration successful
(when configuration
applied successfully)
IP address/ subnet mask/
21
gateway change
22 Event reset
Remote output control
23
disconnect
Remote output control
24
connected
25 Register reset
26 MD reset transaction
27 Application firmware upgrade
28 Current missing phase wise
29 Supply related Invalid phase association
100 Y
events Invalid voltage
30
31 Feeder supply fail
32 RTC fail
Diagnostic events 100 N
33 Internal error
THD voltage related
34 Phase wise voltage THD (%) 100 Y
events
THD current related
35 Phase wise current THD (%) 100 Y
events

For snapshot refer to Appendix G

7.9 Maximum demand

Maximum Demand (MD) plays a crucial role in current scenario of electricity conditions. According to maximum
demand conditions it is easy to monitor variation in the load condition and trend of load according to the time
zone.
The Prometer 100 meter has the capability of logging Maximum Demand for all the selected energy types
(except Net Active and Net Reactive). The Maximum Demand is computed for a fixed block of time which is
called Demand Integration Period (DIP). DIP can be set to 1, 2, 3, 4, 5, 10, 15, 20, 30 or 60 minutes.
Maximum Demand registers are provided for each individual energy type. A separate register is available to
record the Maximum Demand during the entire day (i.e. 00-24 hours). This is known as the Universal Maximum
Demand register. This is not configurable through the tariff.
The rules for logging Maximum Demand in these individual register may be set on the following basis:
As per time zone: In this case the individual MD registers are assigned to a specific time zone of a day. A
particular MD is active in the assigned Time Zone only. In such case the MD register are called TOU MD
register. Prometer 100 supports a maximum of eight TOU MD registers.
Sealed button: User can trigger the Maximum Demand by use of sealed button provided under the front cover
of the meter.
Please note that the Maximum Demand in any MD register is for the current billing period and is always reset to
zero whenever a billing cycle is finished.

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7.10 Historical registers
Historical registers are used by the Prometer 100 to store current register values at defined points so as to be
able to read them later. Stored in historical registers are all maximum demand values, TOU registers and
energy registers, with the exception of energy registers by phase. The historical registers are time stamped to
indicate when storage occurred. The Prometer 100 can store up to 15 historical registers.
Date and time Historical registers

Energy registers Maximum demand

values

Time of use registers

7.10.1.1 Finish billing period

By performing billing, the current registers values are stored in historical registers and the maximum demand
values are reset. When a billing period is finished, an event is stored in the meter’s event log. Periods can be
finished in various ways:
• Via meter push button
The billing period is finished when the meter’s sealed button is
pressed.

This requires that the historical registers are configured to permit

finish via the meter push button.
• Via M-Cubed 100
The billing period is finished when a command is given from
M-Cubed 100 or third-party software.
• At any configured billing
The billing period is finished when the meter clock reaches the
date
configured billing date
• Via digital input
The period ends when a pulse is received at a digital input on the
meter.

This requires both that the Billing Registers and Control are
configured to permit ending via a digital input and that an input is
configured for this purpose.

7.10.1.2 Lock out time for finish billing period

The Lock out time prevents the user to create a new historical period (perform billing action) through sealed
button within a configured time. It can be configured from 1 hour to 40 days.

7.11 Time of use

Time of use is a function that enables energy to be divided up into various registers depending on the rate that
applied when the energy was measured. In the Prometer 100, tariff structure can be stored that switch rates at
predetermined times according to a configurable pattern. A tariff structure consists of seasons, day types and
special days. The maximum number of rates is sixteen.
• Day types specify how rates change during a 24-hour day.
• Seasons specify the day types that apply during the days of the week, Monday to Sunday.
• Special day specify the day type that applies on a certain date.

7.11.1 Day type

Prometer 100 supports up to 16 day types. A day type specifies which rate, from a maximum of eight, should
apply when during the day. A day can have up to 16 changing points. A day type can be connected to a day of
the week in a season or to a special day.

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7.11.2 Season
A season refers to a period. During this period, the season defines the day types that will apply during the days
of the week. Prometer 100 supports up to 16 separate seasons. The seasons are arranged in a sequence
where one season replaces the previous at a predetermined date.

7.11.3 Special Days

Days that change rates according to a pattern but is not covered by linking day types to seasons are called
special days. A special day specifies the day type that applies on a certain date. Special days can be configured
to apply every year on the same date or for a single year. In the Prometer 100, up to 30 special days can be
configured.

7.11.4 TOU energy registers

An energy register that is chosen to be divided into the rates is a TOU energy register. There are 14 TOU
energy registers and each TOU energy register has separate registers for sixteen rates.

7.12 Billing cycle support

The concept of energy metering essentially consists of billing cycles. Prometer 100 has an inbuilt support for
billing cycle.

7.12.1 Billing cycle

The Prometer 100 provides following ways to perform a billing action. Performing a billing action finish current
billing cycle and starts a new billing cycle.
• According to billing dates specified in tariff file. A billing action from a billing date is done at the start of
the day on the nominated date file
• At the time of tariff activation i.e. whenever a new tariff is activated. Downloading of new tariff having
change in energy channels, CT/VT ratio (scaling) and TOU
• By pressing sealed button to perform MD Reset
• Authenticated command for MD Reset from M-Cubed 100
• When billing date is missed
Note: The lock out time prevents the user to perform a billing action using sealed button within a configured
time.

7.12.2 History of energy, rate and MD register

Following values are stored in the meter memory each time a billing cycle completes i.e. a billing action is
performed.
1. Values of all main Energy Registers at the time of a billing action. This is maintained in a rollover
fashion which may have a maximum of 15 histories .i.e. all last 15 historical values will be available to
you.
2. Values of all Rate Registers. This is maintained in a rollover fashion which may have a maximum 15
histories .i.e. all last 15 historical values will be available to you.
3. Values for all MD Registers along with Date & Time of MD occurrence. This is also maintained in a
rollover fashion which may have a maximum 15 histories .i.e. all last 15 historical values will be
available to you.

7.12.3 History for the cause of billing register

The cause of billing is available in the meter for last 15 billing actions along with date and time of billing. Meter
display parameters also available for last billing actions along with date and time.

BGX501-943-R09 Prometer 100 User Manual Page 61 of 92

7.12.4 Cumulative maximum demand registers
A special register is also provided for energy type selected for maximum demand which stores cumulative
Maximum Demand for all MD register whenever a billing action takes place. Each time billing action takes place,
the cumulative register shall increase by the value of their source register.
The purpose of this register is to limit the scope of tampering with Maximum Demand by performing a billing
action repeatedly.

7.13 Meter reading

The Prometer 100 uses DLMS for meter reading. In DLMS protocol the BCS is considered the client and the
meter is the server. On request by the BCS, the meter will send all its supported OBIS codes and expected
queries. All DLMS meters will communicate data only after ‘getting associated’ with the BCS client. Meter
reading is divided in to the following sessions:
Single parameter sessions
Profile sessions
1. Instantaneous profile reading
2. Daily energy profile reading
3. Data loggers profile reading
4. Log wise events profile reading

7.14 Transformer compensation

Transformer compensation is a function for compensating for measurement errors in instrument transformers
and for losses in power transformers. The function enables the Prometer 100 to present measurement values
for which errors and losses have been compensated. The formulas used in the meter are presented in Appendix
E: Calculation principles (pg. 75).
7.14.1 Overview
The following tables present an overview of the transformer compensations in Prometer 100.
Instrument transformer compensations
Name Value to be entered
Voltage error L1, L2, L3 Ratio error as percent
Phase angle in minutes
Current error L1, L2, L3 Ratio error as percent
Phase angle in minutes

Power transformer compensations

Name Value to be entered
Copper losses, Total values Active loss as percent of nominal power
Reactive loss as percent of nominal power
Iron losses, Total values Active loss as percent of nominal power
Reactive loss as percent of nominal power

7.14.2 Instrument transformer compensations

To compensate for errors in instrument transformers, their amplitude error in percent and phase angle error in
minutes are configured in the meter. One minute is equal to the angle 1˚/60. The errors can be specified
separately for all voltages and currents. When instrument transformer compensations are used, current and
voltage are affected, as well as all quantities that arise from these: power, energy, etc.
7.14.2.1 2-element meter
When voltage errors are compensated on a 2-element meter, this is done on phase to phase voltages L12, L23
and L31 instead of on phase voltages. Only L12 and L23 are included in the calculation of power and energy.
Compensation of L31 has no significance in this respect. In compensation of current errors for 2-element
meters, only L1 and L3 can be compensated for because they are the only currents measured.

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7.14.3 Power transformer losses
Power transformer losses consist of copper and iron losses. They are expressed as percentages of nominal
power. One value is specified for active loss and one for reactive. When compensation of losses is configured,
power, energy, power factor, etc. are affected but not current and voltage.
When copper losses are added per phase, the resulting copper loss is the average of the value.
Calculating loss values
Based on the nominal total power and the measured loss value in watts, a loss value can be calculated as a
percentage of nominal power. It is the loss value that is configured in the meter. Nominal power is calculated
with configured nominal current and voltage.
Nominal power:

Powernom = Current nom ⋅ Line voltagenom ⋅ 3

%Loss value:

% Loss value = Loss / Powernom ⋅ 100

7.15 Quality of supply

Power quality encompasses voltage monitoring and harmonics measurement. Harmonics measurement is
described in the section Instant values (pg. 48).

7.15.1 Voltage monitoring

Voltage monitoring monitors the following states: swells (overvoltage), sags (under voltage), unbalance and
interrupts. Monitoring is enabled by checking the check box and configuring limit values for the events. The
occurrence and restoration limits are expressed as percentages of configured nominal voltage.
Example: Occurrence limit of 110% and a restoration limit of 90% for Swell, if primary voltage is configured as
10 kV then Swell will log at 11 kV and will restore at 9 kV.
These events are monitored phase wise every second. For 3-element meters, the average value for phase
voltage is monitored, and for 2-element meters, the average value for phase to phase voltage is monitored.
The states shorter than three seconds are registered by accumulating counters. If the states last longer than
three seconds, they are instead registered in the event log with time stamp and duration. The accumulating
counters and the event log can be read in M-Cubed 100.

State Duration Registered in Duration presented as

1s–3s Accumulating counter Duration of state*

3 s – 60 s Event log Duration of state
Event log as
Sags / Swells /
Interrupt / Unbalance Low voltage (for Sag)
> 60 s High voltage ( for Swell) Duration of state
Feeder fail (for Interrupt)
Voltage unbalance (for unbalance)
* Available over Modbus communication

Note: If voltage interrupt condition persists, then voltage sag and voltage unbalance conditions are not
monitored.

BGX501-943-R09 Prometer 100 User Manual Page 63 of 92

7.16 Using the meter’s IEC 61850 network server
Prometer 100 supports IEC 61850 (Ed. 1.0 and Ed. 2.0) which is an Ethernet-based protocol designed for
electrical substations. It is a standardised method of communications which defines industry specified object
models, containing logical nodes and data objects. IEC 61850 comprises a framework for substation and is
developed to support integrated systems composed of multi-vendor, self-describing IEDs (intelligent electronic
devices) that are networked together to perform monitoring, metering and real-time non-critical protection and
control. IEC (International Electrotechnical Commission) provides service models, testing, and protocols to
ensure the highest levels of interoperability between IEDs and applications from different vendors.
Prometer 100 (variant supporting IEC 61850 communication) can be integrated into an IEC 61850 system as a
tariff metering IED (or server); supporting concurrent IEC 61850 client connections.
Refer to the IEC (International Electrotechnical Commission) website www.iec.ch for information about IEC
61850 protocol.
Refer to the Prometer 100 technical reference guide for IEC 61850 details. Contact concerned sales person for
the Prometer 100 technical reference guide for IEC 61850.
Note: The Prometer 100-R variants supporting IEC 61850 communication will have Ethernet port (for IEC 61850
communication) instead of RS232 port.
The Ethernet-based IEC 61850 communication port (RJ-45) is available on left side under the extended terminal
cover in case of Prometer 100-W and is available at the rear in case of Prometer 100-R as shown in below
figure.

Prometer 100-W Prometer 100-R

By default, the meter is configured with a default set of meter data available to IEC 61850. This default set of
meter data is used in the default data sets and reports in the ICD file.
Note: Contact concerned sales person for the ICD file.
You must load a valid IEC 61850 configuration (CID) file into the meter in order to activate the IEC 61850
features in the meter.
You can configure network settings, generate and upload the CID file for IEC 61850 communication through
M-Cubed 100.

7.16.1 Configuring network settings

The network settings can be configured through M-Cubed 100.

Configuring IEC 61850 parameters using M-Cubed 100:

Launch M-Cubed 100, select product as Prometer 100 and click Prepare configuration. The ConfigView tool will
be launched. Connect to the meter using either Serial or TCP/IP communication. Select the Com Port and the
Baud Rate for serial communication; and enter the Meter IP Address and Port Number for TCP/IP
communication.
Go to the menu tree and select IEC 61850 Configuration.

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Click on Read configuration to get the present IEC 61850 network configuration from meter. This process
takes a few seconds, with on-screen messages indicating progress.
The IEC 61850 information can also be viewed on the meter display under page ‘Default Display Sequence’
(refer to the default display sequence on page 28 for details).
Ensure that ‘Network Configuration’ option is selected. Enter the IP Address, Subnet Mask and Gateway in IPv4
format for IEC 61850 server (meter). Select the UTC Time Zone Offset from the drop-down list to set the time
based on coordinated universal time. Contact your network system administrator for your IP address and other
Ethernet network configuration values for IEC 61850 communication.
You can enable network time synchronisation and configure SNTP time synchronisation settings. Enter the
SNTP Server IP Address and select the Time Sync Interval (in hours) to specify the frequency with which the
meter synchronises over SNTP.
Click Apply to update the configuration in the meter. Click Read configuration to verify the applied IEC 61850
configuration.

You can also verify the IEC 61850

configuration status on the meter
display.
Go to the Default Display Sequence

Scroll down to view the IEC 61850

status. You can also view the IEC
61850 information under default
display sequence (refer to the default
display sequence on page 28 for
details).

(on successful configuration) (in case of configuration failure)

BGX501-943-R09 Prometer 100 User Manual Page 65 of 92

7.16.2 Uploading CID and IEC 61850 program files
Connect the meter’s Ethernet-based IEC 61850 communication port (RJ-45) and PC to the local area network
(LAN) using LAN cable (as shown in below figure) for uploading the CID (Configured IED Description) file for
IEC 61850 communication into the meter variants supporting IEC 61850 communication.

Launch M-Cubed 100, select product as Prometer 100 and click Prepare configuration. The ConfigView tool
will be launched.
Note: You can upload the file in online as well as offline mode of configuration.
Go to the menu tree and select IEC 61850 Configuration.

Select ‘Upload File’ option. Select the File Type and browse the file to be uploaded. You can upload the
IEC 61850 program file having ‘.zip’ extension and CID file having ‘.cid’ extension for IEC 61850
communication. Contact concerned sales person for the file. You can generate the CID file by selecting
‘Generate CID File’ option. Refer to M-Cubed 100 help for details.
Enter the IP address for meter’s IEC 61850 server (refer to the default display sequence on page 28 for IP
address) and click Upload File in Meter to upload the file into the meter variant supporting IEC 61850.
On uploading the CID file, IEC 61850 server (meter) will restart and this process may take up to two minutes.
Note: In case invalid CID file is uploaded in the meter, then meter will not activate it and restore previous CID
file.

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You can verify the success of CID file configuration by reading IEC 61850 server (meter) through suitable client
to check if required changes are applied or not.

Appendix A: Abbreviations
The following are commonly occurring abbreviations used throughout this manual.

APS : Auxiliary Power Supply

BCS : Base Computer Software

CID : Configured IED Description

CMD : Cumulative Maximum Demand

CT : Current Transformer

DIP : Demand Integration Period

DLMS : Device Language Message Specification

DPM : Direct Part Marking

DST : Daylight Saving Time

ETBC : Extended Terminal Block Cover

ICD : IED Capability Description

IED : Intelligent Electronic Device

KDF : Key Data File

MD : Maximum Demand

PC FR : Polycarbonate Fire retardant

PPE : Personal Protective Equipment

RTC : Real Time Clock

RTU : Remote Terminal Unit

SCADA : Supervisory Control and Data Acquisition

SIP : Survey Integration Period

SNTP : Simple Network Time Protocol

THD : Total Harmonic Distortion

TOU : Time of use

UMD : Universal Maximum Demand

UTC : Coordinated Universal Time

VT : Voltage Transformer

BGX501-943-R09 Prometer 100 User Manual Page 67 of 92

Appendix B: Material declaration
The material declaration for the Prometer 100-R is shown below:

Enclosure Rack Stainless steel with Aluminium

Meter Enclosure Mild steel
Meter back plate Stainless steel
Meter current and voltage terminals Brass with gold and silver plating
Handle Stainless steel
Screws M3 for sealing meter with rack and M4 elsewhere
Front Cover PC (Polycarbonate)
Front hinged plate PC (Polycarbonate)

*Rack carries the female part of Essailec connector and meter carries the male part of Essailec connector with
all the back side communication ports in the form of RJ45 connector.
The material declaration for Prometer 100-W is shown below:

Enclosure PC FR (Polycarbonate Fire retardant)

Meter current and voltage terminals Brass with nickel plating
Sealing screws Brass with nickel plating

Appendix C: Communication ports

The Prometer 100 can come as fitted with the following ports (see the variant supplied as per order):
1. Optical 1107 port
2. RS232 port
3. RS485 IN and OUT
4. Ethernet
5. IEC 61850 (Ed. 1.0 and Ed. 2.0) over Ethernet port (refer to section 7.16)

Optical communication port

In Prometer 100-R, the optical 1107 port is protected by a sliding cover. The 1107 optical port cover can be slid
upwards in the arrow direction to the open position. The cover has a captive design and cannot be removed and
lost. There is an optional sealing point. While in Prometer 100-W, the optical 1107 port is protected by a
rotational seal.

Sealing Points

Cover Closed Cover Open

Figure 24: Optical 1107 port in Prometer 100-R

Page 68 of 92 Prometer 100 User Manual BGX501-943-R09

 Figure 25: Optical 1107 port in Prometer 100-W
Communication through the 1107 infrared optical communications port is performed through PC with suitable
communication cable. Care has to be taken to align the optical head so the IR transmitters and receivers are in
the best position to exchange signals. Usually this means attaching the optical head with the connecting wire
hanging straight down. Ambient visible light (daylight, incandescent or in particular fluorescent light) may disturb
the exchange of IR signals if strong enough and cause the communication to fail. To ensure reliable
communications, avoid strong ambient light positions when installing the Prometer 100.

RS232 serial communication port

The RS232 communication port is used for connecting to communication equipment such as computers and
modems through a serial cable. The meter side connector is an RJ-45 type. The user should ensure that the
other side is fitted with a suitable connector before connecting an external device with the meter. See Figure 26
for pin description.

RS485 serial communication port

The RS485 serial half duplex communication ports are intended to be used to connect the Prometer 100 to a
network for multi-drop communications. The RS485 network is looped through the input connector to the output
connector. See Figure 4 for pin description. If for example three meters needed to be “daisy chained”, then
simply connect the “RS485 Out” on the first meter to the “RS485 In” on the next meter and so on. The pin
connection for both ports is identical, so the same type of cable can be used through-out and is not polarity
conscious.

Ethernet port
The Ethernet serial communication port is used for connecting directly to an internal Ethernet network. Each
meter needs to be provided with an IP addressed static to internal LAN for communicating the data over TCP/IP
network. See Figure 26 for pin description.

Figure 26: Pin description for RJ-45 ports

BGX501-943-R09 Prometer 100 User Manual Page 69 of 92

Note- Recommended cable to use with all the above mentioned ports (RJ-45) is CAT6 type and shall be
crimped with standard tools used in LAN connection to PC/ Laptop. The other end of the cable should be as
desired by customer for its intended application like connecting to Modem or PC or LAN switch etc. In general,
all the communication ports in meter are optically isolated with each other and can be configured by M-Cubed
100 for data settings, TCP/IP settings etc. as desired by user. The Ethernet cable is normally connected
between the meter and the main switch, although local IP installations may differ.
The Ethernet port has a 1-minute inactivity time-out period. If no activity is detected the Ethernet port will
disconnect after 1 minute.

Appendix D: How to read meter through Ethernet port

This section discusses reading a Prometer 100 meter through Ethernet port (TCP/IP connection).
Prerequisites:
• Take static IP address, Subnet Mask and Gateway from network
• M-Cubed 100
• Install the M-Cubed 100 on PC
• Connect meter with PC using optical port or RS232 port
• Ensure that the Add-on keys for the connected meter are added in M-cubed 100. Refer to M-Cubed
100 help for details.

Configuring the static IP address, subnet mask and gateway

The static IP address, subnet mask and gateway can be configured using the configuration menu on the meter
display (refer to configuration menu at pg 37 for details) or M-Cubed 100.
To configure the static IP address, subnet mask and gateway IP using M-Cubed 100, do the following:
Connect Prometer 100 meter with PC on optical port

Select connection media, protocol, comport and password level. Click OK.

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The following message will be displayed on successful connection.

Click Transactions and then click TCP/IP Configuration

BGX501-943-R09 Prometer 100 User Manual Page 71 of 92

Enter the IP address, Subnet Mask and Gateway information to be configured in meter.
Click OK

The following message will be displayed on successful TCP/IP configuration.

You can verify on the meter display.

Go to the Default Display Sequence

Scroll down to view the Ethernet

configuration information

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Reading the Prometer 100 meter on the Ethernet port
Connect the meter with the LAN network using the LAN cable.
Confirm that the LAN cable is firmly connected to both the meter and PC Ethernet ports.

Click Connect and then select connection media as TCP/IP, communication type as DLMS. Select the
checkbox “Use TCP profile over Ethernet port.”
Enter the meter static IP information in Connection Address and click OK. For example,

Static IP is 172.16.13.4
Service port is 4059. It is fixed for DLMS

BGX501-943-R09 Prometer 100 User Manual Page 73 of 92

The following message appears indicating that the meter is connected successfully with the M-Cubed 100.

To read instant data, click Home > Get Values/Parameters

Page 74 of 92 Prometer 100 User Manual BGX501-943-R09

Action completed successfully will be displayed.

Appendix E: Calculation principles

Current and voltage
Current and voltage are first harmonic component (fundamental).

Calculated phase to phase voltage

Phase to phase voltage is calculated from the phase voltages’ fundamental vectors. This calculation is only
made in the 3-element meter; in the 2-element meter, the phase to phase voltage is measured.

U 121 = (U 112 + U 212 − 2 ⋅ U 11 ⋅ U 21 ⋅ cos(U 11 p − U 21 p)

Power

Harmonic component power

The calculations below are for active power, the calculations for reactive are identical except for that cos-
functions are replaced with sin-functions.

P1n Active power in L1 is calculated for harmonic component n.

Pn Total active power is calculated for harmonic component n.

ϕn Phase angle between harmonic component U1n and I1n

3-element meter:

P1n = U 1n ⋅ I1n ⋅ cos(ϕ n )

2-element meter:
For 2-element meters, only the total power is calculated in each harmonic component.

ϕ1n Phase angle between harmonic component U12 n and I1n

ϕ 2n Phase angle between harmonic component U32 n and I3 n
Pn = U 12 n ⋅ I1n ⋅ cos(ϕ1n ) + U 32 n ⋅ I 3n cos(ϕ 2 n )

BGX501-943-R09 Prometer 100 User Manual Page 75 of 92

Active and reactive power
Active and reactive power is calculated as the sum of harmonic component power up to 31st harmonic. The
calculation is made with plus and minus signs, where negative power represents export direction and positive
represents import direction.

P Total active power

P1 Active power in L1
Q Total reactive power

Q1 Reactive power in L1

P = P1 + P 2 + P3
Q = Q1 + Q 2 + Q3
For 2-element meters, two elements are added instead of three.

Apparent power
S Total apparent power

S1 Apparent power in L1

S = P2 + Q2

S1 = P12 + Q12

Energy
Energy is calculated by integrating power (P, Q and S) over time.
Definition of quadrants
The term phase angle is described under its own heading below.
Quadrant I: phase angle 1–90°
Quadrant II: phase angle 90–180°
Quadrant III: phase angle -180–(-90)° or 180–270°
Quadrant IV: phase angle (-90)–0° or 270–360°

Active energy
Active energy is calculated for import and export. The direction is controlled by the sign for active power
(+ import, – export).
Active energy import: quadrant I and IV
Active energy export: quadrant II and III

Active total forwarded energy - |E1 Active total | + |E2 Active total | + |E3 Active total |
Active import total gross energy - e.g. E1 + E3 if only E1 and E3 are in import, E1+E2+E3 if all phase are in
import
Active export total gross energy - e.g. E1 + E3 if only E1 and E3 are in export, E1+E2+E3 if all phase are in
export
Note:

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E1, E2 and E3 are phase-wise energy.

Reactive energy
Reactive energy is calculated for four quadrants. The quadrant is controlled by the sign for active and reactive
power. The direction is controlled by the sign for reactive power (+ import, – export).
Reactive energy import: quadrant I and II
Reactive energy export: quadrant III and IV
Reactive energy inductive: quadrant I and III
Reactive energy capacitive: quadrant II and IV

Reactive lag forwarded energy – |E1 Reactive lag | + |E2 Reactive lag | + |E3 Reactive lag |
Reactive lead forwarded energy – |E1 Reactive lead | + |E2 Reactive lead | + |E3 Reactive lead |
Note:
E1, E2 and E3 are phase-wise energy.

Apparent energy
Apparent energy is calculated for import and export. The direction is controlled by the sign for active power;
apparent energy is registered for the direction that the active energy has during the same period. In ‘Apparent’
energy calculation, ‘Active’ energy can be either ‘fundamental’ or ‘fundamental with harmonics’. This can be
configured through the tariff tool.
Apparent energy import: quadrant I and IV
Apparent energy export: quadrant II and III

Apparent forwarded energy – |E1 apparent| + |E2 apparent | + |E3 apparent |

Note:
E1, E2 and E3 are phase-wise energy.

Power factor
pf ( L1) = P1 / S1
P1 Phase Active power
S1 Phase Apparent power

pf (Tot ) = P / S
The power factor is calculated without signs and is thus always positive.

Phase angle
ϕ ( L1) = U 1 p − I1 p
Phase angle is specified in degree.

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THD (Total Harmonic Distortion)
Voltage, current and power THD (up to 31st harmonics) will be available on display as well as in individual
reading.

THD is calculated as the ratio of the square root of the sum of the squares of each harmonic to the value of the
fundamental quantity, expressed as a percent of the value of the fundamental.

For Voltage THD

U 22 + U 32 + U 42 + ....U n2
THD =
U1

Where, U 1 = Voltage 1st harmonic value (Fundamental value), U2 = Voltage 2nd harmonic value, U3 = Voltage

3rd harmonics value …, Un = Voltage 31st harmonic value.

Similar for current THD

Transformer compensations

Instrument transformer compensations

Instrument transformer compensations are specified as error in percent for amplitude, and as error in minutes
(one-sixtieth of a degree) for phase angle. These errors can be specified separately for all voltages and
currents.
RatioErr Ratio error as percent

PhaseErr Phase angle error in minutes

u meas Measured voltage

u Compensated voltage

NetPhaseErr Phase error of CT - Phase error of VT

Amplitude compensation

u = u meas (1 + RatioErr )

Phase angle compensation

Phase Angle Compensated = Phase Angle Uncompensated + NetPhaseErr
A positive NetPhaseErr adjustment will increase the lag of the current.
In 3-element meters, phase voltages are compensated and in 2-element meters, phase to phase voltages. The
same calculation is used for all currents and voltages.

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Power transformer losses
Power transformer losses consist of copper and iron losses. They are expressed as percentages of nominal
power.
Active Power Compensated = Active power + Active copper loss x (I/Inom)2 + Active Iron loss x ( U/ Unom)2
Reactive Power Compensated = Reactive power + Reactive copper loss x (I/Inom)2 + Reactive Iron loss x ( U/ Unom)4

Definition of phase order

Correct phase order (123) corresponds to phase position:
U1 p Phase position for U1

U 1p = 0°
U 2 p = −120°
U 3 p = 120°
The same system is represented graphically below. The vectors rotate in an anti-clockwise direction.

BGX501-943-R09 Prometer 100 User Manual Page 79 of 92

Appendix F: Connection and general details

Electrical
Connection type HV3/HV4/LV4
Wiring configuration 3-phase 3-wire, 3-phase 4-wire
57.7/100 V to 240/415 V (configurable) for 3-phase 4-wire
Voltage range (L-N/L-L)
100 V to 240 V (configurable) for 3-phase 3-wire
Inominal / Ibasic: 1 to 5 A (configurable)
Current range Imax: maximum 10 A (configurable)
Istarting: 0.1% of Inominal / Ibasic
Accuracy Class 0.2S, class 0.5S, class C (applicable for Prometer 100-W only)
50/60 Hz
Frequency
Note: PTB approved meters to be used with 50 Hz supply only.
If power drawn from Aux supply –
<0.1 VA /phase (for voltage and current circuit)
<10 VA (burden on Aux supply)
Burden
If power drawn from VT (i.e. self powered) –
<0.1 VA /phase (for voltage and current circuit)
<6 VA /phase (burden on VT supply)
STOC 10 times Imax for 1 second
Prometer 100-W - CAT III ≤ 300 V AC (versus earth)
Measurement category
Prometer 100-R - CAT III ≤ 150 V AC (versus earth)
Prometer 100-W – 6 kV
Rated impulse voltage
Prometer 100-R – 4 kV
Prometer 100-W
3.5 kV AC/50 Hz/5s
• Outer surface versus earth.
• All voltage and current inputs connected together versus earth.
• All auxiliary inputs versus earth.
Insulation AC voltage test
Prometer 100-R
2.2 kV AC/50 Hz/5s
• Outer surface versus earth.
• All voltage and current inputs connected together versus earth.
• All auxiliary inputs versus earth.

Compliance
IEC62052-11, IEC62053-22, IEC62053-24, IEC62056-52, IEC61010-1,
Standards IEC61010-2-030, IEC62052-31, IEC61850-6, 7-1, 7-2, 7-3, 7-4, 8-1 (as per
ed. 1.0 and ed. 2.0), IEC62059-31-1, CE

Page 80 of 92 Prometer 100 User Manual BGX501-943-R09

 IEC62053-23 (applicable for Prometer 100-R only)
MID (EN50470-1, EN50470-3) (applicable for Prometer 100-W only)

Mechanical
Prometer 100-R
428 x 133 x 260 mm approx. (meter with 19” rack)
Dimensions (L X W X D)
299 x 133 x 260 mm approx. (meter with 11” rack)
Translucent polycarbonate cover (with clear transparent window for display)
Enclosure
and overall mild steel body
Sealable screws on the front and back fascia of meter, sealing provision for
Sealing
optical port and sealed button
Meter – 3.8 kg approx. (± 0.1 kg)
Weight 11” rack – 2.1 kg (± 0.1 kg)
19” rack – 3.3 kg (± 0.1 kg)
Ingress Protection (IP) IP53 on front fascia and IP20 on back side
Prometer 100-W
Dimensions (L X W X D) 292.7 x 201.5 x 105.2 mm (± 0.5 mm)
Enclosure Plastic material (type Polycarbonate)
Sealing Sealable base and cover
Weight 2.5 kg approx. (± 0.2 kg)
Ingress Protection (IP) IP54
Impact rating (IK code) IK06

Environmental
-25 0C to + 55 0C (EN)
Operating range
-10 0C to + 60 0C (IEC)
-25 0C to +70 0C (EN)
Limit range of operation
-25 0C to + 70 0C (IEC)
Temperature -25 0C to +70 0C (EN)
Limit range for storage
-25 0C to +70 0C (IEC)
-25 0C to +70 0C (EN)
Limit range for transportation
-25 0C to + 70 0C (IEC)
Display operating range -20 0C to + 70 0C
Humidity 95% non-condensing
Altitude level Up to 2000 m
Pollution degree Type 2
Prometer 100-W - CATIII (refer to measuring and auxiliary inputs ≤ 300 V
AC versus earth)
Over voltage category
Prometer 100-R - CATIII (refer to measuring and auxiliary inputs ≤ 150 V AC
versus earth)

BGX501-943-R09 Prometer 100 User Manual Page 81 of 92

 Prometer 100-W - II Double insulation
Protection class Prometer 100-R - Basic insulation – Protective class I

Battery type (field replaceable) AA, lithium thionyl chloride, 3.6 V, 2 Ah

The meter is intended to be installed in a Mechanical Environment ‘M1’, with Shock and Vibrations of
low significance, as per 2004/22/EC Directive.
The meter is intended to be installed in Electromagnetic Environment ‘E2’, as per 2004/22/EC Directive.

Page 82 of 92 Prometer 100 User Manual BGX501-943-R09

Appendix G: Events
Description Logging as event Alarm LED Pulse output
Low voltage   
High voltage   
Voltage unbalance   
Current unbalance   
High THD power  
Auxiliary supply fail   
Low power factor   
Low active power  
High active power  
High harmonic voltage  
High harmonic current  
Internal error / RTC fail / Battery fail   
Low voltage (phase wise)  
High voltage (phase wise)  
Voltage sag power quality 
Voltage swell power quality 
Voltage interruption power quality 
Voltage unbalance power quality 
Energy pulse on channels 
Logger 1 integration period start 
Demand integration period start 
Billing action start 
End of rate period 
End of MD period 
Rate register selection 
MD register selection 
Remote control  
Phase wise VT missing   
Phase wise reverse energy direction   
Phase wise current circuit open (HV 3P4W meter

only)
Current terminal shorting (HV 3P4W meter only) 
Power failure / Power On-Off 
Time set transactions 
BGX501-943-R09 Prometer 100 User Manual Page 83 of 92
 Neutral disturbance 
Magnet detection


Cover open (In case of cover open during power

fail duration, time stamp and snapshot will be 
logged at power up time)
ETBC open detection 
Device ID change (bus address) 
Password change (level 1) 
High level security keys change (passwords for

levels 2, 3 and 4)
Tariff download 
Feeder supply fail (All phase missing) 
Event log reset 
Current missing phase wise 
Invalid phase association 
Invalid voltage 
RTC fail 
Internal error 
Phase wise voltage THD (%)   
Phase wise current THD (%)   

List of profile parameters (DLMS)

Section : Event log 1 to 9 snapshot profile
Sr.No Profile Parameter
1 Instantaneous Real time clock – date and time
2 Instantaneous Cumulative energy – Active import
3 Instantaneous Cumulative energy – Active export
4 Instantaneous Voltage – VRN for 3Ф4W / VRY for 3Ф3W
5 Instantaneous Voltage – VYN for 3Ф4W
6 Instantaneous Voltage – VBN for 3Ф4W / VBY for 3Ф3W
7 Instantaneous Line current – L1
8 Instantaneous Line current – L2
9 Instantaneous Line current – L3
10 Instantaneous Active current – L1
11 Instantaneous Active current – L2
12 Instantaneous Active current – L3
13 Instantaneous Power factor – L1 phase
14 Instantaneous Power factor – L2 phase
15 Instantaneous Power factor – L3 phase
16 Instantaneous Voltage angle – angle between L1 and L2 phase
17 Instantaneous Voltage angle – angle between L2 and L3 phase
18 Instantaneous Voltage angle – angle between L3 and L1 phase

Page 84 of 92 Prometer 100 User Manual BGX501-943-R09

 List of profile parameters (DLMS)
Section : Event log 10 snapshot profile
Sr.No Profile Parameter
1 Instantaneous Real time clock – date and time
2 Instantaneous Cumulative energy – Active import
3 Instantaneous Cumulative energy – Active export
4 Instantaneous Voltage THD % - Phase 1
5 Instantaneous 3rd Harmonic voltage - Phase 1
6 Instantaneous 5th Harmonic voltage - Phase 1
7 Instantaneous 7th Harmonic voltage - Phase 1
8 Instantaneous 9th Harmonic voltage - Phase 1
9 Instantaneous Voltage THD % - Phase 2
10 Instantaneous 3rd Harmonic voltage - Phase 2
11 Instantaneous 5th Harmonic voltage - Phase 2
12 Instantaneous 7th Harmonic voltage - Phase 2
13 Instantaneous 9th Harmonic voltage - Phase 2
14 Instantaneous Voltage THD % - Phase 3
15 Instantaneous 3rd Harmonic voltage - Phase 3
16 Instantaneous 5th Harmonic voltage - Phase 3
17 Instantaneous 7th Harmonic voltage - Phase 3
18 Instantaneous 9th Harmonic voltage - Phase 3

List of profile parameters (DLMS)

Section : Event log 11 snapshot profile
Sr.No Profile Parameter
1 Instantaneous Real time clock – date and time
2 Instantaneous Cumulative energy – Active import
3 Instantaneous Cumulative energy – Active export
4 Instantaneous Current THD % - Phase 1
5 Instantaneous 3rd Harmonic current - Phase 1
6 Instantaneous 5th Harmonic current - Phase 1
7 Instantaneous 7th Harmonic current - Phase 1
8 Instantaneous 9th Harmonic current - Phase 1
9 Instantaneous Current THD % - Phase 2
10 Instantaneous 3rd Harmonic current - Phase 2
11 Instantaneous 5th Harmonic current - Phase 2
12 Instantaneous 7th Harmonic current - Phase 2
13 Instantaneous 9th Harmonic current - Phase 2
14 Instantaneous Current THD % - Phase 3
15 Instantaneous 3rd Harmonic current - Phase 3
16 Instantaneous 5th Harmonic current - Phase 3
17 Instantaneous 7th Harmonic current - Phase 3
18 Instantaneous 9th Harmonic current - Phase 3

BGX501-943-R09 Prometer 100 User Manual Page 85 of 92

Appendix H: Hardware security
The meter has five authorisation levels that can limit access to the meter during communication via any of the
meter’s communication ports. Authorisation levels 1 and 2 are password-protected. Authorisation levels 3 to 5
can be protected by passwords and hardware security. In addition, measuring and calibration LED configuration
can also be protected by hardware security. Hardware security settings can be configured using M-cubed 100 if
the meter is connected with authorisation level 4. By default, it is not used.
Note: Hardware security should be unlocked for the configured levels before applying passwords.
Authorisation levels
1 Provides access to reading.
2 Provides access to everything in level 1 plus access to set the clock and reset maximum
demand values.
3 Provides access to everything in level 2 plus access to configure the meter, CT/VT ratio
and linear transformer correction; reset events and change password for levels 1, 2 and 3
4 Provides access to everything in level 3 plus access to non-linear transformer correction,
change password for levels 3 and 4.
5 Provides access to reset passwords and energy registers; and upgrade application
firmware in the meter

Unlocking hardware security

To access the functions which are protected by hardware security, you need to unlock the hardware security.
The procedure to unlock hardware security is as follows:
1. Remove the top cover (Prometer 100-W) / swing-up the hinge cover (Prometer 100-R) by removing the
seals and loosening the screws to access the sealed button as shown in figure below.

Figure 27: Unlocking hardware security in Prometer 100-W

Page 86 of 92 Prometer 100 User Manual BGX501-943-R09

 Figure 28: Unlocking hardware security in Prometer 100-R
2. Press the sealed button continuously for 5 seconds (long push). The following display menu appears. Select
Unlock Hardware Security option and press Enter. A confirmation message appears, press Up to proceed.
The message appears indicating that the hardware security is unlocked.

During hardware security unlocked mode, the display blinks to indicate that the hardware security is
unlocked. An event will be logged every time hardware security is unlocked.
After performing required operations, press the sealed button again for 5 seconds (long push) to enable
hardware security lock. The following display appears indicating that the hardware security is locked.

Note: The meter automatically enables hardware security lock at midnight.

BGX501-943-R09 Prometer 100 User Manual Page 87 of 92

Frequently Asked Questions (FAQs)
The message ‘Not configured’ is shown on the Prometer 100 display.
The message ‘Not configured’ is displayed when the parameters are not configured in the meter.
For e.g, Bar Graph of Energy parameter for the logger will be available on meter display if user configures
logger energy in meter. Similarly Rate Registers and Demand Registers will be available if user configures TOU
energy in meter.

Is it possible to have different IDs for the two RS485 communication modules attached to the meter?
For DLMS, different IDs (bus address) can be used for both the RS485 communication modules. While for
Modbus, same Modbus IDs will be used for both the RS485 communication modules.

Are the harmonics data up to 31st order available on meter display?

The voltage and current harmonics data up to 31st order is not available on meter display and can be accessed
using M-Cubed 100 and via the communication protocol.

Which information is not available on the Prometer 100’s display for 3-phase 3-wire?
On configuring Phase 2 displays for 3-phase 3-wire, the Phase 2 parameters such as energy, voltage, current,
Power, P.F, harmonics, L1-L2 voltage phase angle, L2-L3 voltage phase angle and current symmetry data will
be displayed as “……..”.

Which events are not applicable for 3-phase 3-wire?

Phase 2 current reversal, Phase 2 current miss, Current circuit open, Current terminal shorting, neutral
disturbance and invalid phase association are not applicable for 3-phase 3-wire.

Will the existing meter data reset on changing configuration?

The existing meter data will be reset on configuring/changing existing energy channels, logger parameters or
CT/VT ratio (scaling information) in meter.

What happens if a new successive DST adjustment is made when one is already underway?
The current adjustment will be stopped and the new begun.

When summer time starts, the clock jumps one hour. What happens if the user sets the meter to a DST
time within that hour?
The meter will ignore the new time because that hour “does not exist”.

Is logger’s data affected by daylight saving time change? What data is affected by daylight saving time
change?
Yes, the logger’s data will be affected by the daylight saving time change.
The daylight saving time is also applicable for TOU rate registers, TOU demand data, billing data, loggers,
events and daily energy snapshot.

Page 88 of 92 Prometer 100 User Manual BGX501-943-R09

How are logged values affected by the daylight saving time change?
According to the example:
Change from standard to daylight saving time
Interval Period is 15 minutes and DST Offset is 1 hour
Begin Time 27/03/2016 at 1:00 AM and End Time 30/10/2016 at 2:00 AM
27/03/2016
00:00 - 00:15 2804.8 kWh
00:15 - 00:30 2815.8 kWh
00:30 - 00:45 2934.8 kWh
00:45 - 01:00 2854.8 kWh
01:00 - 01:15 00.0 kWh
01:15 - 01:30 00.0 kWh
01:30 - 01:45 00.0 kWh
01:45 - 02:00 00.0 kWh
02:00 - 02:15 2854.8 kWh
02:15 - 02:30 3437.4 kWh
02:30 - 02:45 3567.4 kWh
02:45 - 03:00 3517.4 kWh
…………..

Change from daylight saving to standard time

Current day will close and duplicate day opens as soon as DST ends. Logger data will be logged in duplicate
day (i.e. new day in same date).
30/10/2016
00:00 - 00:15 2825.6 kWh
.
.
01:30 - 01:45 2935.6 kWh
01:45 - 02:00 3028.7 kWh
02:00 - 02:15 00.0 kWh
02:15 - 02:30 00.0 kWh
02:30 - 02:45 00.0 kWh
02:45 - 03:00 00.0 kWh
.
.
.
23:45 - 00:00 00.0 kWh

30/10/2016

00:00 - 00:15 00.0 kWh

00:15 - 00:30 00.0 kWh
.
.
01:00 - 01:15 2954.7kWh
01:15 - 01:30 2754.1 kWh
01:30 - 01:45 3154.8 kWh
01:45 - 02:00 2854.2 kWh
02:00 - 02:15 3054.4 kWh
02:15 - 02:30 3037.4 kWh
02:30 - 02:45 3167.2 kWh
02:45 - 03:00 3017.8 kWh
………
Logged values during daylight saving time are labelled with the flag “Yes”. “Yes” means that the DST offset is
applied in the meter

BGX501-943-R09 Prometer 100 User Manual Page 89 of 92

How previous IP data will show on meter display and Modbus when DST begin and end?
The meter time jumps by DST offset when DST begins, so no data is available in meter for previous IP.
Similarly, the meter time is set backward by DST offset when DST ends so no data is available in meter for
previous IP.

Can user set meter clock via Modbus communication protocol?

Time set transaction as per base time or DST time will be provided via DLMS communication protocol.
Only time synchronisation as per base time or DST time will be provided via Modbus communication protocol.
Meter will reject the time sync request if it is above time adjustment limit.

What is the maximum time adjustment limit and how it works?

Meter will not sync the time if the time difference is more than the time adjustment limit configured in the meter.
By default, the time adjustment limit is set as 25 seconds. The time adjustment limit can be configured as any
value between 0 to 30 seconds using ConfigView.
So, if user wants to set the meter time above time adjustment limit then time set transaction has to be performed
via DLMS communication protocol.

What are the possible consequences of adjusting forward the meter clock?
If the clock is adjusted forward over one or more integration period, there will be empty spaces filled by zero
value in the logging memory.

What are the possible consequences of adjusting backward the meter clock?
It the clock is adjusted backward over one or more interval limits, one or more values will exist with the duplicate
day and same time stamps. Empty spaces will be filled by zero value in duplicate day. In the worst event, this
can result in data read from the meter not matching the expected period. Previous integration period and rising
demand data will be reset.

What are the possible consequences of adjusting backward or forward the meter clock within time
adjustment limit?
Integration period will be compressed for forward time sync and stretched for backward time sync. Data will be
logged as per integration period.

How time stamp for events will be logged when DST begins and ends?
Time stamp of events will be logged as per DST time.
In normal case, the event time stamp will be logged as per DST time but in some exception case it will be
logged as per below example.
Occurrence delay is 2 minutes for events, DST begin time is 1:00:00 a.m. and offset is 1 hour.
If event condition starts at 12:59:00 a.m., and DST begins at 1:00:00 a.m. so event will be logged as per 1 hour
offset of DST 1:59:00 a.m. after 2 minutes of occurrence delay due to DST began during occurrence delay.
Event restoration delay is 2 minutes, DST end time is 02:00:00 a.m. and offset is 1 hour.
If event already occurred at DST time 1:55:00 a.m. and restoration condition starts at DST time 01:59:00 a.m.,
and as DST ends at 2:00 a.m. so event restoration time stamp will be logged as per standard time 12:59:00
a.m. after 2 minutes of restoration delay.
In this exceptional case, time duration of event will be not useful for consideration.

How to know about error compensated in meter?

Error compensation displays have to be configured in meter to view on meter display or user can read
measuring configuration using M-Cubed 100 (ConfigView).

Page 90 of 92 Prometer 100 User Manual BGX501-943-R09

Meter is not powering up in battery mode.
Batteries which are intended to be used infrequently and survive for longer life use Lithium thionyl chloride
chemistry. The interaction between electrolyte and electrodes result in passivation. Passivation causes inability
of the battery to provide power, when sudden load current is demanded. To recover the battery from this state,
multiple attempts to draw load current has to be made. This can be done by pressing the Enter button for ten
seconds and if the display doesn’t turn on, you can repeat this for three times at an interval of ten seconds.
Storage of battery and product at higher temperatures may result in irrecoverable passivation and the battery
will have to be replaced.
Even after pressing the Enter button for multiple times (as mentioned above), if the meter does not power up in
battery mode, then the battery might have been completely discharged/drained or passivated beyond recovery
and needs to be replaced, so contact concern sales representative for the new field replaceable battery.
The field replaceable battery specifications are as follows:

Field replaceable battery details

Battery voltage 3.6 V
Battery chemistry Li-SOCl2 (Lithium thionyl chloride)
Minimum continuous current 200 mA
Size AA
Construction Spiral wound

How to check the modem / IEC 61850 communication port supply status?
For auxiliary-powered variant of Prometer 100, either Aux 1 or Aux 2 supply is required to power up the modem
or IEC 61850 port.
For self-powered variant of Prometer 100, all three phases’ voltage are required to power up modem or
IEC 61850 port, however this can be powered up if two phases L1 and L3 are available.
You can verify the modem supply status through modem LED and IEC 61850 communication supply status on
the meter display. Go to the Default Display Sequence page and scroll down to view the IEC 61850 status. In
case the IEC 61850 supply is unhealthy, the following display appears.

BGX501-943-R09 Prometer 100 User Manual Page 91 of 92

 Secure Meters (Sweden) AB
Box 1006 (Repslagaregatan 43)
SE 611 29 Nyköping
Sweden
t: +46 155 775 00
f: +46 155 775 97

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